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
191-144
bp • • April 16, 2002 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P 0. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561-5111 Mr. Thomas Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 „ stioNED APR i 2O < Site Closure: Badami No.1 (PTD 189 -117) and Badami No. 2 (PTD 191 -144) Alaska 011 & Gas Cons, 6crs1 sss(rar Anchorage Dear Mr. Maunder: Conoco Inc. (Conoco) transferred its Alaskan assets to BP (Exploration) Alaska Inc (BPXA) in 1994. As part of this transfer, BPXA assumed responsibility for the above- named exploration sites. The Alaska Oil and Gas Conservation Commission (AOGCC) has not been able to confirm location closure for the Conoco Badami No. 1 and No. 2 exploration wells, according to a letter sent to John Skopak, Conoco, from Blair Wondzell, AOGCC, dated November 30, 2000. In review of the Badami files, we have located information that confirms the closure of the Conoco Badami No. 2 well site (PTD 191 -144). We also have supporting information to confirm closure of the Conoco Badami No. 1 Well reserve pit. However, we have not found conclusive evidence the repair to the subsided area around the well was completed. We recommend a site visit to determine the status of the Badami #1 well site during the summer of 2002 with representatives from BPXA, AOGCC, and possibly other agencies. Following the site visit, BPXA will provide a rehabilitation plan (if necessary) for agency approval and work towards a satisfactory closure of the site. We have attached copies of the supporting information to this letter. This information is also summarized below. Badami No. 1 (PTD 188 -117) The November 30, 2000 letter to John Skopak, Conoco, indicated the Badami No.1 well was inspected by AOGCC in August 1994. The inspector noted a depression around the wellhead and an open reserve pit. A September 1994 letter to Mr. Zseleczky, BPXA, reported the depression to be 8 to 12 feet wide by 2 to 4 feet deep around the well location. The following revegetation report indicates the reserve pit has been backfilled S :HSEIPermitting\BadamikBadami 1 and 2 Closure.doc • • Mr. Thomas Maunder, AOGCC April 16, 2002 Badami Nos. 1 and 2 Closure Page 2 and revegetated with color plates confirming. However, the color plates (presented on page 8 and 9) also show the possibility of a depression around the well. • Evaluation of Vegetation Establishment on Badami No. 1 Exploratory Wellsite, North Slope, Alaska (1999) prepared January 2000 (revised March 6, 2000) by Lazy Mountain Research. This report summarizes the results of a three -year revegetation attempt at the Badami #1 well site. The exploratory permit required a 30% vegetation cover on the reserve pit, which had been capped with local soil. This is the final report satisfy U.S. Army Corps of Engineers and Alaska Department of Natural Resources requirements. Badami #2 (PTD 191 -144) The November 30, 2000 letter to John Skopak, Conoco, indicated the Badami No. 2 well was "drilled from an ice island; because we have no documentation to confirm that there is no junk or equipment on the sea floor, the sea floor needs to be surveyed." The following is provided by copy to help show proper and complete location closure: • Approved Application for Sundry Approval to Abandon the well, dated 4/02/1992 • Conoco abandoned the well April 13, 1992 and submitted a Well Completion Report and Log to AOGCC. A few representative log entries (paraphrased) are listed below showing Conoco made every effort to properly close the Badami #2 well site. 0 4/14/1992 — cut casing and pull casing strings — release rig 0 4/15/1992 — clear liner, timbers, rig mats, etc. from site 0 4/16 & 4/17/ 1992 — operations shutdown due to weather 0 4/18/1992 — opened ice road to location 0 5/19/1992 — Dig up well cellar and clear location. Trim 6' of ice off pad. Retrieve all road reflectors from ice access road. End of Project. • Completion Report, for Land Use Permit LAS 13446 (Badami #2). In this report Conoco states, "Before final abandonment of the project site, all structures and facilities were removed, all debris was picked up, and all of the road markers and flags were retrieved." From the above, BPXA is confident the Badami No. 1 reserve pit and the Badami No. 2 well site were closed in accordance with 20 AAC 25. If you have any questions, please contact me at (907) 564 -4592 or Karen Wuestenfeld at (907) 564 -5490. We would be available to meet with you to discuss well closure at your convenience. Sincerely, Shana Kane, Permitting Advisor HSE- Alaska S:\HSE\Permitting\Badami\Badami 1 and 2 Closure.doc • • Mr. Thomas Maunder, AOGCC April 16, 2002 Badami Nos. 1 and 2 Closure Page 3 cc.: (w/ attachments) John Skopak, Conoco, Inc. Attachments: Evaluation of Vegetation Establishment on Badami No. 1, 3/06/00 - revised Approved Application for Sundry Approval to Abandon Badami No. 2 Well Completion Report and Log for Badami No. 2 Completion Report submitted by Conoco to ADNR -Lands dated 5/21/92 S:\HSE\Permitting\Badami\Badami 1 and 2 Closure.doc • ..0nDAJD) Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 -3999 (907) 564-7600 May 21, 1992 Mr. Leon Lynch Alaska Dept. of Natural Resources Division of Land 3700 Airport Way Fairbanks, AK 99709 -4699 SUBJECT: COMPLETION REPORT, LAND USE PERMIT - LAS 13446 - AK910918 -05 /F BADAMI EXPLORATORY WELL, MIKKELSEN BAY, ALASKA Dear Mr. Lynch, Conoco Inc. has completed operations in support of the Badami #2 Exploratory Well for the 1991/92 winter season. In accordance with the referenced permit, Conoco submits the enclosed completion report. Should you require additional information about this project please contact me at 564 -7653. Best regards, Gv 5/Latie-__ Wade L. Srock Environmental Coordinator cc File 504.05.03 • • COMPLETION REPORT FOR BADAMI #2 EXPLORATORY WELL Conoco Inc. has completed activities in support of drilling the Badami #2 exploratory well. Operations began with construction of the ice road on 12/22/91. The ice road and pad were completed on 1/28/92. The drill rig and camp were mobilized and the well was spud on 2/7/92. Drilling operations ceased and well was plugged and abandoned on 4/13/92. The site was surveyed and debris removed by 4/20/92. The last of the road markers were retrieved on 4/30/92. Operations were conducted in conformance with permit conditions. Discussion of specific aspects of the project follow: Tundra Travel A number of types of vehicles were used to conduct operations. All vehicles were restricted to operating on ice roads and pads; no tundra travel occurred. Ice Road The ice road followed the route shown on Attachment I. Water Use Water was withdrawn from two permitted water sources; the Sag C and Shaviovik gravel site shown on Attachment I. Water use for construction of the ice road and pad totalled 52,955 bbls. from Sag C and 163,835 bbls from the Shaviovik pit. Water for camp, drilling, and maintenance operations were taken from the Shaviovik pit and equalled 63,123 bbls. Clean -up Activities Before final abandonment of the project site, all structures and facilities were removed, all debris was picked up, and all of the road markers and flags were retrieved. Garbage and Debris Disposal Putrescent camp garbage was incinerated to reduce attraction of wildlife. Refuse and debris from the project were hauled to the North Slope Borough landfill. • • Badami Completion Report Page 2 Waste Injection Drilling fluids were injected into the rock formation under the permafrost. A total volume of 902 bbls. of drilling mud was injected at a depth of 10,085 feet TVD. On Ice Disposal A total of 30,536 bbls. of drill muds and 2,856 bbls. of cuttings were deposited on the sea ice a short distance from the drilisite. Polar Bear Detection System The trip -wire system utilized at the Badami site performed very well with very few false alarms. The system consisted of a light gauge wire suspended from a series of fiberglass poles and surrounding the drill pad at 250 feet from the perimeter. If the wire was broken, a set of strobe lights and an audio alarm warned personnel to seek safety. Although there were no visits by polar bears at the Badami site, the system proved itself to be effective this season when a young polar bear made several visits to the NW Milne site. Tundra Disturbance No incidents of tundra disturbance were noted during construction and maintenance of onshore ice roads. • . . -.-r 0 lakuk '%.• ••••• . . • •••• .. .. . . Oft... Na/Whill - 1 .% ) . C l ia %‘' . , , • e e 6.5; ', i - 01014 65 3 1\ , - f.,.. .... \ .................._. ... .. .. . \ I • pt 40 659 6t:,(.. •'.I • • • ■•• •I '••• .7 . •• • • . • : ... vm4 3 Gk. 6 fo 4 -. :"."•-••••-) 4,, , 64*-------. . ON Win& i N Is Heald 4 --• il . ! • :; ,, ;.1,...8 • a. PV;P:40,.,, ............. ' • ,'. "- .....•Ft Prudh e 61.40 • 6 i \........\\ t (trkl i k -N 11 4'-\ \‘ ‘ • , ,p,\\ i.. 1 . - . '1'.', , i.. , •,.. , .,„ ...,, op Ho,. ,v, .j*..:4;:i.:;;... ?' . b, 700 '• .:' coco•uiyfi 13 a y . & 1 --, 0 no 70 , . • . , ,o I 'V - 1..,- . will. f 3 • - ci,,f l' • . .......„y ... • • ,•, 0,1:17r Hews I .4 won, .1 " . It 1. J3.41 - -%1 04, r''' V • VA ,.,. `:•": ••.) ., .• ).. kapv_ ,..,. - ., V.... • -. 7 i ' • '••.. Arudely pi p 9 47 i •••.4) 3 tc. '" i g' . ! i , w-.....,ili.a q ...................*-4 .., - - , • .... „... ‘.oAh.,...-..... ------: .." . • .. , , .i. .... .r Pk' ••?' ;7' i .. • ti '` 0: la, , K;c:i'ilgS. • „u • '..:•,o 0,14o, 4 t .. '‘Art ' 1. ' ' ' ::)'. . . -4ff 7-1 -- &--A-. • 7 44 7 4 5 ,,..,* 0..::1;.'... P. " - r:•••••■••1 r. weir ( i ••-' 14 . . - Im• I or' t' .1 ''', 1 r ''''' •• ' ' 6 ' P IYIF.':1.:wri.1...:.... PI B'Qw47 4 3 ' / 7 .,11*‘A.. ...„.., .....„)._, 7 t:13::... 4 l'... , ,.. ..): •,: .1.. , • 1 e• 1 ci'.-C .? 1. ., { t.i, . -....- • ,.et . . . . ii or , . , „ h ..,- !.,. ••• . ,0 .,„e,..r....; „le-. .v:• -. 0 • .1. • !. • ... i • 1 ----•• 1 ..5;;...n : : .. " • •it,f(:) !,' * i o Oa ,Aters: , iir.:.;!4* 0i. : •. r ■ :9: • , *.'#.. ' 71 .• •?•4 ' • ...• ..•..... ••••......"_. ., 0•1ipoltili 1, I!). 1,.(i. 44 Yi v . 1 : 0 4,‘. '..; .'. , A..' ' -.:"-';' • • ^ i 4 .• • 8 . t Is d .. ••1 • 1, Al.;) ' .1 . 6 ., ., ...... 1,....V. . • :. i t !,...... ? i y ...A....t ..l ''.'N'..v.j 1,., : , • ° ;_: / 42, 44 .1 ' l '' ''t $ :" ••• • 7 . 7 e '' - r c.: ' ....., c) -1.......:.:.c..r.,,velz:vr ft=.?.!..Ifit •;,;.:., '.ii-TI , ;: .7...e. ly..4 r '.'il :4••,,?0 lip .4) 78•' ....„, 4- - J ';• , ';' • c '.: , •(.) 47.11:1 . • .. `• • .-t c ,. .. ..... •-:-°1•1?:tr•v•:..) 0 - r - . I.1on Pt it .1,1 -.i•r: '''' .r,kil ' r . ,.o.,p, 8 ay 61 7. la Islatio „ 9 (kill 1194 , 4,4 /.. • 4 . !!!!! ........ : \ . .., .. "I f •!. ': . •,...'.. '...',. ' A J4 A, 4 . " . 4 1t DI solos • I 1 1).sw.ika t ilileil ':.•11:::41.er:::4•",...,:!f. t 4 : i a - .. •.. ,,,,...% \ib..., ), ,r , ,, . A ,,f. ,;. . 0 ' ,. .14:1 .r,?/ ' ' '.' % C.! • (1 I :; : E N D IC 0 T T R 0 AD ?..F. • ,..?....,, ' '..',,4i ,.:.. . ,...,.. •-w 1r ... 4 '-• ‘ I ";. i ! ..i.t . ...b.. ..... ..---...-.-.............-....-,--”••••-•"- - - ' - • ..';',•;,•:.' ./-' ' -.:\ . j '• !. ' 5 , W • • • I•Ib :: i . t •P .7. --t-4: '. .X / 444 1 ( t:64t ''. • • ;\ . . I/ Rulieficu 8 51 ' • •.. t ....i. . :•.) rt. .....111". • ....'■ ....s ... 1% ''.' ... 4'. V......• •••• o * I. ' i ' i; II 9 ' ..., PdYitg,I4 JO ' ' . .. ' 7 ..:.• ,,,I „. ,u 011411 . • e • 4 " . • . .' .., 1 I 1 . v 1 i .. - + • '.W..* l f.. r t , : , ....i.,. .4 ..:,...: .,.... ,; . 2 3 M.I L E I C E ROAD Itr4.1 • ' ... i..,.1 ' -, 4 • , ..,,... ..,,, _,.....,.. : ,h.. . ... , ; , . ,,.. ,•.. ,..•:,,..„,...,:,.„.• 1,,It t .:: .... . , „1,-,:i 7, Wick 14 e. ri • : 0 Y " ."'......,,x„,,,,,',4 ,r; 4 Ityr I .. • ...// q. " _ .. a .,..4. 1 .. ... „p, 1 , .: • .,:„,.,... „ 04,-; )1'. j■ ':41•,' 11 1 .••:. 7 r; % • • ,v., ;, ;;....,_,,..„ ..., ,.,,, - .. (., 94. yr vy • ••••• . J ■ „IA, . 61 4 1 ^1 $ 0 .t.r " 0 , . Ir. • • ' ' 411%i, o• I' •tim. . .1 isi .4, h ad vh.11 ' Ut(• • ' ../, i, • •• •'. • . ''\ ''' • . 'A .' . p• • " 1 .1: Sr % .1 , , ;./ 1::.: I: C ....• t .4. v; eit - _v.' 1. qr ; 1 • i '1/4.4 1•• i ,.. ol, 4•' 4 ..' 9, 14" . •••• 11.,%. ;,' • • InE pAD i , ,' .' . J ,. 1'...' .: •J q A .1 V- ,, ..., ..,i., .. , ) ,4 1 , it. l. , r•N li .` m: 's , . V' 1• - • A" • 0 • •ot.. 'Iv'. ' . 1. .... f.1 ';',. ' Ni I "" ' .4. .1 .9 ;.' t .C „ ' z,:)..ir 0 1 . .n . .v c „ . .....,.... .1., ••■.? ...i. ,, .c,,..),..; ■.,.?: , ...4 . ,; 11 , . 4„ !; ,L . ,•:r , .;,' 11., F 1 ki s I. -.....;•4 • ;., ... ',•7". • - • - ,' .. 47,11'4 x ;V•kiet•' 0 1 ;',/: • Y •„. . . .t.: i . 1 . i.t... % . r t:te.,/ Al.. Cl, . ).1 .0 ., s.,„,- •I ; "I. ... ).: .. ,' , . ;,. %., ,.. -, .: _01/4 •.- . - . .1 j • b.. .%,.,, ,•:,•01,1)'1'. -. . ...PA ■ . r • , 0. t:( „. k ( NI ty %.. opi:,, I ,1% ‘, 1 . 91 s i •■•„ 1 ,..:` 1 , • 9 : • ,,,, .... 7.. I ., •, vii, ;. ...; • •,, . ,, i ' y , 6. i0114 ..• ,., ;.. . & .17. 0, .i". '.• 1",.,•4 %1C.w14 A 1 .4A.,/,1 1 :/: ''' ii i N . 1 • ... 4 e..1 .,.! , '4 •■• ( IN II . ` 7- • ••• 1 • . ; 1 '(• ' y.i t,;,. ..‘ . • • .• .'.. ! '' . 4 "3 '1 4 ..: ;',' '''. • '.' 7 .(."44 0 0 .r . `1 ) ' ...) t . '"n‘" ... ' 11 ; 7 " 1 .; 11‘7 ...4! ' ( SHAVIOVIK GRAVEL PIT ..!.,.....,-.1, .qt... :, . ; .. 3;. . ...... 6 ' _?0_40_,...,;4' • ,,,:•.•., • r, Itt. , (t.. (, ; I 6 • ...9.% .,... .1,0 t ., Y „V.:,..1 . .,.. • ..,. ...; , );Auh i'..1,., • ' ..," .; i . :?54,,,c) 1,1,0 . 4P , " `r s ,v 0 • t • /.•17., V1 ) % 0. .Vati.11 . • :.... .%.;; 1 ) . '•••• . • • • ./ i ' ••, t •••, • (,,, Ail* :. .., .4 ,. : . k .,,,.; , t Of . x .* 0 ..., ,, i. ., WATER SOURCE. 4. Ii . ,• . ...* ..' .' / '-. , 7 r ,.,-..( \ s'.. I ,: p• ..'y . ., -y...L. •z.. • . .:• w . .. -v.. ,. 1 4, •,'.: !' .' / . . . , . • -..,...,..,,,... ... , ....., • ,- . ........ • •.... . , • ,• . : .. - .t.. • ..• . • ... J(1 / .41 i • .. N. • '"‘'-',F''' ' •• r: ‘ 7140 . . /1 , 1 !.1 ' ' ' .4 ■ .. t ti 4 ii '( T' .• .r -' .'•:::: , :. . ,........, ..,...:r„ .. •• i. 1 1 i , 4 1 :4..... . i..1 t, . • .„,,,,‘. ,Letne,sii :. .,7 4%.V.L ,i., ' 1, , ,,:e ■:.•.' ... '. , !‘,...r . iyik 1 it ■I •••• .."; ,`• •, ; .... . II.% r ' . t* A • s...., 1 ' • - 1 . P ■ - '1'•, 1 . 1 .•• - V%,-.. oil: ;•'i.•' ‘ .....••••",.,,,. , 1.' c • b. V.% e".14 . .. ; :Va•• :7,, .1 4j: 1 4 ' .,i''' ,.... :', i.. 'IV );.k , • , 7,.. 4 "...., '.(),:. i I ' •') ..,‘-•:, l'..... I . j 'f:. e t. .!• 4 .1 9 ; „ v 1. ),11. . I.. .4 ...•:,.,1 ....!, ; • ' •` : '' . ,4 4 „Ile'. .... ,I• - : , ',11 ••• •• h..' -..•.,:? , 1: •-••• . I' .'' :::,.. j ( ,%•'. ; ',A.Y 71.,-4,o:Ad ,''(,\ ,..,,,s, ...%, , , - ., ., ; I., :.' k • ..4 • , t', 11 „ k• , • •,••• ..*: • n t „, * -I, .-, ' ' • : 1 ,......1:;'' f e9 ) ... I ' .i.i.Y. •() - e '..,..) ••. • • • %. ,.., ‘,43', , ... ); : 4 , ' . ' .",.....1" •“. • ■ • N .' „‘. . \ I . ', . .„•••,1, ';',•;.... 1 , . • ; ', 1 ... . .,. i,..6 ,,... ,.; p 1 ...,, ;if'!" P ,4/ .•": 1; 4 ...; % ,, .1,:liA :.....3 ) $:. . .1 ■ .v 1 ..v. . - i ■ ..., `s. , 0'. j . 's1 ••‘• ., ; .. '•,•, ...,* i • ;,:',.. :,I..... • , ' "' '•''' . . ;.• .''' • I r ,11., st . A ...\*,...,,...!? ). (1.. • F.r..0; 'kv. ;7' -.• ) 0 ... ' 1 . C tt„,%. • • '■ ( . •,.. • '4:%';',i '.1 • .7:1 ... $::.:'•• 'J .*: , .: ..k:','.: ?f,,."....° .. :, ..... • '..i I -- ". - • r • l' • ..."'i,?'''''' e ...,4.7?.......... 0 1'7 '...; :,' • Yr I I ,, . '‘ , 2 (.. .r.,..../ 1Z4., ..:..) , I t 7,, i , ..t. 'ilio alv; li • ri; ...r. ''‘il 44 '1 , .. 11 •• • '...• . ,c..•'.•• ... ' :, ' !.0 :. :'••••:' / PAO /194i 4 • . AO I ...v• .0 ., , /,..: .: e' *- 1 1 • • %. if k ..,.. -pi 3,:', ,. wil . s. .. )„ . Id • ../ q , •. .,,;, , ,,...y.. .pk,‘".v.4 ..-,,, - •• .v...... •,.. • ...0.. ......).).: . . • v i v - 1% .. ;:lre A ... • ,•(,..../ .. ( ...., ,.. ,.: ••,.,, , .1 •J ly • k 9 , ' li:Y i ••• D 14%1 .k:r. - %. i •': ,"• • • •Tr (1 : :•• ". . ' 1 • ' \ i'r'.../ . ., ( f ; f.,' $ :::......,;,0 x' -.$,( 1 . 1 ,,,t .,, ., •e). ,..,:l' _ i7. / i 1--i --0.... • .f ‘,y ..: picrdr? 1 : c, .. •,.51 k,..; "(9,1 -‘ . • e.., ' ( y , „ , . , -. •-, ;, ' lw; ,6■.. ,1 o t..., BADAMI TRANSPORTATION ROUTE ..i ;,.... ( : . ;.:.:; , : i 0 • ' ' .1 : . ! ..4 ' s i ' .ki• • ' I . ,, . • S. , ., 4 ,n . ,•:,%•1•• . t ... /6 . s. r la 1 . • ' . ' . 4) tio N. • ; I • 0 1.-......" " ' i ‘ ' " ..... 4* " . 1‘1. .1' 1:' NAME: 0 MI LES t. E 8 • . • • ; .,.. : 0 ,.. et:, ........ -:, . • orliii. 1.: .1, Conoco Inc, (1) , ,, g , e .. .,„ .,. , ,, E .,, . _ . ,,, .. 8 _,. 1 ' . 1'1' •.• 1, i :■• , ........%. i ( AREA: Mikkelson Bay e4 •,r . 1 ..; ,4'••• • 4 t.: iNv 1,,...." tr.. .(., lg ...... . . • ■ ; :.:.; --A,. I* , ••• •• .89 i? • v ( ... ;:i ...... L 4. .... t „ . ., it ., . LOCATION: Sec 30-T1ON-R2OE 4J E. , 4 30' • 1 t!.. e. 148' if 17 I SHEET I.. II Id 1:. _Z. of ?_ Date 6/25/ . 1 . 14 45 46 417 '4 . , Re: Badami #1 Subject: Re: Badami #1 Date: Fri, 08 Mar 2002 09:30:42 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Goates, R. Neal" <R-NeaI.Goates@conoco.com> Neal, I apologize for the delay. Things have been nuts up here as elsewhere. That doesn't excuse the delay, but it is life in the patch right now. Best wishes. Tom "Goates, R. Neal" wrote: Thanks Tom, I appreciate your response. Neal Goates Remediation Project Manager Mid-Continent BU, EP Americas, NG&GP Conoco Inc. 600 N. Dairy Ashford P.O. Box 2197 Houston, TX 77252-2197 (281) 293-3822 Fax (281)293-3305 Cell Phone: 832-465-4123 ----Original Message .... From: Tom Maunder [maiito:tom maunder~_,admin, state, ak. us! Sent: Friday, March 08, 2002 12:05 PM To: Goates, R. Neal Subject: Badami #1 << File: Card for Tom Maunder >> Neal, This note confirms that to my knowledge all Conoco's Alaska properties were conveyed to BP. On the basis of that property transfer, Conoco should not be responsible for any further actions with respect to Badami #1, PTD 189-117, APl 50-029-22017-00. Conoco's request for no further action is hereby approved subject to the following conditions: Please be advised that AOGCC approval of this plan does not relieve Conoco of liability should their operation fail to adequately investigate and rernedia.te contamination that pose a threat to ground water, surface water, human health or the environment. In addition, AOGCC approval does not relieve Conoco of responsibility for compliance with any other federal, state, or local laws and/or regulations. Please contact me with any questions. Tom Maunder, PE Sr. Petroleum Engineer 1 of 2 3/28102 7:44 AM g ESE Hardin A MA CTEC COMPANY Harding ESE, Ipc. 601 East 57th Place Anchorage, AK 99518 Telephone: 907/563-8102 Fax: 9071561-4574 Home Page: www. mactec.com October 9, 2001 53971 Mr. Tom Maunder Senior Petroleum Engineer ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Location Clearance Badami 1 and Badami 2 North Slope, Alaska RECEIVED ~as~a 0ii & Gas Cons. Commission Anchorage Dear Mr. Maunder: Harding ESE is submitting this letter for Conoco Inc. (Conoco) in response to a letter from Blair Wondzell with the Alaska Oil and Gas Conservation Commission (AOGCC) dated November 30, 2000. The letter states that the AOGCC could not confirm Onshore Location Clearance (Title 20, Alaska Administrative Code, Chapter 25, Section 170 [20 AAC 25.170]) for Badami 1 or Offshore Location Clearance (20 AAC 25.172) for Badami 2. Badami 1 is on the coast of Mikkelson Bay on the North Slope of Alaska (Section 9, Township 9 North, Range 20 East, Umiat Meridian). The well was drilled in 1990 as an exploratory well, and its current status is plugged and abandoned. The vertical depth of the well was 12,911 feet. The unique American Petroleum Institute (APl) number given to the well is 50-029-22017. Badami 2 was an offshore exploration well drilled in Mikkelson Bay (Section 30, Township 10 North, Range 20 East, Umiat Meridian). The well was drilled in 1992 and its current status is plugged and abandoned. The unique API number given to the well is 50-029-22230. Conoco's wells were part of the Badami prospect that was transferred to BP Exploration (BPX) in an assets exchange between the two companies in 1993. A copy of the assets exchange is attached. Conoco believes it is now the responsibility of BPX to verify that the requirements for Location Clearance at the Badami sites have been met. A letter from BPX to AOGCC dated November 8, 1994, discusses location clearance inspections of three sites, including Badami 1. The letter includes plans for corrective actions at the sites. A copy of the letter is attached. Conoco requests a response from AOGCC acknowledging receipt of this letter and confirming that no further action is required. October 11,2001 53971 Mr. Tom Maunder ALASKA OIL AND GAS CONSERVATION COMMISSION Page 2 If you have questions or need additional information, please contact Neal Goates with Conoco at (281) 293-3822 or me at (907) 563-8102 or _li iohnson~mactec.com. -- Yours very truly, HARDING ESE Lorri John~ Project En~ QC/TE/jm/W2486C Attachments Harding ESE A MACTEC CO~.,~PANY ALASILA OIL AND GAS CONSERVATION CO~I~llSSION TONY KNOWLE$, G~VERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 30, 2000 John E. Skopak Conoco Inc. P.O. Box 2197 Houston, Texas, 77252-2197 Re. Location Clearance Dear Mr. Skopak: We have your.E-mail of October 5, 2000 c0nceming. Conoco's two Badami wells. Nos; 1 and 2.' We have again reviewed our. files; the Badami #1 (PTD 189-117) is an onshoreweil and was last inspected' by our. inspector in' August of 1994 at which.' time he noted a depression around the well head and an open reserve pit; both'of which .need to be 'filled. ,. 'Badami #2 (PTD 191-. 144) was drilled .from an ice island; because we have no. documentation to confirm that there is no junk' or .equipment on. the sea' floor,, the sea floor needs tO be surveyed. .We :.can not confirm 20 AAC 25.17 Onshore LoCation Clearance or 20 AAC 25.172. Offshore Location Clearance of either well at this time. Sincerely; L-lc-co2bad.doc' Blair E. Wo'ndzell:P.~. x. 'Sr. Petroleum Engineer .- ' '~ .' 7/o7/2ooo · .PERMIT LOC CLEAR API NUMBER 191-144 5-NOT-CLEAR 029'-22230-00 189-117 5-NOT'CLEAR 029-22017-00 ALASKA WELLS LOCATION CLEARANCE STATUS WELL STATUS WELL N~E STATUS DATE TALLY OPERATOR BADAMI 2 P&A 4/13/1992 CONOCO INC BADAMI 1 P&A 4/27/1990 CONOCO INC PAGE '! of- oto~z~5~+ ;~ 7o . BP EXPLORATION Exploration Department Mr. David W. Johnston, Chairman Alaska Oil s, nd Gas Conserv2,tion Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Location Clearance Inspection - North Slope Wells BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 8 1994 , Dear Commissioner Johnston: Reference is made to your September 2, 1994 letter, a copy of which is attached for your reference. At this time BPX plans for the noted wells are as follows: 1) 2) 3) BPX Ekvik #1 - Our current plan is to inspect the well site post break-up (circa July, 1995) with the purpose of establishing the status of the marker post at the tundra level. Assuming the post is incorrectly positioned, we plan to return to the site in the Autumn (circa September or October) to rectify and make final clearance. BPX Fawn Lake #1 - Our plan is the same as noted for the Ekvik well."O~ Conoco Badami #1 - BPX assessment indicates ponding around the well / / I' location appears extensive and could possibly enlarge. Our plan is to monitor changes in 1995 and obtain necessary permits for filling the .depression in 1996-1997. If feasible we would prefer to perform this work in conjunction with Badami development gravel work. RrcC£1VrcD ~0V -9 1994' Oil & Gas Cons. Commissiot~ Anchor~j~ Letter- Mr. D.W. Johnston, AOGCC November 8, 1994 Page 2 of 2 Please advise should these plans not appear satisfactory or should you have any questions. Very truly yours, EPZ:Ibs cc: T. J. Obeney RECEIVED NOV -'9 1994 Alaska Oil & Gas Cons. Commission Anchom ,~ ALASKA OIL AND GAS ./ CONSERVATION COMMISSION / September 2, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEP 8 - 1994 Land Department (MB12-1) Pete Zseleczky, Mgr BP Exploration (Alaska) inc P O Box 196612 Anchorage, AK 99519-6612 Re: Location Clearance Inspections Eight (8) North Slope Wells. Dear Mr. Zseleczky: On August 24, 1994, our Inspector Lou Grimaldi accompanied Wade Srock, your reprensentaive, on location inspections of six BPX and two Conoco North Slope wells. Three of the wells were not ready for location clearance. On two BPX wells and one Conoco well he found problems on the locations to the extent that he could not recommend location clearance. The wells and the major problems are as follows: BPX Ekvik #1 PTD 89-020 Casing stub is 1-2' above tundra level. BPX Fawn Lake 1 PTD 90-013 Casing stub is level with the tundra. Conoco Badami #1 PTD 91-144 Depression 8-12' wide x 2-4' deep around weI1 location. Please advise the Commission as to your plans for these wells. Chairman ~ C: Rory Mayra, BP Environmental Blair Wondzell, PI Spvr, AOGCC RECEIVED NOV -' 9 1994 ~.~,~ska. Oil & Gas Cons. Commission Anchor;:. bew/1 lbpSnsw Steve C. Nicandro~ .Manager commercial Development Business Development ~xploration Production November 2, 1993 600 N. Dais/Ashford Rd. P. O. Box 2197, Oasis 3004 Houston, Texas 77252. Tel: (713) 293-279~ Fax: (713) 293-4414 BP Exploration Operating Company Limited Britannic House ! Finsbury Circus London EC2M 7BA Arm: Dr. Philip M. G. Nolan Manager, Acquisitions and D. isposals Gentlemen: RE: BP/CONOCO - U. S. ASSETS EXCHANGE Conoco Inc. ("Conoco") on behalf of itself and its affiliates hereby offers BP Exploration & Oil Inc. ('BPXO") on behalf of itself and its affiliate, BP Exploration (Alaska) Inc. (~BPXA") the sale and purchase of certain assets generally described below. The essential terms of the proposal are: 1. The Conoco assets to be acquired by BPXA or BPXO, as appropriate, are: (a) all of Conoco's undivided 64.38% working interest in the Milne Point Unit in Alaska and all the properties, both real and personal, relating thereto ("MPU"); (b) all of Conoco's interest ih the Milne Point Pipeline Company Partnership and all the properties, both real and personal, relating thereto ("MPPCP"); (c) all of Conoco's interest in the properties, both real and personal, relating to the acreage known as "the Badami area" in Alaska ("Badami"); (d} ali of Conoco's remaining North Slope Alaskan exploration acreage and the properties, both real and personal, relating thereto; and (e) all of Conoco's interest in thc offshore Gulf of Mexico deep water acreage comprised of the 54 blocks listed in Schedule A to this letter, except for a reserved overriding roya. lty interest in tracts MC 79, MC 123, MC 124 and MC 211, as more fully ~bed in Schedule C to this letter. APR 3 0 2DD2 '1 BP Exploration Operating Company Limited November 2, 1993 Page 2 . The following property is excluded from the Conoco assets to be transferred to BPXA and BPXO: (i) any Conoco property, not located on the North Slope of Alaska. except as provided in Section 3 of this letter: (ii) all seismic, geological, geophysical and geochemical information and data licensed from third parties, together with Conoco's proprietary interpretations of same; (iii) all of Conoco's intellectual property including but not limited to proprietary computer software, patents, trade secrets, copyrights, names, marks, and logos; and (iv) any other Conoco property of a kind or type not normally transferred as part of a sale of producing oil and gas properties. The BPXO assets to be acquired by Conoco are: (a) a thirty-three percent (33%) interest in BPXO's wholly-owned offshore producing asset known as Mississippi Canyon 109 ("MC 109"); (b) a thirty-three percent (33%) interest in BPXO's interest in Mississippi Canyon 108 ("MC 108"); and (c) associated interests in any related BPXO and its affiliates' transportation and infrastructure assets and arrangements as may be necessary to allow Conoco and its affiliates to produce and transport to points of sale its share of production from MC 108 and MC 109 on a basis equivalent to BPXO and its affiliates. . The following property is excluded from the BPXO assets to be transferred to Conoco: (i) any BPXO property located in the Gulf of Mexico, except as provided herein; (ii) all seismic, geological, geophysical and geochemical information and data licensed from third parties, together with BPXO's proprietary interpretations of same; (iii) all of BPXO's intellectual property including but not limited to proprietary computer software, patents, trade secrets, copyrights, names, marks, and logos; and (iv) any other BPXO property of a kind or type not normally transferred as part of a sale of producing .oil and gas properties. Except as otherwise specifically provided in this letter, the Conoco assets and the BPXO assets each include a proportional interest in all associated facilities, equipmeat, and other real and personal property (or a proportionate share thereof) associated with those assets, including: (i) all associated wells, platforms, pipelines, facilities, gathering systems, tanks, injection systems, salt water disposal systems or wells, f'~'tures, pipe, supplies, and equipment, located on or used in connection with producing, gathering, storing, measuring, transporting, treating, processing, managing, operating or otherwise handling the crude oil, condensate and gas production from the assets; (ii) all transferrable contracts and agreements affecting the assets and other real and personal property, including without limitation, gas sales contracts, processing agreements, farmins, farmouts, operating agreements, fight-of-way agreements, and surface leases affecting the assets; (iii) all proprietary seismic, geological, geophysical and geochemical data and information, provided, however, Conoco shall retain a license to use such data and information; and (iv) all other tangibles, miscellaneous interests or other assets on or used in connection with the assets, including without limitation, records, files, maps, and other information related to or used in connection with the assets. B~ Exploration Operating Company Limited November 2, 1993 Page 3 4. To the extent possible, this proposed transaction will be structured in such a manner as to avoid a nontaxable exchange. For the convenience of the parties, no existing tax partnership subject to the transaction will be terminated by either party, prior to closing. A mutually acceptable Joint Operating Agreement coveting MC 108 and 109 will be entered into by the parties upon closing. In addition, the parties agree that Conoco, for itself and as operator for the other owners in Mississippi Canyon Blocks 243, 199, 244, 245, 287, 288, 289, 290, and 333 and any other blocks with which said blocks may be unitized from time to time (~VIC 243 Area'), shall have the right, but not the obligation, to utilize the MC 108/109 platform and facilities and the pipelines associated therewith ('109 Facilities") for the handling, processMg, and transportation to the point of sale of all oil and gas production from the MC 243 Area, up to a level of 22,000 barrels per day of liquid hydrocarbons and 100 mmcfd of natural gas, commencing on or after January 1, 1998, under terms and conditions to be negotiated prior to the commencement of such usage. With the exception of third party usage for production from MC 108, (i) this tight shall be superior to any other third party usage tights in the 109 Facilities, and (ii) Conoco's consent shall be required before any other third parties may utilize the 109 Facilities for the benefit of any other blocks. The intent of the Conoco consent requirement is to ensure that all such third party usage is done at 'arm's length' and to ensure that such third party usage does not prevent Conoco from utilizing the 109 Facilities (existing at that time or which could be installed, given ..platform weight and space constraints) for the processing of its production from the MC 243 Area up..to the volume limits set out above. Conoco shall have an option, to be exercised prior to closing, to receive from BPXO a guarantee: (a) that Conoco will receive its thirty-three percent (33%) equity share of the MC 108/109 flowstreams set out in Schedule B to this letter; such that, in the event that production shall be less than that set out in Schedule B, BPXO shall make up' the difference in cash, based upon recognized hydrocarbon price indices, PROVIDED HOWEVER THAT if p'roduction shall exceed that set out in Schedule B, then Conoco shall make up the difference in cash based upon recognized hydrocarbon price indices; and (b) that Conoco's responsibility for the capital expenditures, operating costs, liabilities, transport costs and abandonment costs incurred by BPXO in operating MC 108/109 shall be thirty-three percent (33%) of those set out in Schedule B to this letter; such that, in the event that the same exceed thirty-three percent (33%) of those set out in Schedule B, Conoco shall have no liability in respect of the excess PROVIDED HOWEVER THAT if the same shall prove less than thirty-three percent (33%) of those set out in Schedule B, then BPXO shall be wholly entitled to the shortfall. The effective date for the proposed transaction is January 1, 1994. BPXA shall employ at least fifty (50) Conoco personnel currently associated with the ~ assets which are the subject of this letter. BPXA shall employ these Conoco Per~tmel at substantially equivalent wages and benefits. More detailed terms and eo~Etions of employment shall be negotiated as part of the definitive agreements ~g BP ~xt~l°rati°n Operating Company Limited November 2. 1993 Page 4 documenting this transaction- 9. This transaction is proposed subiecl to the [ollowing conditions: (a) The expeditious negotiation and execution by the parties o[ mutually ae.~ptable definitive agreements, conveyances (including special warranties of title given by the granting party), and other legal documentation necessary to give effect to thc transactions described above, in each case, with a view to closing, all such transactions not later than December 31, 1993, each party to bear its own expenses in negotiating and closing the transaction; having all reasonable access and opportunity to conduct a thorough due ests to be acquired by it (the parties Each party . -; ,~-e ~sets and/or inter .... ~- data and information (b) dill ence reme~. ~[ ,~'~ -- not reviewed the r,.ecu)_u'2, ,h~. 'assets during the .g_ .~A,,,, that ConOCO has _, ..~n be connrma, s acgllowt~'-'r~" _ ,-m~r~ ets eno wm .... *~ D~z~,~' aSS pertatmng tu negotiations); and (c) Compliance with all third parry fights, both governmental and non.governmental, concerning which the parties shall endeavor to obtain appropriate waivers or consen~ and compliance with all regulatory requirements, including anti-trust pre 'approvals under the Hart. Scott-Rodino Act. 10. The transaction contemplated by this letter is subiecl to and contingent upon management and appropriate board and partnership approvals o[ the parties. recognized that such approvals are not assured, and the parties understand that £allure obtain such approvals sh.all be without liability. It is £urther recognized that this lette~ not an agreement, and unless and until the a[orementioned transaction documentation been executed, neither party shall be bound or obligated to proceed in any whatsoever, and either party may terminate negotiations without liability at any time [or reason. to disclosure to 11. Both parties shall keep the existence and terms o[ this letter strictly confidentialcili or such earlier date as is mutually agreed upon, except aS necessary to £a closing, subsidiary or affiliated corporation or other affiliated entities parent, component transaction contemplated hereby. the overall and/or any mattel/~ it re uires acceptance a.n_d. 12. This proposal supersedes all prior communications concerning the subiecl expires at 12:00 noon CST on November 3, 1993, and o[ t¢~s proposal is valid t[ cie by BPXO to Conoco pdor to expiration- Acceptance by personal delivery, telex, telecoPY or similar [ac. simile means or by courier or service. Nov¢ .q PageI If th. retur -~ CO? ' Prt BF T~ ~BP Exploration Operating Company Limited · November 2, 1993 Page 5 If the above is acceptable, please sign the enclosed duplicate in the space provided below and · return it to this office within the time period specified above. Very. truly yours, CONOCO INC. Steve C Nlcandros Manager Commercial Development Proposal accepted this BP EXPLORATION & OIL INC. Name: ~e~. x day of November, 1993 Schedule A-1 Conoco Leases o Alaska ADL/ WORKING NET ' CONOCO OCS DATE OF INTEREST REVENUE LEASE NO. NO. LEASE LESSOR LESSEE 96 INTEREST % DESCRIPTION , , ' ' '"" BADAMI::PROSPECT i 22236g-000 367005 05101186 State of Conoco Inc. 66.671 58.331 Tract 48A-05 Alaska T. 10 N.. R. 19 E Sec 25: All Protracted (640 acs) Sec 26: All unsurveyed tide and submerged lands (258 acs); Sec 27: All unsurveyed tide and submerged lands (207 acs);.,.,~.. Sec 34: All unsurveyed tide and submerged lands 1171 acs) Sec 35: All unsurveyed tide and submerged lands {110 acs)' Sec 36: All unsurveyed tide and submerged lands {523 acs); .T. 10 N., R. 19 E.(Tract A) Sec 26: All unsurveyed, fractional (382 acs); Sec 27: All unsurveyed, fractional (433 acs); Sec 34: All unsurveyed, fractional (469 acs); Sec 35: All unsurveyed, fractional (530 acs); Sac 36: All unsurveyed, fractional (117 acs) 222370-000 367006 05/01186 State of Conoco Inc. 66'67~ i 58.33~ Tract 48A-06 Alaska T. 10N.. R. 20E. Sec 17: All Protracted (640 acs); Sec 20: All Protracted (640 acs); .. Sec 29: All Protracted (640 acs); Sec 30: All Protracted {620 acs); ~,~_ Sac 31: All Protracted (623 acs); Sac 32: All Protracted (640 acs); Sec 18: All unsurveyed tide & submerged lands (569 acs); Sec 19: All unsurveyed tide & submerged lands (603 acs); T. 10 N.. R. 20 E.(Tract Al Sec 18: All fractional unsurveyed (46 acs); Sec 19: All fractional unsurveyed (14 acsl, A-1-4 PERMIT DATA ( ~ AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 91-144 CORE CHIPS DST #1 AIT AIT AIT CAL DGR/EWR/FXE C 10730-10789,SS#827 D 6 DISKS L 5345-11425,TVD L 5805-11850 L 5805-11850, COLOR L 5805-11826, COLOR 487-11406, MWD-TVD DGR/EWR/FXE/TEM L 487-11860, MWD-MD EPM FMI LDL/NL (RAW) LDT/NL (PORO) LDT/NL (PORO) LDT/NL (PORO) LDT/NL (RAW) LDT/NL (RAW) LSS LSS LSS MCT MUD MUD NGT NGT NGT/SPEC PDT PIL/LDT/NL L 430-11860, MD (2 R&S) L 5815-11826 L 400-11862 L 400-11862 L 445-11424, TVD L 5805-11862, COLOR L 445-11424, TVD L 5805-11862, COLOR L 400-11802, MD L 447-11354, TVD L 5805-11802, COLOR L 5805-11730 L 430-11860, MD (2 R&S) L 430-11860, TVD (2 R&S) L 5320-11425, TVD L 5805-11833 L 5805-11833, COLOR L 430-11390, TVD (2 R&S) L 400-5820, MD L 400-2400 Page: 1 Date: 05/16/94 RUN DATE_RECVD 04/23/92 05/22/92 2 05/15/92 2 05/15/92 1 05/15/92 1 05/15/92 5-14 06/26/92 5-14 06/26/92 06/26/92 2 05/15/92 1-2 05/15/92 1-2 05/15/92 1-2 05/15/92 I 05/15/92 1-2 05/15/92 1 05/15/92 1-2 05/15/92 1-2 05/15/92 2 05/15/92 2 05/15/92 06/26/92 06/26/92 2 05/15/92 2 05/15/92 1 05/15/92 06/26/92 1 05/15/92 1 05/15/92 PERMIT DATA ---- 91-144 PIL/MSFL 91-144 PIL/SFL/MSFL 91-144 PIL/SFL/MSFL 91-144 SHDT 91-144 91-144 91-144 91-144 91-144 ('i ~OGCC Individual Well Geological Materials Inventory T DATA_PLUS L 5805-11856, MD COLOR L 400-11856 L 445-11405,TVD L 5815-11896 USIT L 150-5800, COLOR 407 R COMP DATE: 04/13/92 CORE ANALYSIS R 10560-10856, & DESCRIPTN CORE ANALYSIS R 10730-10789, CONV. CORE DESCRIPTION R 10730-10790, CONV. 91-144 DAILY. WELL OP 91-144 DST #1 91-144 SURVEY 91-144 DRY DITCH 91-144 5263 91-144 5303 91-144 5304 * R 02/07/92-04/05/92 R 10494-11082 R 415-11860 S 430-5785,SS#827 T 445-11880, OH-DITE T 5775-11845, T 418-11860, EXLOG LIS Page: 2 Date: 05/16/94 RUN DATE_RECVD -------- 2 05/15/92 1-2 05/15/92 1-2 05/15/92 2 05/15/92 2 05/15/92 04/28/92 06/26/92 07/09/92 07/22/92 04/28/92 05/22/92 04/28/92 02/24/92 1-2 05/15/92 06/26/92 06/26/92 Are dry ditch samples required? ,..yes~)no And received? Was the well cored? ~no Analysis & description received? no Are well tests require~no Received? .~~ no Well is in compliance Initial COMMENTS RMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 03/31/94 RUN DATE_RECVD L 5345-11425,TVD -144 AIT L 5805-11850 2 -144 DGR/EWR/FXE -144 -144 -144 FMI -144 LDL/NL (RAW) -144 LDT/NL (PORO) -144 LDT/NL (PORO) -144 LDT/NL (RAW) -144 LSS -144 LSS -144 MCT -144 MUD -144 MUD -144 NGT" -144 NGT -144 -144 -144 -144 -144 -144 -144 -144 D 6 DISKS L 487-11406, MWD-TVD DGR/EWR/FXE/TEM L 487-11860, MWD-MD EPM PDT PIL/ASL PIL/LDT/NL PIL/SFL/MSFL PIL/SFL/MSFL SHDT 407 C~ ANALYSIS L 430-11860, MD (2 R&S) L 5815-11826 2 L 400-11862 1-2 L 400-11862 1-2 L 445-11424, TVD 1-2 L 445-11424, TVD 1-2 L 400-11802, MD 1-2 L 447-11354, TVD 1-2 L 5805-11730 2 L 430-11860, MD (2 &as) L 430-11860, TVD (2 Ras) L 5320-11425, TVD 2 L 5805-11833 2 L 430-11390, TVD (2 RRS) L 400-5820, MD 1 L 400-2400 1 L 400-11856 1-2 L 445-11405,TVD 1-2 L 5815-11896 2 R COMP DATE: 04/13/92 5-14 5-14 04/23/92 05/22/92 05/15/92 05/15/92 06126/92 06/26/92 06/26/92 05/15/92 05/15/92 05/15/92 05/15/92 05/15/92 05/15/92 05/15/92 05/15/92 06/26/92 06/26/92 05/15/92 '05/15/92 06/26/92 05/15/92 05/15/92 05/15/92 05/15/92 05/15/92 04/28/92 06/26/92 -144 DST #1 -144 AIT -144 JTA4t"F~ C6w'~ o~k.~ C 10730-10789 ~.J~' f'Z..7 mmmmmmm mmmmmmmmmmmmmmmm m mmmmmmmmmmmmmmmmmmmmmmmmm mmmm mmmmmmmmmm RMIT -144 .-144 -144 AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS RUN DATE_RECVD CORE ANALYSIS R 10730-10789 CORE DESCRIPTION R 10730-10790 DAILY WELL OP R 02/07/92-04/05/92 -144 DST #1 P age: 2 Date: 03/31/94 - ! 44 SURVEY -144 DRY ~JJW-T~-N~S R 10494-11082 R 415-11860 S 430-5785,SS#827 -144 5263 T 445-11880, OH-DITE 1-2 -144 5303 -144 5304 * T 5775-11845, T 418-11860, EXLOG LIS 07/09/92 07/22/92 04/28/92 05/22/92 04/28/92 02/24/92 05/15/92 06/26/92 06/26/92 :e dry ditch samples required? .~~ no And received? ~ no ~s the well cored? ~ no Analysis & description received? ~ no :e well tests require~ no Received~ no ~11 is in compliance ~ Initial ,mments STATE OF ALASKA Alaska Oil Gas Conservation Commission Anchorage, Aiasl[a 99501-3192 CONFIDENTIAL DATA FIELEASF Thc AOGCC will release confidential well data to authorized DNRIDOG employees. All data is to be inventoried prior to release and a copy of the inventory given to the DNR/DOG employee. · · 01) Permit to Drill (40i]: pages 02} Completion Repofl (407]' , ,~..~--, pages 03) Daily Drilling History: ~' pages 04) Directional Surveys: 7 pages ! 051 Drill Stem lests: ~~:~~_... ~ 061 Core Analysis Repnfl: / '2-pages -" 071 Core Description: pages 081 Digital Data: reels 09] Formation Picks! ~6 7'pages 10) Bluelines: logs [list below) OTHER ,, , LOG WPE INTERVAL RuN 11 SCALE , / TODAY'S DATE' The under-signed B~V~d employee hereby accepts receipt of the above listed confidential materials, Print and sign your name below. -- . -- II . . I I ii Facsimile Cover Sheet To: Company: Phone: Fax: From,' Company: Phone= Fax: LARRY GRANT Alaska D.N.R. Oil & Gas Conservation Comm. 907-279-1433 907-276.7542 Timothy O. Ryherd Alaska D.N.R. - Division of (907)762-2140 (907)562-3852 Date: 06/10/g3 Pages including this cover page: I Larry, I request Ihe following well data be prepared for me to pickup as soon as possible. Thanks for your help. , BP Cascade #1 (93-00D1)-all well logs, well history, completion report, horizon pic~, directional surveys, core descriptions & analyses, & production tests. BP Cascade #lA (93-0041)--all well logs, well history, completion report, horizon picks, directional surveys, core descriptions & analyses, & production tests. · Conoco N.W, Milne Pt. #1 (gJ-0145)-all well logs, well history, completion report, horizon picks, directional surveys, core descriptions & analyses, & Production tests. Conoco Badami #2 (91-0144}--all well logs, well history, completion report, horizon picks, directional surveys, cote descriptions & analyses, & production tests. ARCO N..Prudhoe Bay State #3 (92-0145)-all well logs, well history, Completion report, horizon p~cks, directional surveys, core clesoriptions & analyses, & pmdu=lion tests. · .A..RC.O. Tu!aga #1 (93.0010).-ali well logs, well history, completion report, horizon picks, oireotiona~ surveys, core descriptions & analyses, & production tests. · ARCO Jones Island #1 (92-0140)-all well logs, well history, completion report, horizon picks, directional surveys, core descriptions & analyses, & production tests. Exxon Thetis Island #1 (g3-0021)--all well logs, well history, completion report, horizon picks, directional surveys, core descriptions & analyses, & production tests. · ARCO Kuukpik #3 (92-0138)--all horizon picks and production tests. · ARCO CoMIle River #1 (92-0153).-all core descriptions & analyses, 'ON Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 July 20, 1992 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: Enclosed is the document which you reqUested from Conoco's Badami No. 2 well. I[ Badami No. 2 I' APl No. 50-029-22230. Permit No. 91-144 Core Description All data from the above referenced well is CONFIDENTIAL and should· be handled accordingly. To confirm arrival of the data, please sign the attached copy of this letter and return it tO me. . , Should you have any questiOns, telephone me at (907) 564-7640. · ~' '~o~,~9~ °" File: Badami #2 BADAMI ~2 Core ~1: 10,730' - 10,790' ORIGINAL 10,730.0' - 10741.3' Sandstone (60%) & Siltstone (40%) 10,741.3' - 10,748.7" Sandstone, dark brown to black, very fine grained, friable to firm, fair sorting, angular to subangular, silty. Massive (?) basal sands grade into laminated to very thinly laminated siltstone. 0.4 ' to 1' thick. Siltstone, gray to black, very thinly laminated with occasional interbedded sandstones. Uppermost siltstone beds often scoured. Sandstone-siltstone sequences are found in stacked, discrete fining upwards units. Individual units are 1' to 2' thick, display occasional rip up clasts near the base and scoured upper surfaces. Sandstone' (50%) & Shaley Siltstone (50%) Sandstone, as above, friable, slightly calcareous. 0.1' to 0.4' thick. Siltstone, as above, increasing shaliness. 10,748.7' - 10,758.2' Sandstone (10%) & Shaley Siltstone (90%) Sandstone, as above. Siltstone, gray, firm to hard, thin to very thinly laminated, increasing shall'ness, graded in part, with wavy to even laminae. 10,758.2' - 10,765.1' Sandstone (50%) & Shaley Siltstone (50%) Sandstone, black, very fine to fine, subangular, fair sorting, friable to firm, numerous thin shale laminae. 0.1' to 1.0' thick. 10,765.1' - 10,771.0' Siltstone, light gray to gray, even, parallel laminae, shaley, increasingly sandy, and calcareous in places. Sandy siltstone (100%) Siltstone, light gray to gray, thinly to very thinly laminated, occasional sandy streaks, few sedimentary structures. 10,771.0' - 10,790' Sandstone (30%) and Siltstone Sandstone, black, very fine to fine, subangular, fair sorting, friable, laminated. Sand units are .2' to .6' thick. Siltstone, as above. FROM COHOCO NNC ENG/E,V, pL PAGE. 001 CONOCO INC. REQUEST FOR FACSIMILE DATE: FROM: CITY/STATE: .lul;y 20, 1992 Stephen F. Davies Anchorage, Alaska O R l l ,rf ,4 TO: Larry Giant CONPANY: Alaska 0il & Gas Conservation Commission CITY/STATE: Anchorage, Alaska FAX #: 276-7542 NO, OF PAGES: COVER + 1 RECEIVED JUL 2 0 1992__ AlasKa u~t & Gas Cons. Commission Anchorage FAX REPLY NUHB£R: (907) Please notify aY secretary, Linda Stair, at (907) 564-7811 if transmission is incomplete ot illegible. JUL 9 '92 10:22 FROM CONOCO ANC ENG/EXPL PAGE.00~ Conoco Inc. 3201 C Street, Suite 200 (9O7) 564760O July 9, 1992 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: Enclosed are data from the Badarni ~2 well, located in Section 30, TION, R20E on the North Slope of Alaska., The APl number for this well is 50-029-22230. The.following is a list of the data being transmitted:' · ~C:~ An.l.I.R.urm" (Core Laboratories) Analysis Report (Petroleum Testing Service) These and all other data from the Badmai ~2 well are CONFIDENTIAL and should be handled accordingly. To confirm arrival of these data, please sign' the second copy of letter and return it to me at the letterhead address. Should you have any questions, telephone me at 564-7640, Sincerely, Steve Davies Staff Geologist Conoco Inc. File: 1111.03 Geological File Nasl~ 0ii & Gas Cons. Commission Anchorage .J'UL 9 '92 10:21 FROM CONOCO ANC ENG/EXPL PAGE.001 CONOCO INC. REQUEST FOR FACSIMILE DATE: FROH: CITY/STATE: July 9, 1992 Steve Davtes Anchorage, A1 aska TO: Larry Grant COHPANY: Alaska 0tl & Gas Conservation Commission CITY/STATE: Anchorage, Alaska FAX #: Z76-7542 NO. OF PAGES: COVER + 1 3 SPECZAL ]rNSTRUCTIONS: RECEIVED L o 91992 & Gas Cons, Commission Anchorage FAX REPLY NUNBER: (g07) 564-7655 Please notify my secretary, Ltnda Start, at (907) 564-7611 tf transmission is Incomplete or 11legible. Conoco Inc. 3201 C Street. Suite 200 Anchorage. AK 99503-3999 (907) 564-7600 June 26, 1992 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: RECEIVED JUN 2 6 1992 Alaska 0il & Gas Cons. Commission Anchorage Enclosed are the following documents which you requested from Co. noco's Badami No. 2, Sequoia No. 1 and NW Milne No. I wells. Badami No. 2 APl No. 50-029-22230 Permit No. 91,144 ,,C'0re Analysis Report and Mud Logs (detailed on the attached list) These and all other data. from the above referenced wells are CONFIDENTIAL and should be handled accordingly. To confirm, arrival of the data, please sign the attached copy of this letter and return it to me. Should you have any questions, telephone me at (907) 564-7640. Sincerely, Staff Geologist Conoco Inc. 3201 C Street, Suite 200 Anchorage. AK 99503-3999 (9O7) 564-7600 June 26, 1992 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: Enclosed are the following documents which you requested from Conoco's Badami No. 2, Sequoia No. I and NW Milne No. 1 wells. Badami No. 2 Sequoia No. I NW Milne No. I APl No. 50-029-22230 Permit No. 91-144 APl.No. 50-029-22226 Permit No. 91-136 APl No. 50-029-22231 Permit No. 91-145 Core Analysis Report and Mud Logs (detailed on the attached list) Core Analysis Report (Sidewall Core) Core description and Core Analysis These and all other data from the above referenced wells are CONFIDENTIAL and should be handled accordingly. To confirm arrival of the data, please sign the attached copy of this letter and return it to me. :, Should you .have any questions, telephone me at (907) 564-7640. Sincerely, , ' ' RECEIVED Staff Geologist JUN 2 6 1992 Alaska 0il & Gas Cons. C0mmissi0n Anchorage CONOCO INC. BADAM! #2 Badami ~' 2, Wildcat AP1#50-029.-22230 26-June-92 IIState of AK WELL LOG I RUN I DATE I SCALE I MD/TVDI TOP I BASEI TYPE # Petroleum Testing Service: Core Analysis Report Apr-92 Report 1 Exlog: Formation Evaluation Log v'/' 5-Apr-92 2" = 100' MD 430 11,860 Blueline 1 Exlog: Formation Evaluation Log ,.."/ 5-Apr-92 2" = 100' TVD 430 11,390 Blueline 1 Exlog: Engineering Parameters Log ,.,/ 2" = 100' MD 430 11,860 Blueline 1 Exlog: Pressure Data Log 1:6000 TVD 430; 11,390 Blueline 1 Sperry-Sun: MWD - DGR/EWR/FXE/TEM v/ !1 - 14 21-Mar-92 2" & 5" MD 487 11,860 Blueline 1 Sperry-Sun: MWD - DGR/EWR/FXE v/ I -14 21-Mar-92 1" & 2" TVD 487 11,406 Blueline 1 Exlog: Formation Evaluation Log ,."" 5-Apr-92 2" = 100' MD 430 11,860 Sepia 1 Exlog: Formation Evaluation Log ,.// 5-Apr-92 2" = 100' TVD 430 11,390 Sepia 1 Exlog: Engineering Parameters Log ~/ 2" = 100' MD 430 11,860 Sepia 1 Exlog: Pressure Data LOg /"~/ 1:6000 TVD 430 11,390 Sepia 1 Sperry-Sun: MWD - DGR/EWR/FXE/TEM~ I - 14 21-Mar-92 2" & 5" MD 487 11,860 Sepia 1 Sperry-Sun: MWD - DGR/EWR/FXE ~ I - 14 21-Mar-92 //~* & 2" TVD 487 11,406 Sepia 1 / Exlog' Formation Evaluation Log v' 5-Apr-92 / 2" = 100' MD 430 11,860 Rim ~ 1 Exlog: Formation Evaluation Log ~" 5-Apr-92 / ,,, 1:600 TVD 430 11,390 Rim %.,%~ ~' 1 Exlog. Engineering Parameters Log u,," RE£EiVED / Exlog: Pressure Data Log ~ ~~1:6000 TVD 430 11,390 Film'~- 1 ExlogData, LIS1600bpi .~ ~"',~~ ,/'~/ 418 11,860 Mag. Tape 1 Sperry-Sun: Tape No. 1 (With Verification Listing) ,,,' /[l~eE.~ 13ii ~r~q3bn§.2Commtssior 5,775 11,845 Mag. Tape 1 -~' ~""3 o ~ ........... Anchorage APPROV RECEIVE ~',.,onoco Inc. Anchorage Division ~"..acord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Date From Jim Hand Conoco Inc. 3201 C Street, Suite 200 May 22, 1992 Anchorage, Alaska 99503 (907) 564-7645 Via Petroleum Couriers Subject Wildcat, Badami #2 APl #50-029-22230 TIGHT HOLE · Quantity Contents Well Test Analysis 3/29/92 (Halliburton Reservoir Services) DST #1 Interval: 10494'-- 11082' RECEIVED MAY 2_ 2 1992 Alaska 0il & 6as Cons. Commission Anchorage Signed By Transmittal Approved By ,/."~ ,~ _ Date 'Instructions: Please ackn~l~'dge"~ receipt promptl" y by signing and returning second copy. Received By ~ ~ Date Remarks May 22, 1992 Transmittal Copy Only To _ ~alka ,'/ . -i .-._: .- '"'RECEIVED MAY 1 5 1992 ~dam~ ~2, ~ldcat APl ~50-029-22230~ ~ r ~~ D. se. to 8~ of AK ~oa I,RUN I DA~ J SC~ I MD~I TOP I BASE I ~E II · En~m~ P~ Ind~on ~my 8on~ (Amlo~ / 1 ~O-Feb-~ 1', ~', 5' MD ~ ~0 BI~I~ 1 En~ P~ In~on L~ Dens~-Ne~on / .~1 ~O-Feb-~ 1', ~', 5' MD ~ ~ BI~ 1 ~mylnduc~nLog~elim~Log-SmRe~ ~ 1 Z1-~-92 ~ MD ~ 11~ C~ / 1 L~oDem~-Ne~on ¢ORO~I~ ~ 1 ~1-~-~ 1',~,]' MD ~ 11~ C~ / 1 Long 8~cing Sonic CD~ A~og De~ ~me ~ 2 21 -~-~ 1", 2", 5" MD 5,~5 11 ,~2 C~~ 1 U~a Sonb I~, Cement and C~ion ~ 2 21 -~-92 5' MD 1~ 5,8~ Col~ ~ 1 Nraylndu~onLog ~elim~ryLog-S~Re~ ~2 21-~-g2 1%2',5" MD 5,~5 11,~ Bluelbe 1 Nray Indu~on Log ~elim~y Log ~ 2 21 -~-92 1", 2" ~D 5,~ 11 ,~5 Bluelbe 1 ~ral ~m~ ~y S~om~y Log ~ 2 21 -~-92 1', 2", 5' MD 5,~ 11,~ Bluelbe 1 ~ral ~m~ ~y S~om~ Log ~ 2 21-~-92 1', 2' ~ 5,~0 11,~5 Bluelbe 1 F~fion Milo I~g~, I~ and Dipm~ Mo~s ~2 21 -~-92 .... 5' MD 5,815 11 ,~6 Bluelbe 1 S~afl~apN~ High-Re~l~n Dip~ ~ 2 21 -~-92 5" MD 5,815 11,8~ Bluelbe 1 M~ni~l Coring T~I ~ 2 21 -~-g2 MD 5,~5 11,7~ Bluelbe 1 / P~ Indu~o~FL-MSFL ~n~ed ~sin~t ~ & 2 20-Feb-~ & 21 -~r-92 1', 2', 5' MD ~ 11~6 Bluelbe 1 P~ Indu~o~FL-MSFL (E~need ~sin~ ~& 2 20-Feb-~ & 21 -~-92 1', 2' ~D ~5 11405 Bluelbe 1 L~oDem~-Neu~on ~AWDAT~ ~ I &2 20-Feb-~ & 21-~r-g2 1',2',5" MD ~ 11~2 Bluel~ 1 L~oDem~-Ne~on (~WDAT~ ~ I &2 20-Feb-~ & 21-~-92 1",2' ~D 4~ 11424 Bluelbe 1 L~o Dem~-Neu~on (POROSI~ ~ I & 2 20-Feb-~ & 21 -~-g2 1", 2', 5" MD 4~ 11~ Bluelbe 1 LEho Dem~-Ne~on (PORO81~ ~ I & 2 20-Feb-~ & 21-M~-92 1% 2' ~D ~ 11424 Bluelbe 1 Long S~ing Sonic CD~ A~og Del~ ~me ~' I & 2 20-Feb-~ & 21-M~-92 1', 2", 5' MD 4~ 11~ Bluelbe 1 LongS~cingSonic(SD~A~ogDe~me ~ 1 &2 20-Feb-~ & 21-~-92 1',2' ~D ~7 11~ Bluelbe 1 En~ced P~ Ind~on Nmy Sonb (~1o~ ~ /1 20-Feb-~ 1', 2% 5' MD ~ ~0 Sep~ 1 En~eed P~ Ind~on L~ Densi~-Ne~on ~ / ,1 20-Feb-~ 1", 2', 5" MD ~0 2~ Sepb 1 Nraylndudi~Log ~elim~Log-S~Re~./2 21-~-~ 1',2%5" MD 5,~5 11,850 Sep~ 1 NraylndudionLog Prelim~yLog ~ 2 21-~-~ 1",2' ~ 5,~5 11,~5 Sep~ 1 ~ral~m~yS~om~Log ~ 2 21-~-~ 1",2',5' MD 5,~5 11,~ Sepb 1 Natuml~m~yS~om~yLog ~ ~ 2 21-~-~ 1",2' ~ 5,~0 11,~5 Sepb 1 Fm~on Milo '1~, I~ and Dipm~ Mo~ ~ 2 21 -~-92 5' MD 5,815 11 ,~6 Sep~ 1 S~ati~apNc High-R~ol~n Dipm~ ~ 2 21 -~-92 5' MD 5,815 11,8~ Sep~ 1 M~ni~l C~i~ T~I ~ 2 21 -~-92 MD 5,~5 11,7~ Sep~ 1 P~ Indu~o~FL-MSFL (E.~nced,~in~/1 & 2 20-Feb-92 & 21 -~-~ 1', ~, 5' MD 4~ 11~ Sep~ 1 ,P~ Indu~o~FL-MSFL (E~nced ~in~- ~ & 2 20-Feb-g2 & 21-~-92 1', 2' ~D ~ 11405 Sep~ 1 L~oDem~Ne~on ~WDAT~ ~ 1 &2 20-Feb-~ & 21-~-g2 1%2%5" MD ~ 11~ Sep~ 1 L~oDem~-Neu~on ~AWDAT~ ~ 1 &2 20-Feb-g2 & 21-~-g2 1',2' ~D ~5 11424 Sepb 1 L~oDem~-Ne~on (PORO8I~ ~ 1 &2 20-Feb-~ & 21-~-92 1',2",5' MD ~ 11~ Sep~ 1 Li~o Demi~-Ne~on (POROSI~ ~ I & 2 20-Feb-g2 & 21 -~-~ 1', 2' ~D ~5 11424 Sep~ 1 LongS~cingSonie¢D~A~ogDe~me ~ I &2 20-Feb-92 & 21-~-~ 1',2",5' MD 4~ 11~2 ,Sep~ 1 Long S~ing S~i= CD~ A~og De. Time ~ I & 2 20-Feb-g2 & 21-~-~ 1', 2' ~D ~7 11~ ~Sep~ 1 DITE/MSFL/I. SS/LDT/CNL/NGT/PROCESSED AlT '/ I & 2 21 -Mar-92 445.5 11,880.5 Mag. Tape LIS listing for magnetic tape .i~ ..~,~ ,//' 1 & 2 21 -Mar-92 .~44'~t~11~8~0~ I1~ listing " Di:( I-IV t'U APPROVED: ~' RECEIVED BY: J"'" Alaska Oil & Gas r~ Anchorage ~,onoco Inc. Anchorage Division ~r' acord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 Enclosed [] Under Separate Cover Date From Jim Hand Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 (907) 564-7645 May 15, 1992 Via Petroleum Couriers Subject Wildcat, Badami #2 APl #50-029-22230 TIGHT HOLE Quantity Contents Well logs and magnetic tape per the attached list. Transmittal Approved By Signed By Date Instructions: Please ackn~mptly by si~l~nd returning second copy. Received By ~ / ~ Date Remarks ~ ¢/ ~ ~ 15, ~992 RECEIVED MAY 1 5 Transmittal Copy Only To A~.-<ka 011 & ~a~ Cons. Commission Anchorage May 4, 1992 Ms. Cathy Girard Alaska Department of Environmental Conservation State Pipeline Coordinator's Office 411 West 4th Avenue, Suite 2C Anchorage, AK 99501 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (9O7) 564-7600 (~OMM' ?/~ COMM COMM RES ENG SR ENG SR ENG ENG ASST ENG ASST SR GEOL/~ GEOL ASST GEOL ASS'~ STAT TECH · STAT TECH FILE RE: CONOCO INC. ACCIDENTAL DISCHARGES Dear Ms. Girard: ~.~/~,~ ~ Please be advised that there were no accidental discharges for the period of April 26 - May 2, 1992. Attached, however, are discharges that occurred during the period of April 14 - April 19, 1992. These discharges were not reported to our Anchorage Office until April 29, 1992 and were therefore not included in previous weekly reports. These discharges occurred at the Badami Exploratory Project. Conoco apologizes for any inconvenience the late reporting causes. If you require additional information you can contact me at 564-7617. Yours very truly, Bob Soptei Environmental Coordinator RJS/bgs Attachments CC Mr. Blair Wondzell, AOGCC Mr. Ralph Davis, NSB Mr. Frederick L. Smith, DNR Mr. Carl Lautenberger, EPA Field Safety, Training and Compliance Coordinator, MPOC File 500.01 \RJS\DISWEKS0.RJS RECEIVED ALASKA DEPARTMC_NT OF ENVIRONMEN'"AL CONSERVATIL,, OIL & HAZARDC ~S MATERIALS INCID~. ~T NOTIFICATION FOR OFFICIAL USE ONLY ,= FILE# CLOSURE' Final Report Date' Closure Date' Closure authorized by- .i PERSON REPORTING Joe Poyla (Conoco) RESPONSIBLE PARTY (COMPANY NAME) Cold Weather Contractors/Conoco DATE/TIME OCCURRED 4-19-92; 8:00 a.m. PHONE (9071 659-6452 TYPE OF NOTIFICATION 1st party 2nd party X. 3rd party. DATE/TIME REPORTED KNOWLEDGE OF SPILL 4-19-92; 9'00 a.m. 4-19-92; 9'00 a.m. INCIDENT DETAILS LOCATION Badami Exploratory Well No. 2; Cuttings Dump Pad PRODUCT TYPE Hydraulic oil QUANTITY SPILLED 5 9al 1 ons QUANTITY CONTAINED 100% QUANTITY RECOVERED 100% QUANTITY DISPOSED 100% SOURCE OF SPILL Maxi haul dump truck. CAUSE OF SPILL Broken fitting on hydraulic line. STATUS OF CLEANUP CLEANUP ACTIONS Cleaned up contaminated ice/snow with shovels/loader and placed into red trash bags. DISPOSAL METHODS Disposed of the red trash bags into dumpster (less than 10% by volume) for disposal at the NSB disposal facility. ENVIRONMENTAL DAMAGES YES NO X SURFACE AREA (Sq. FT.) 60 sq. ft. SURFACE TYPE (GRAVEL PAD, ETC.) Ice pad; contained on the pad. REMEDIATION ACTIONS None, recovered 100% of material down to clean ice. CONHENTS None. PREPARED BY Joe Poyla/Bob Soptei DATE 4-20-92/5-4-92 ,LASKA DEPARTMFNT OF ENVIRONMEI .?TL CONSERVATION OIL & HAZARD S MATERIALS INCIDI[. NOTIFICATION SPILL# FILE# CLOSURE- Final Report Date: Closure authorized by: FOR OFFICIAL USE ONLY Closure Date- PERSON REPORTING Joe Poyla (Conoco Inc.) RESPONSIBLE PARTY (COHPANY NANE) Nabors Alaska Drillin~l/Peak/Conoco DATE/TINE OCCURRED 4-14-92; 10:00 p.m. PHONE (907) 659-6452 TYPE OF NOTIFICATION 1st party 2nd party X 3rd party DATE/TIHE REPORTED KNOWLEDGE OF SPILL 4-15-92; 6-00 a.m. 4-15-92; 6:00 a.m. INCIDENT DETAILS LOCATION Badami Exploratory Well No. 2 ice pad. PRODUCT TYPE Hydraulic Oil QUANTITY SPILLED 3 gallons QUANTITY CONTAINED 100% QUANTITY RECOVERED 100% QUANTITY DISPOSED 100% SOURCE OF SPILL 96.6, front end loader (Peak leased to Nabors). CAUSE OF SPILL Leak in hydraulic line fitting. STATUS OF CLEANUP CLEANUP ACTIONS ' Removed all material and contaminated ice with loader and shovels. DISPOSAL NETHODS' Placed recovered material in cuttings bucket. Peak melted material and washed down the cuttings bucket. Peak then recovered the liquid with a vacuum truck and disposed of the material at BP's CC-2 disposal facility. ENVIRONNENTAL DANAGES SURFACE AREA (sq. FT.) SURFACE TYPE (GRAVEL PAD, ETC.) YES NO X 50 sq.ft Ice pad; contained on the pad. REHEDIATION ACTIONS None, recovered 100% of material down to clean ice. COHMENTS None. PREPARED BY · Joe Poyla/Bob Soptei DATE 4-20-92/4-30-92 ALASKA DEPARTM.r-NT OF ENVIRONMENT a, L CONSERVATIOns. OIL & HAZARDO,,..$ MATERIALS INCIDE,. I' NOTIFICATION SPILL# FILE# FOR OFFICIAL USE ONLY CLOSURE- Final Report Date: Closure authorized by: C1 osure Date- PERSON REPORTING Joe Poyla (Conoco Inc.) RESPONSIBLE PARTY {COMPANY NAME} Nabors Alaska Drilling/Conoco Inc. DATE/TIME OCCURRED 4-15-92/2:00 a.m. PHONE (907) 659-6452 ITYPE OF NOTIFICATION . 1st party 2nd party X 3rd party DATE/TIME REPORTED KNOWLEDGE OF SPILL 4-15-92/7:00 a.m. 4-15-92/7'00 a.m. INCIDENT DETAILS LOCATION Badami Exploratory Well No. 2 ice pad. , PRODUCT TYPE Motor Oi 1 QUANTITY SPILLED 10 gallons QUANTITY CONTAINED 100% QUANTITY RECOVERED 100% QUANTITY DISPOSED 100% SOURCE OF SPILL SDU (sewerage) plant. CAUSE OF SPILL Drip Pan knocked over during camp move. STATUS OF CLEANUP CLEANUP ACTIONS Cleaned up all oil, contaminated snow, and removed contaminated ice until clean ice with shovels and front end loader. Placed recovered material in barrel. DISPOSAL METHODS Washed out drip barrel at Peak wash bay, sucked up recovered material into vac truck, and disposed of at BP's CC-2 disposal facility. ENVIRONMENTAL DAMAGES SURFACE AREA (SQ. FT.) YES NO X 30 sq. ft REMEOIATION ACTIONS No~e, recovered 100% of material down to clean ice. SURFACE TYPE (GRAVEL PAD, ETC.) Ice Pad; contained on the pad. COMMENTS None. PREPARED BY Joe Poyla/Bob Soptei DATE 4-20-92/5-4-92 -~LASKA DEPARTIVl/CN, T OF ENVIRONMENc~.AL CONSERVATI.O'N OIL & HAZARDG .~ MATERIALS INCIDI',..T NOTIFICATION FOR OFFICIAL USE ONLY FILE# CLOSURE: Final Report Date: Closure Date: Closure authorized by: PERSON REPORTING Joe Poyla (Conoco) RESPONSIBLE PARTY (COMPANY NAME) Cold Weather Contractors/Conoco OATE/TINE OCCURRED 4-15-92; 1:00 p.m. PHONE (907) 659-6452 TYPE OF NOTIFICATION 1st party 2nd party X 3rd party DATE/TIME REPORTED KNOWLEDGE OF SPILL 4-15-92; 1:30 p.m. 4-15-92; 1:00 p.m. INCIDENT DETAILS LOCATION Badami Exploratory Well No. 2; Cuttings Dump Pad PRODUCT TYPE Hydraulic Oil QUANTITY SPILLED 3 gallons QUANTITY CONTAINED 100% QUANTITY RECOVERED 100% QUANTITY DISPOSED 100% SOURCE OF SP!LL Maxi haul dump truck. CAUSE OF SPILL Broken hydraulic 1 ine fitting. STATUS OF CLEANUP CLEANUP ACTIONS ' ,Cleaned up contaminated ice & snow with shovels/loader and placed into red trash bags. DISPOSAL METHODS Disposed of the red trash bags into dumpster (less than 10% by volume) for disposal at the NSB disposal facility. ENVIRONMENTAL DAMAGES YES NO X SURFACE AREA (SQ. FT.) 40 sq. ft. REMEOIATION ACTIONS None, recovered 100% of material down to clean ice. SURFACE TYPE (GRAVEL PAD, ETC.) Ice pad; contained on the pad. COIIMENTS None. PREPARED BY Joe 'Poyla/Bob Soptei DATE 4-20-92/5-4-92 A'LASKA DEPARTM'-NT OF ENVIRONMENTAL CONSERVATION OIL & HAZARDO ,$ MATERIALS INCIDE,, I- NOTIFICATION SPILL# FILE# CLOSURE- F FOR OFFICIAL USE ONLY nal Report Date: Closure authorized by: Closure Date: PERSON REPORTING doe Poyla (Conoco) RESPONSIBLE PARTY (COHPANY NAHE) Nabors Alaska Drilling/Conoco DATE/TIHE OCCURRED 4-15-92; 3:00 p.m. IPHONE (907) 659-6452 TYPE OF NOTIFICATION 1st part~ 2nd part~ X 3rd party .... DATE/TIHE. REPORTED KNOWLEDGE OF SPILL 4-15-92; 3-00 p.m. 4-15-92; 3'00 p.m. INCIDENT DETAILS LOCATION Badami Exploratory Well No. 2 ice pad. PRODUCT TYPE Glycol QUANTITY SPILLED !5-20 gallons QUANTITY CONTAINED 100% QUANTITY RECOVERED 100% QUANTITY DISPOSED 100% SOURCE OF SPILL NaborS.,26E Drillin~l Rig. CAUSE OF SPILL Unknown - discovered under substructure during demobilization of rig. Spill was mostly contained on Herculite, however 15-20 gallons were released onto ice around cellar box. ' STATUS OF CLEANUP , CLEANUP ACTIONS Sucked up glycol and water/slush (contaminated) into a vac truck. DISPOSAL NETHODS , Materi,a, 1 disposed of at BP's CC-2 disposal facility. ENVIRONHENTAL DAHAGES YES NO X , SURFACE AREA (SQ. FT.) 50 ft. sq RENEDIATION ACTIONS None, recovered 100% of material down to clean ice. SURFACE TYPE (GRAVEL PAD, ETC.) Ice pad; contained on the pad. CONNENTS None. PREPARED BY Joe Poyla/Bob Soptei DATE 4-20-g2;5-4-g2 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 April 22, 1992 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Well Completion Report Dear Mr. Johnston: Attached please find a Well Completion Report for Well Badami No. 2. A Drill Stem Test Report will be submitted upon completion. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, BOb Soptei Environmental Coordinator RJS/bgs Attachments CC Badami No. 2 Well File Jeff Allison Steve Bolt \RJS\AOGCC35.RJS APR 2 8 ]992 Alaska Oil & Bas Cons. Commission Anchorage CONFIDENTIAL STATE OF ALASKA { ' ALASKA OIL AND GAS CONSERVATION COMMISSION 0 R I 6 I N COMi LE?IOI, I OR RECOMI LI ?IOI, I RIq Ol=l? &#D LO ' 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number CONOCO I NC. 91-1/+/+ 3. Address ~0r~PL~-r~, · ~---.--..--.--.~ B. APl Number 3201 C STREET, SUITE 200, ANCHORAGE; ALASKA 9950_~ I' ~.~_TE)_ LOCATION,S! 50- 029-22230 4. Location of well at surface ~ ~,'~2'lFi:~_, ~ i V£~IFfI~. ~.~. . 2700' FNL, 700' FWL, SEC 30, T10N, R20E, U.H., AL.~~ J~ .H..~.~..~ BADAMI At Top Producing Interval '- ~ 10. Well Number 10,580' MD, 10,126' TVD, 2399' FNL, 2/+71' FWL, SEC 30, T10N, R20E, U.N., #2 At Total Depth ALASKA 11. Field and Pool 11,860' ND, 11,/+06' TVD, 2/+0/+' FNL~ 2/+6/+' FWL, SEC 30, T10N, R20E~ U.N. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ALASKA BADAMI PROSPECT 38' ASL KB (35' KB) ADL - 367006 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. No. of Completi°ns 02/07/92 03/20/92 0/+/13/92I 13 feet MSL NONE 17. Total Depth (MD+TV.D) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11 ~860' MD/11 ,/+06'TVD 11,082'MD/10,628'TVr YES I~ NO []I NONE feet MD :1: 1600' 22. Type Electric or Other Logs Run A IT/SDT/GR/TCC/ANS - D ITE/MSFL/SDT/GR/TCC/AMS - LDT/CNL/NGT - FMI - USIT - MSCT (/+1//+9 RECOVERED) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .~ /+8" 502 X-56 SURFACE 51" KB /+8" N/A 10'. 30" 158 X-56 SURFACE 132' KB /+M' 550 sx PERNAFROST 22' ~ 20" 9/+ K'55 SURFACE /+17' KB 26" 13/+/+ sx PERMAFROST : 22' ~'13 3/8" 61 K-55 SURFACE 5e05"KB 17½" 3500 sx PERNAFROST ! /+00 ;x "G" 27" 9 5/8" /+7 N-80 SURFACE 0~539' KB 12:~" 600 sx "G" 190" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) sIZE DEPTH SET (MD) PACKER SET (MD) OPEN HOLE 10,539" - 11,082' MD NONE 10,085' - 10, 628' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.' OPEN HOLE PRODUCTION 10,580' - 10~85/+' ND 10,126' - 10~/+00' TVD DEPTH INTERVAL (MD) AMOUIr~J~I~ii~FiII~AjTFi. BIi41~. USED SEE SCHEMATIC E 'L; E'I V I; U OPEN HOLE "BAREFOOT" DST PERFORNED PLUGS'. SEE WELLBORE SCHEMATIC ATTACHED ~, nm ~ n ,~nn -27. ' ' PRODUCTION TEST /Uas. ka'.OJl & Gas Cons. gm~'tmissi0n Date First Production I Method of Operation (Flowing, gas lift, etc.) Anchorage 3/30/92J FL0Wl NG . .,., Date of Test Hours Tested PRODUCTION FOR OIL-BBL "GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO /+/2/92 20 TEST PERIOD J~ 316 109 0 5/6/+ TO 0P,ENI 3/+/+ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 70 1550 24-HOUR RATE I~ 379 130 0 19.0 28. CORE DATA Brief description of lithology, porosity', fractures, apparent dips and presence of oil, gas or water. Submit core chips. 10~730' - 10,790', INTERBEDDED TO VERY THINLY LAMINATED SANDSTONES, SILTSTONES, AND SHALES. SANDSTONE.' DARK GREY TO BLACK, VERY FINE TO FINE GRAINED, SUBROUNDED, POOR TO WELL SORTED, FRIABLE TO FIRM, OCCASIONAL CALCITE CEMENTATION, VERY THINLY LAHINATED TO MASSIVE, IN STACKED, FINING UPWARDS SEOUENCES. GOOD VISIBLE POROSITY IN MASSIVE SAMPLES. GENERALLY LOW DIP, PARALLEL BEDDING WITH OCCASIONAL RIPPLES AND SCOUR SURFACES. OIL STAINED THROUGHOUT WITH NO APPARENT CONTACTS. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29~ :" 30. GEOLOGIC MARK ?~MATIQN TESTS E~S.-~'I~PT~'-- ' TRUE ~ER~--'DEPTH: GOR0 and time of each phase. · i1564 1559 NONE 7174 6719 7347 6893 8652 8198 '10,580 10~126 'i 11~778 11~324 ,. ............................................. ................................................................................................................................................................................................. 31. [_ISTOF ~TTACHME~TS D I RECT I ONAL DATA, SUMMARY OF OPERAT IONS, WELLBORE SCHEMAT I C 32. I hereby certify that the +oregoing is true and correct to the best of my knowledg.e ' BASE OF PERM. STAINES TONGUE STAINES 2 CANNING CANNING TURBIDITE HUE SHALE Title DRILLING ENGINEER INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurennents given in other' spaces on this forn'~ and in any attachments. Item 16 and 24: If this well is cornpleted 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 't:o 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-ir'l, Other-explain. Item 28' If no cores taken, indicate "none". Form '10-407 g:ONFII]EN11AL CONOCO EXPLORATORY BADAMI NO. 2 - DRILLING API No.: 50-029-22230 02/07/92: Accepted rig at 12:00 hours on 02/07/92. 02/08/92= Finished rigging up. Make up 26" bit and BHA. Drilled to 430'. POOH and prepare to run 20" casing. 02/09/92= RIH with 10 joints of 20", 94 ppf, K-55, BTTS. casing. RIH with 5" drill pipe and stab in tool. Pumped 30 bbl. fresh water spacer followed by 230 bbls. 14.95 ppg, Cold Set II cement, with 10 bbls. of cement returns to surface. Floats did not hold. Displaced drill pipe and WOC. NOTE: Cost totals include ice road, pad and the rig mob. Also included in the costs is all Conoco labor to date. 02/11/92= Pressure test wellhead welds and nipple up diverter. Make up 17-1/2" BHA and function test diverter. Drill out cement. Drill and slide to 618'. 02/12/92= Drilling from 618' to 980'. Surveying every joint. Well not building sufficient, angle~ POOH and increase motor bend from i degree to 1.75 degree. RIH and drill ahead to 1507'with '',,, favorable directional results. 02/13/92: Drilling from 1507'to 2687'. Surveying every joint. Short trip 11 stands. No hole problems, no fill. 02/14/92: Drilling from 2687'to 3932'. Surveying every joint. No hole problems. 02/15/92= Drilling from 3932'to 4318'. Surveying every joint. ,, 02/16/92= Drilling from 4318' to 4404'. ~OOH for MPT tool failure. Replace MPT and change bit. Drilling from 4404' to 4700'. 0Z/17/92: Drilling and surveying from 4404' to 5300'. 02/18/92= Drilling from 5134'to 5785'. Surveying every joint. 02/19/92: Drilling from 5785'to 5823'. Surveying every joint. Condition hole for open-hole logs. POOH. Rig up Schlumberger. RIH with GR/SP/DITE/LDT/CNL/LSS/CAL. 02/20/92= RIH with GR/SP/DITE/LDT/CNL/LSS/CAL. Stacked out at 2,465'. POOH and attempted to log with GR/SP/DITE/LSS/CAL. Stacked out at 2,465'. POOH and attempted Run # 3 with GR/LSS. Stacked out' at 2,465'. POOH and rigged down loggers. P/U 16" bit. RIH and tagged a ball at 2,365. Washed and reamed to TD. POOH to log. No tight spots or hole problems. 02/21/92: R/U Schlumberger and ran GR-SP-DITE-LSS from 5,828' to 1,450'. POOH and rigged down. R/U casing crew and ran 27 joints 13- 3/8", 72 ppf L-80, BTC and 115 joints 13-3/8", 61 ppf, K-55, BTC. Landed float shoe off bottom at 5,805'. Circulate and condition hole for cementing..-- (. CONFIDENtiAL 02/22/92: Mixed and pumped 3500 sacks of Cold Set III cement followed by 400 sacks class "G". Displaced with 868 bbls. mud and had 268 bbls. cement contaminated mud to surface. Ran two 1" strings to 120' and pumped top job with 125 sacks Cold Set II. Pulled strings to 70' and washed out with 10.4 ppg. brine. POOH with 1" tubing. Set 13-3/8" slips, cut 13-3/8" casing and nipDle down diverters. Pre-heat and weld on 13-3/8" x 13-5/8" 5M casing head. 02/23/92: Allow casing head to cool. N/U BOPs and rig up to test. 02/24/92: Tested BOPs. Rig up Schlumberger and ran GCT gyro from 5672' to surface. Begin making up BHA. 02/25/92: RIH with BHA. Pressure tested casing to 1,500 psig for 30 minutes. Drilled out float equipment and 10' of new formation. Conducted LOT to 14.5 ppg EMW. Displaced hole with PHPA polymer. Drilled to 5,969'. Lost bit jet and surface MWD data. Will retrieve MWD data from down-hole memory on the next bit trip. Drilled to 6,323'. 02/26/92: Drilled from 6323' to 6796'. CBU at 6796' and short trip to 13-3/8" casing shoe at 5805'. Hole tight from 6631' to shoe. TIH to 6796' - no problems. Drilled from 6796' to 7102'. 02/27~92: Drilled from 7102' to 7339'. ROP decreased while torque increased. CBU. Began POOH for new bit. Pulled tight from 7008' to 5750'. Finish POOH. Make up new 12-1/4" PDC bit and TIH. 02/28/92: Drilled from 7339' to 7,536. High torque. Rotary stalling at 5,000 lbs. WOB. POOH 47 stands and installed drill pipe rubbers. Drilled from 7,536 to 7,737'. Torque is reduced and the rotary is not stalling. 02/29/92: Drilled from 7,737' to 8,145. Pentration rate slowed to 1 FPH. POOH with no hole problems. Download MWD data and RIH with bit #7. 03/01/92: Drilled from 8,145 to 8,816'. 03/02/92: Drilled from 8,816' to 9,277'. 03/03/92: Drilled from 9,277' to 9,340'. Circulate and condition mud. POOH for new bit to 7,840'. Pipe stuck at 7,840'. Circulated and jarred on stuck pipe with no movement. Spotted 100 bbl. pill and jarred on pipe with no movement. Rigging up free point tools. 03/04/92: RIH with free point tool. Found pipe stuck at 7725' - top stabilizer. POOH with free point tool. RIH to 7694' with string shot back-off charge (1 DC above top stabilizer). Fired charge and backed-off string at 7694'. POOH with drill pipe. M/U screw-in sub and fishing BHA and TIH to top of fish at 7696'. Screw-in top of fish and jarred down freeing B~iA. Backreamed fish up to 7674'. POOH from 7674' with no hole problems. , .... CONFIDENTIAL 03/05/92: POOH with fish to 5800' (inside shoe). CBU. Finish POOH with fish. L/D fishing BHA and drilling. BHA. Test BOP's to 500/5000 psi - OK. M/U 12-1/4" BHA and TIH to 13-3/8" casing shoe. Break circulation at shoe. Finish TIH to 9340'. Drill from 9340' to 9416'. 03/06/92: Drill from 9416' to 9564'. Circulate and short trip. from 9564' to 9792'. CBU and POOH for bit. Drill 03/07/92: Finish POOH for bit. P/U PDC bit and TIH to 9792'. Drill from 9792' to 10,042'. 03/08/92: Drill from 10,042' to 10,133'. Short trip. Drill from 10,133' to 10,335'. Short trip. Drill from 10,335' to 10,473' - increase MW from 10.8 to 11.0 PPG. 03/09/92: Drill from 10,473' to 10,600' MD. Drilling break last 20' · CBU with heavy oil shows in cuttings samples· Drill from 10,600' to 10,606'. Increase in BBG and CG - increase MW from 11.0 PPG to 11.5 PPG. Drill from 10,606' to 10,623'. CBU with heavy oil shows, in cuttings at bottoms up. Drill from 10,623' to 10,730' MD - Core Point· CBU for samples prior to coring· 03/10/92: POOH for coring· M/U core barrel and coring BHA. 10,730' MD. Core from 10,730' MD to 10,750' MD. TIH to 03/11/92: Continue to core from 10,750' to 10,790' MD. Decreased MW from 10.5 PPG to 10.3 PPG while coring· POOH and L/D cores· P/U 12-1/4" BHA and TIH. 03/12/92: Finish TIH to 10,730'· Ream 8-1/2" core hole to 12-1/4" from 10,730' to 10,790'· Increase MW from 10.3 PPG to 10.4 PPG. Drill 12-1/4" hole from 10,790' to 10,995'· 03/13/92: Drill with medium speed motor' from 10,995' to 11,018'. Circulate and short trip. Drill from 11,018' to 11,031'. Circulate and POOH for bit. P/U insert bit and slow speed motor and TIH. 03/14/92: Drill with motor from 11,031' to 11,233'. 03/15/92: Drill from 11,233' to 11,270'· Circulate and POOH for new bit. Test BOP's to 500/5000 psi - OK. P/U PDC bit and med. speed motor and TIH. 03/16/92: Drill from 11,270' to 11,295'. Trip gas to surface with a mud cut to 8.2 PPG (MWin = 11.4 PPG). Close annular - DPP = 0 psi; CP = 0 psi. Circulate gas cut mud through choke (TGmax = 3580 units). Open annular and drill from 11,295' to 11,504'. 03/17/92: Drill from 11,504' to 11,548'. Circulate and short trip. Drill from 11,548' to 11,571'. Circulate and POOH for bit. 03/18/92: P/U insert bit, L/D mud motor and TIH to 11,571' MD. from 11,571' to 11,631'. Drill ( CONFIDENTIAL 03/19/92: Drill from 11,631' to 11,757' MD. Increase MW from 11.4 PPG to 11.5 PPG. Circulate and POOH for new bit. 03/20/92: P/U new bit and TIH to 11,757' MD. Drill (rotary) from 11,757' MD to 11,805' MD. 03/21/92: Drill from 11,805' to 11,860' MD. Circulate and short trip to 13-3/8" shoe at 5,805' MD. Circulate and condition mud for logging. Spot a 100 bbl., 12.5 PPG Hi-vis pill on bottom. POOH. 03/22/92: Finish POOH. R/U Schlumberger and Run Logging Run No. lA: AIT-SDT-GR-TCC-AMS. Set down at 2700' MD. POOH and reduce tool stand-off's. RIH with run No. lB (same tools as lA) Begin downlog and AMS tool failed. POOH and change AMS tool. with log run No. lC (same as iA) to T.D. (11,867' WLM). SDT tool failed but continued to log. POOH. R/U and run logging run No. 2: DITE-MSFL-SDT-GR-TCC-AMS from 11,865' (WLM) to 5805'. POOH and L/D tools. R/U and logging run No. 3: LDT- CNL-NGT from 11,862' (WLM) to shoe. POOH and L/D same. 03/23/92: R/U and run logging run No. 4: FMI. POOH and L/D same. R/U and run logging run No. 5: USIT (casing caliper) inside the 13-3/8" casing. Detected .3 probable holes in casing through build section of hole. POOH and L/D same. R/U and run logging run No. 6: MSCT (mechanical sidewall core tool). Cut 34 sidewall cores at various depths. 03/24/92: Cut 16 addition rotary cores. POOH with the MSCT tool. Recovered 41/49 cores. R/D Schlumberger. TIH with BHA and HWDP. POOH moving HWDP in derrick and L/D BHA. M/U cementing sub and TIH to 11,670' MD. Circulate and condition mud. Spot a balanced cement plug from 11,100' to 11,670' MD. POOH to 10,900' and circulate. POOH. 03/25/92: Finish POOH with cementing shoe. Released operations to Badami DST AFE No. 10-81-1470 at 09.:00 hrs on 03/24/92. 04/05/92: Accepted rig and operations to Badami Drilling AFE No. 10-81- 1403 from Badami $2 DST AFE No. 10-81-1470 at 04:30 hfs on 04/05/92. TIH with 8 stands of HWDP. POOH and L/D HWDP. 04/06/92: M/U 9-5/8" EZSV and TIH to 10,489'. Set same at 10,489'. Shear out of EZSV and circulate. Stab into EZSV and test surface lines to 6000 psi. Bullhead produced fluid from tank farm into formation. Pump 50 bbls water, mix and pump 513 sx (105 bbls) class 'G' cement @ 15.8 PPG, and displace with 11.5 PPG mud. Unsting from EZSV - well flowing (EZSV not holding). Shut-in on pipe rams. Bullhead 140 bbls mud down kill line and 20 bbls mud down DP (130 bbl gain in pits) at 3 BPM at 2000 psi. Close Hydril and open rams. Strip down and sting into EZSV. Well static on both sides. Open Hydril. CONFIDENTIAL 04/07/92: Circulating bottoms up - gain 37 bbls in pits. Close annulus and circulate mud/gas through choke ..... Pressure test EZSV - pumping away at 2 BPM at 1900 psi (EZSV internal sleeve not holding). Bullhead 42 bbls mud down kill line. SIP on DP and annulus of 1300 psi. Sting in and out of EZSV attempting to close sleeve - no success. Sting into EZ_~and pressure test packer element - OK. Establish injection rate through DP at 5 BPM at 2900 psi. Mix and pump 10 bbls water, 84.6 bbls of 15.8 PPG class 'G' cement, and displace with 177 bbls 11.5 PPG mud. Final SIDDP of 1450 psi. Close annular and equilize on backside. Unsting and P/U 30'. WOC. SIDPP & SICP is 1450 psi. 04/08/92: Continue WOC. Test plug by 1) bleeding off pressure on DP and annulus - pressure built back up, 2) pump down DP/annulus - injecting fluid. Sting into EZSV and test annulus to 2500 psi - OK (packer element good). Displace DP with 14.5 PPG mud through choke (SIDPP=O, SICP=1550). Strip out of hole 3 stands and M/U TIW and circulating pin. R/U B.J. and test lines to 5000 psi. Mix and pump 100 bbls (478 sx) class "G" cement with "Gas Block" additive. Dispalce cement to 200' above retainer. WOC, SICP=1200 psi. 04/09/92: WOC, FSICP=1000 psi. R6verse circ 14.5 PPG mud to surface through choke. Bleed off pressure - well static. TIH and tag TOC at 10,413!. (76' of cement on top of EZSV). R/U B.J. and set a 124' cement plug On top of cement (ETOC @ 10,213' - 200' above EZSV). POOH 4 stands and CBU. Pressure test casing to 2050 psi for 30 minutes - OK. POOH. 04/10/92: Finish POOH. R/U HLS and run 8.125" gauge ring/junk basket. POOH. M/U 9-5/8" EZSV and RIH on wireline and set at 10,015'. POOH with wireline. Pressure test EZSV to 2000 psi for 30 minutes - OK. M/U JRC 22 gram charges to wireline and RIH. Perforate 9-5/8" casing with 4 SPF from 5755'-5757'. POOH with wireline. Establish circulation rate through perfs at 5 BPM.at 200 psi. M/U 9-5/8" EZSV and RIH and set at 5705'. POOH with W/L. Test EZSV to 2000 psi for 30 minutes - OK. M/U stinger and plug catcher and TIH. Sting into EZSV and pump 50 bbls of water, 53 bbls of 15.8 PPG 'G' cement, and 7 bbls water. Spotted 30 bbls water 'and 500' cement in annulus and 3.6 bbls cement below EZSV. Spot 20 bbls water and 100' cement on top of EZSV. POOH 3 stands and CBU. Test plug to 2000 psi for 30 minutes - OK. POOH L/D DP. 04/11/92: Displace mud with 10.2 PPG brine at 2000' to freeze protect. POOH. P/U 9-5/8" casing cutter and TIH to 220'. Cut casing and POOH. N/D BOP's and 13-5/8" 5000 spool. M/U spear, latch and POOH L/D casing. P/U 13-3/8" EZSV and TIH and set at'218'. P/U 13-3/8" RTTS and TIH and set at 198'. Pressure test EZSV -. no test (RTTS not set). P/U kelly and reset RTTS at 213' and pressure test to 1350 psi for 30 minutes - OK. 04/12/92: POOH and L/D RTTS. P/U cementing sub and TIH to EZSV. Spot 23 bbls (137 sx) Cold Set I cement from 220' to 15' BML. Cut 13- 3/8" casing at 62' KB. POOH with 19.5' of 13-3/9" casing. P/U cutters and TIH and cut 20' & ~0" at 59' KB. P/U 20" spear and CONFID EhiTli i . attempt to pull casing - no success. P/U cutter and make another cut @ 49! KB. ~. 04/13/92: P/U spear and retrieve 14' of 20" casing. Attempt to retrieve 8' fish of 20" casing - no success. Cut casing again and retrieve 20" fish from 57' KB (16' BML). P/U 26" bit and drill out cement to 57' KB. P/U 30" cutter and attempt to cut casing at 57' KB. P/U 30" spear and attempt to retrieve 30" pipe - no success. 04/14/92: P/U cutter with 21" blades (49.5" swing) and cut casing. POOH and L/D cutter. Pull 30" and 48" casing strings. Release rig at 1750 hfs on 04/13/92 with 9400 gallons of fuel. Demob rig. AFE 1402 & 1403 = $6,880,599 AFE 1470 = $1,401,324 04/15/92: Move substructure to Prudhoe Bay stacking location. At location, clear liner, timbers, rig mats, etc.. Blowing conditions shut down operations. 04/16/92: Shut down for blowing conditions. 04/17/92: Shut down for blowing conditions. 04/18/92: Open ice road to location . 04/19/92: Dig up well cellar and clear location. Trim 6" of ice off pad. Retrieve all road reflectors from ice access road. End of Project. CONFIOENTIAL CONOCO EXPLORATORY BADAMI NO. 2 - DST API No.: 50-029-22230 03/25/92: Accept rig on Badami No. 2 DST AFE No. 10-81-1470 at 09:00 hfs on 03/24/92. P/U bit and TIH to TOC at 11,030' MD. Wash cement from 11.030' to 11,072' MD. Drilled firm cemnet from 11,072' to 11,082', set down 50,000# - OK. Circulate and condition mud, spot a 120 bbls hi-vis pill on bottom. POOH. Change rams to 9-5/8" and test bonnet seals to 2000 psi. R/U and run 9-5/8" casing. 03/26/92: M/U and run 9-5/8", 47 #/ft, N-80, BTRC casing to 10,339' MD. Land hnager and M/U cement head. 03/27/92: Test lines to 4000 psi. Release latch down plug and inflate ECP with mud. Packer element from 10,512' to 10,533' MD. Shear open HOS stage cementing tool. Mix and pump 50 bbls of 12.2 PPG Sepiolite spacer and 600 sx (123 bbls) class 'G' cement at 15.8 PPG. Displace with 768 bbls mud at 11.6 PPG, bump plug and close HOS cementer. N/D BOP's and set slips with 350,000#. Cut casing and N/U 13-5/8" 5,000 psi casing head. N/U BOP's and test to 300/5000 psi. P/U 8-1/2" BHA and TIH. 03/28/92: Finish RIH w/8-1/2" Bit. Drill out Float Equipment and clean out open hole to 1108~'. Circulate and condition mud. POOH and lay down excess dr~ll pipe. RIH with bit and casing scraper to 10495'. Circulate. 03/29/92: Drop ball and pressure flex test drill pipe/drill collars to 5000 psi. POOH. R/U Schlumberger. Run VSP #1 SAT log from 11,080' to 10,350'. Began running VSP #2 ASI log from 10,550'. 03/30/92: Finished running VSP #2 ASI to 5000' MD. P/U DST tool string and TIH. Position packer at 10,500' MD and M/U surface equipment.. NOTE: VSP logging charged to Badami #2 drilling AFE. 03/31/92: Test flow head to 5000 psi. Pump 10 bbl XCD polymer pill and displace with 65 bbls of 3% KCl water and 165 bbls of water for underbalance. Set packer at 10,494' , test drill pipe to 5000 psi. Flow well for initial flow period. Shut-in for initial build-up. Flow well for extended flow period. 04/01/92: Continued to flow well for second flow period. Cycle OMNI and reverse string clean with 11.5 PPG mud. Displace string with Nitrogen. Cycle OMNI and flow well for third flow period. 04/02/92: Continued flowing well for third flow test. Shut-in well and repair leaking swab valve on test tree. Open well and continue with third flow test. Shut-in well at master valve. Bleed pressure off tree. P/U Schlumberger perforating guns and R/U lubricator. Test lubricator to 5000 psi. RIH with perf. assembly and tag up at top of bundle carrier. POOH and L/D CONFIDENTIAL perf. assembly. Close LPRN valve and bleed off Nitrogen. R/U slickline and test lubricator to 4000 psi. RIH with GRC gauges to LPRNvalve. Open well for fourth flow period and ran gauges below packer. Sat down below packer. POOH with slickline. Continue flow period #4. 04/03/92: Continue flow period #4. Took downhole sample. Shut-in well for final build-up. 04/04/92: Finish 24 hr final shut-in with LPRN closed. Reverse circulate 11.5 PPG mud to kill well (circulated through choke also). Purged test lines with diesel/air. R/D rig floor test equipment. Cycle OMNI valve to test position and bullhead with 11.5 PPG mud (1700 Psi). 04/05/92: Cycle OMNI to circulating position, P/U on packer to open concentric bypass and bullhead the tubing tail annulus with 75 bbls of 11.5 PPG mud. L/D test tree and POOH 10 stands - well static. POOH and L/D DST BHA. Retrieve bundle carriers and downhole samplers. Had 1.5' of fill in tubing tail mule shoe - no plug in tubing. R/U HLS and RIH with CCL-GR and tag fill at 11,046' WLM (36' of fill). POOH and R/D wireline. NOTE: Release rig and operations from Badami $2 DST AFE No. 10-81-1470 to Badami $2 Drilling AFE No. 10-81-1403 at 04:30 hrs on 04/05/92. ECEIV£D Alaska Oil & Gas Cons. Commission AnChorage CONFIDENTIAL BADAMI #2 WELLBORE SCHEMATIC CONFIDENTi , . 04/15/92 SURFACE: CASING CUT 16' BML SURFACE PLUG FROM 24'-174' BML PERMAFROST CEMENT RETAINER @ 215' KB (174' BML) 9-5/8" CUT @ 220' MD (179' BML) 48" CASING @ 51' KB (10' BML) '30", 0.5" WALL CASING AT 132' KB (91' BML) CMTD TO SURF. 20", 94#,K-55, BTRC CASING ~ 417' KB - CMTD TO SURF. ANNULUS CEMENTED 5757'-5257' (500' COVERAGE) RETAINER @ 5705' KB 100' CEMENT ON TOP 50' CEMENT BELOW PERF's FROM 5755'-5757' 13-3/8", 61#, K-55, BTRC CASING @ 5805' KB - CMTD TO SURF. ETOC @ 9,539' KB RETAINER AT 10,489' KB DOWN SQUEEZED TO 11,082' KB TOC @ 10,213' MD ON TOP 276' CEMENT ON TOP OF RETAINER 9-5/8", 47#, N-80, BTRC @ 10,539' KB- CMTD TO 9539' ISOLATION PLUG @ 11,082'-11,640' KB TD AT 11,860' RKB · .~ J,UL B '0~ 10:~G , FROM CONOCO ANC ENGxEXPL (" PACE. 00? 4450 W. 50TH AVENUE , ANCHORAGE, ALASKA 99502 TELEPHONE (907) 243-2822 May 12, 1992 Jim Hand Conoco, Inc. Suite 200 3201 "C# St. Axtchorage, AK 99503 Dear Mr. Hand= Core Analysis Badamt No.2 Badamt Field North Slope, Alaska This report presents final Core Analysis and Oil Gravity Data for samples received from your Badamt No.2 Well. Laboratory procedures are included for your reference. We appreciate this opportunity to be of service, and trust these data prove helpful in the modeling and development of this reservoir. Sincerely, i~ ~Pe~er T. Sdhuyler President INC. I i i PTS: rf Eric1. L o 9 lgg2 l~as Cons. Commission Anchorage OII&IIIAL Company : CONOCO, INC. #ell : BADAHI #2 Locatton : Co,State : NORTH SLOPE, ALASKA CORE LABORATORTES Fteld : EXPLORATION Formation : EXPLORATZON Cortn9 Flutd: BLAND NUD Elevation : Ftle No.: C01462 Date : 24-HAR-92 AP[ No. : Analysts: PLB CORE ANALYSTS RESULTS SATURATZ011 SAHPLE DEPTH PERNEAB];LZTY POROSITY .... GliAZN DESCRIPTION NUHBER (HORZZONTAL) (HELZUH) (PORE voLijflE) DEIt$ITY Kair O~L VAT£R ft nd 2 ~ ~ gnVcc C0RE I [0730.0 - 10789,6 t 1 10730.3 10~-. 17.1 63,4 13.0 2.63 S$-ltg~Y,Vl)-fgr, pred fg~,occ bJt,lim, wsrtd, lbrnd,wcng,qtz,wh cly cng. I 2 10731.3 0~94 10.0 $Z.6 34.9 2.67 $$-mltgy,vf-fgr,p~ed vt'gr,bnd,sbrnd, wcng,qtz,brn & wh c]y,tr ca~c. I 3 I073~.3 0.36 10.6 5(i.0 ~4,0 Z.63 SS-nltgy, vf-fg~,pred vf0~,bndosbrnd, wcng,qt:,brn & ~h cly, tr cllc. 1 4 10733.6 5.2Z 13.0 6Z.O 19.2 2.67 SS-ltgy,vl'-fgr,pred fgr,vsrtd,bd w/vf s$,sbrnd,,cng.qtz,brn cly,tr calc. 1 5 107;34,3 11.6 8.3 4~.2 66.5 2.70 SLTST-mgy, slt,bnd w/f~n~r 8brnd ss,vGmt,qtz,brn cly,tr c&lc. ! 6 107;35.4 2.66 13.6 64.1 13.1 2.60 S$-mltgy,vf-nwr,pred v~gr.~srtd,occ lam, sbang,vcmt,q~z,~h cly en~,tr 1 7 10736.3 0.43 7.2 36,6 66.4 2.64 SS~y. slt-md, pred vf sd,~rtd, lam, sbrnd, vc~,~z,brn cly,tr cni~. 1 8 10737.5 143. 17.0 67.2 J7.6 Z.68 SS-ltgy,vf-~r,pred rgb,ccc btt lam, vsrtd, sbrnd,~og,~z,vh ;ly ;K, I 9 10738.5 1.94 12.2 62.2 13,4 2,65 SS-mltgy,vf~r,pred vfgr, vsrtd,f lam, sbrnd,vc~,qt~, occ btt,wh ely i [0 10739.3 26.8 16.9 66,1 9.4 2,61 SS-ltgy,vf-~r,pred fgr,~rtd,~ lsm, sb~d,K~,qtz,occ bit. -I il 10740,3 16.6 68,7 18,5 2.64 SS-ltgy,vf-~r,pred fgr,vsrtd,vk lim, sbrnd,v=~,qtz,occ bit,broken. 1 12 10741.6 O. D8 1.7 63.4 27.1 ~.76 S$-~y,~gr,ws~td. sbrnd, vvc~,~z,ealc. I ~3 10742,3 3,31 ~3,1 67,3 12.9 2.66 SS-ltgy,vf-~r,~srtd, wk 1Em, sb~nd, vc~,qtz,ecc-b~t. I ~4 10743.3 27,3 17.8 66.0 9.0 2.66 SS-ttgy,~-~r,,pred fgr, sb~d, vcg,qtz,tr blt. 1 ]5 t0744.1 S2.3 16.6 62.6 12.5 ~.65 SS-ltgy,~-~r,pred fgr,~s~,K ]am, sb~d,KK,~z,t~ btt. I I6 10746.4 2,67 12,1 61,1 17.6 ~.61 SS-ltgy, vf-~r,pred fgr,~lrtd,~k lam, sbrnd,~,qtz,tr bit. I 17 10746,2 77.7 ~9,6 64,3 ~.6 ~,66 SS-]tgy,~-~r,~d, sb~nd,~,qtz,~h ely ~. ~ I 18 10747,3 0,13 7.8 69.9 39.8 2.70 SLTST-BIt~,bnd 81t~fsd, sb~d,~c~,~z,tr btt,carb c~. I 19 10748,3 1.18 11.6 63.4 15.4 ~,56 SS-ltgy,~-fgr,p~d vfgr,vvsrtd,vk lam, sbrnd, wcK,qtz,dk b~n cly. [ Z0 10749,3 11.3 9.2 44.7 46.3 2.6~ SS-mltw, slt-fad, pred ~sd,~d, bnd, sb~d,K~,qtz,gy cly,tr cllc,fra~. I ~] 10750.2 0.73 7,4 45.4 6J.7 ~,~4 SS~lt~,~lt-fsd, pred ~sd,vsrtd,bnd, sbrnd,w~,qtz,gy cly,tr ~ ~2 10761.1 K.5 11,1 58.1 24.2 2,67 SS-mltgy,~,v~rtd, lam, sbrnd,vc~,qtz,brn ~ly,tr L 23 10762.3 0.23 8,2 31,5 64,9 2.69 SS-mlt~,slt-fsd, pred vfsd,wrtd, bnd, sb~d,~,qtz,gy cly,tr calc,frac. J 24 10753.4 5.20 9.9 61.0 37,0 ~.~6 SS-mltgy,~,vvs~d, lim, eb~d,K~,qtz,brn Gly,tr calc. I 25 10754.2 6.~ 9.0 38,8 57,0 ~.70 SS-mltgy, alt-md,pred fsd,vsrtd, bnd,sb~d,vc~,qtz,wh cly c~,t~ ..... ~ .... . .......... · . ._ .... : - . 1-1 Z 0 X emm mm m mm. .mm m m mm mm em em imm m m m m · · · CORE LABORATORTES Company : CONOCO, INC. #611 : BADAHI #2 Ftold Formation : EXPLORAT!ON : EXPLORATXON File No.: C01462 Date : 24-NAR-92 CORE ANALYSIS RESULTS ......... I" SATURATION SAMPLE DEPTH PERMEABILITY POROSITY L, GRAIN D£SCItlPTION NUHBER (HORZZONTAL) (HELZU#) (PORE VOLUHE) DENSITY Kal r OZL YATER ft mci X % % gm/cc 26 ] ~$'$'.:) 26.7 1X.7 68.7 24.6 2.62 SS-ltoy,, lt-fsd, Pred 27 10756.2 33.; 12,4 66.9 24.1 2.67 SS-ltgy,slt-md,p~ed vfsd,wrtd,bnd,sbrnd,wcn~c,qtz,tr btt,tr calc. 28 J0767.1 1,4! 8.1 44.7 -53.6 2.67 $S-11:gy,$11:-fad.pred vPsd,wsrtd, bnd,sb~nd,wcmt,qtz,occ btt,tr 29 10768.3 5,46 14.0 63.7 14,4 2.58 S$-ltgy,vf-mgr,pred vfgr,wsrtd, lam, rnd,~cng,qtz,dk brn oly. 30 10759.4 6.91 10,3 56.0 30.6 2.64 $$-mltgy,vf-fgr,p~d vfgr,wertd, lam, sbr~d,wemt,qtz,dk brn ~ly, tr ;ale. 3! 10760,4 6.66 2,3 64.8 28.3 2.72 $$-mltgy, slt-fad, pred vfsd,tt~rtd,~k lam, mbrnd,v~cnd;,qtz,~mlc cmt. 32 10761.4 0.65 9.8 67.7 35.2 2.63 S$-mltgy,vf-fgr,pred vfg~,wmrtd, lam, sbrnd,~cmt,qtz,brn cly,tr calc. 33 10762.4 98.6 19.6 64,3 9.5 2.66 SS-ltgy,vf-mgr,pred fgr,wmrtd,rnd,mod emt,qtz,dk arb gr. 34 10763,4 1.79 12.2 69.0 17.0 ~.56 $$-mltRy, vt'-fgr,pred vfgr, lam,#srtd,sbrfld,#cM:,qtz,dk 36 10764.3 11S. ~9.1 66.! 6.0 2.64 S$-ltgy,vf-fgr,pred vfgr,~k lam, wrtd,sbrnd,~cmt,qtz,wh cJy cng. 36 10765,4 2.14 11.0 57.1 29,4 2,70 $$-mltgy, sJt-fsd, pred vfad, bnd,~mrtd, sbrnd,wnd:,qtz,wh cly,tr calc. 3;/ 10766.4 19.7 13.Z 59.2 19,5 2.65 $$-ltgy,vf-fgr,pred v~gr,wrtd,uk bnd,#mnt,qtz,tr br~ cly.tr calc. 38 10767,4 4.03 8,6 39.7 51.5 2.70 SS-mltgy,slt-f'sd, pred vfsd, k~rtd,bnd, abrnd,~cnfc,qtz,gy cly,c&rb cn~c,frac. 39 10768.4 0,19 8.3 45,9 47.7 2.69 SS-mltgy, slt-vfsd,w$~td, lan,&brnd,wc~t;,qtz,gy cly,carb cmt. 40 16769.4 1.61 9.0 47.7 42.5 2.69 SS-mltgyoslt-vfad,wsrtd, lam, sbrnd,wemt,qtz,gy c~y,capb cngofra~. 41 10770.4 18.8 8.4 40.3 52.2 2,69 SS-mltgy,slt-vfsd,#srtd, lan,sbrnd,wcmt,~z,gy cly,c&rb cnd:ofrac. 42 10771.6 0.29 11.6 49,4 35.3 2.68 SS-mltgy,sJt-vfsd,~rtd, lamosbrlld,~cnd;oqtz,g¥ cly.carb cng,broken. 43 16772.4 0,58 10.6 62,2 22.8 2.66 $S-mltgy, vf-fgr,pred vfgr, lam, sbrnd,~cng,qtz,brn cly, carb cmt. 44 10775.4 1.18 t2,3 57.7 24.6 2.69 SS-mltgy,vf-fgr,pred vfgr, lam, sbrnd,wcngoqtz,brn ely,oath cng. 46 10774,4 1,85 t3.6 64,6 14o3 2.65 SS-mltgy°vf-fgr,pred vfgr, lem, Bbrnd,wcnfc,qtz,brn ely, oath cmt. 46 10776.4 8.60 I0.3 59.0 26.6 2.67 $S-mltgy, vf-fgr,pred v~gr, lam, sbrnd,~mng,qkz,brn cly,~arb cml;,l'rac. 47 10776,6 0.96 11.1 69.2 23.7 2,66 $S-mlCgy, vf-fgr,pred vfgr, lam, sbrnd,wcnd;,qtz,brn cly,carb ©nd:,b~Oken. 48 10777.4 1.9 38.3 52.5 2.71 S$-ltgy, .vfofgr,pred vl'gr,wk lam, abrnd,v~ cn~,qtz,¢alc 49 10778.4 O. OS 7.6 4;.5 50.9 2.73 SLTST-mlf;gy, slt-fsd,bnd,sbrnd ad,¥~ng,qtz,;alc cmt. 50 10779,6 0.64 10.1 50.9 37.0 ;,67 S$-mltgy, elt-fsd, pred vfsd,wrtd, lam, rnd,wemt.qtz,gy cly,carb (:nd;, 51 10780.5 23.5 13.4 58.2 19.0 2.66 SS-ltgy,vf-mg~,pred fgr,wsrtd, lam, rnd, v~,qtz,brn cly,tr calc,t~ bit. 52 10781.~ 2.83 B.7 48.9 40,6 2.67 S$-Ttgy,vf-mgr,pred fgr,vsrtd, lam, rnd, v~cmt,qkz,brn cly,tr calc,ta bit. 53 10782.9 37,2 9°2 37,6 47.1 2.66 SS-mltgy, slt-fsd, pred vfad,wrtd, bnd,rnd, v~mt,qtz,gy ~ly,carb cmt°broken. 1. 64 10783°6 4,62 0.4 41,! 48,6 Z,06 SS-mltgy, slt-fsd, pred vfsd,~a~td, lam, rnd, vN~mt,qtz,Ry i · r .. ~ ..... ., i l, .il i ... . .... ~0 o o z o c) o z Fll Z Fll X .,~. · 1-2 Company : CONOCO, ZNC. He11 ; BAOAH! ~2 :J CORE CORE LABORATORTES Fie'Id : EXPLORATION Fomat'ion : EXPLORAT]0N ANALYS ZS RESULTS Ftle No.: C01462 Date : 24-NAR-g2 SAHPL£ DEPTH NUHBER I 56 50784.5 1 56 10785.5 1 57 10786.4 ! 58 10787.2 I $9 50788.1 1 60 ] 0789. ] I PEitNEAB! L ZTY I (IIORZZOIITAL) I 0.22 0.19 72.2 3.25 8.94 POROSITY (HELZUN) SATURATZON OZL VATER 10,1 37.4 -47.9 8,1 48.1 43.4 8.7 43.9 44.8 18.0 69,2 11.3 12.6 66.1 23.2 9.1 38.7 59.3 GRAIN DESCRZPTZON DENSITY gm/Ge Z.68 SS-mltgy, slt-fad, pred vfsd,vsrtd, lam, rnd, v~emC,qtz,gy oly, oarb oK,b~ok~. ~.67 SS-mltgy, slt-fsd, pred vPsd,~d, lim,~d, vK~,qtz,gy cly,Gerb c~. ~.66 SS-mlt~, slt-fsd, pr~ vfed, wrtd, lam, ~, vv~,~z, gy cly, cerb ~, broken, ~.~ SS-ltgy,f-~r,pred ~r,~d,sb~d,w~,qtz,dk 11th gr. 2.67 SS-mltgy,=l~-Nd, pred v~sd,~rtd, lam, sb~d,~,~x,gy c]y,c~rb c~. 2.71 SLTST-~,bnd w/fsd,cirb ~. o z o o z z m x r-- m 1,-3 ~~~CORE ANALYS!S REPORT FOR CONOCO, ZNC. BADAH! NO.2 BADAH! Apr'il 1992 F]:LE 70103 Reports submitted by PetroLeum Testing Service are based on the ana(ysis of materials and information supp(iedl~, the ctient, and cannot be guaranteed. These opinions and interpretations expressed rqpresent our best judgement; however, PetroLeum Testing Service assumes no responsibility nor makes any uarranty regardin9 profits or performance resulting from the use of such reports. Conoco, Inc. Badami No.2 Wildcat North Slope, Alaska ROUTINE CORE ANALYSIS PROCEDURES 1. Trim 1" diameter rotary sidewall core to right cylinder. 2. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volume. 3. Vacuum dry at 150°F until weight is stable. Allow sample to cool and weigh to the nearest 0.01 gram. 4. Measure bulk volume using mercury immersion method. 5. Measure sand grain volume using a Boyle's Law helium porosimeter. Calculate porosity, saturations and grain density. ' . 6.. Mount samples in hydrostatic Hassler-type sleeve using a confining stress of 300 psi. 7. Measure permeability with nitrogen gas using a calibrated flow tube type permeameter. 8. An additional c.ore'plUg..sampie from 10,736, was provided by the client. The SamPi:e'w~s'.'.processed as described above, but subsequently cleaned in a C~10roform/acetone azeotrope. Porosity, permeability, and saturation data for each cleaning technique is presented following the sidewall core data. COMPANY : CONOCO, ]NC. CORE TYPE: 4 TN MUD TYPE : WATERBASE FORMATION: UNKNOWN ,- C .I Vr IROLEUH TESTTHG SERVTCE, TNC. JUN ~ 6 ~9~ WELL : BADAHI NO.2 FIELD : BADAH] ~8ska OiL &A~chors~eGas Cons. com~mS~on STATECOUNTY :: ALAs~NORTHSLOP E PAGE : 1 FILE NO.: 70103 DATE : APRIL 28, 1992 SIDEWALL CORE ANALYSIS RESULTS I I '1 I I I SAMPLE I DEPTH IPERMEAB]LITYI I NU~tBER I f tI ~d I i.. i I I I I I I I I SATURATION I I I I IGRAIN I INCHES POROSITYI o/. I OIL .ATE. TOTAL I DENSITY I RECOVEREDI % I RATIO I (PERCENT PORE VOLUHE)I g/cc I S34 10560.00 <0.1'* ; 8.7 0.0 '0.0 85.1 85.1 2.70 0.00 COMMENTS **Fractured, Estimated Ka I I I LITHOLOGICAL DESCRIPTION I I Sst, gry, vfsd, shty, N[ cmt, no odor, no stn, no fluor S3 10589.00 24 20.7 0.3 11.7 42.7 54.4 2.~ 0.00 Sst, Lt brnsh gry, fsd, shiy, wL cmt, trace carb, no odor, ev med stn, dL gId fluor S4 10591.00 24 14.6 . ***** 0.0 0.0 0.0 2.70 0.00 OIL GRAVITY Sst, Lt brnsh gry, fsd, shLy, wi cmt, trace carb, no odor, ev med stn, dI gid fluor SS 10606.00 <0.1 7.3 0.0 0.0 96.9 96.9 2.71 0.00 Sh, bLk, skty, wt cmt, no odor, no ~;tn, no fluor S6 10613.00 <0.1 S7 10615.00 22 6.2 0.1 7.3 85.9 93.2 2.77 0.00 18.4 0.4 15.9 43.3 59.2 2.67 0.00 Sst, dk gry, vfsd, shty, ~L cmL, calc, no odor, strk med stn, d[ gld fluor .~. Sst, brnsh gry, vf-fsd, st shLy, wL cmL, no odor, ev med stn, dL gLd fluor' S8 10626.00 19 S9 10635.00 0.1 17.6 ***** 0.0 0.0 0.0 2.62 0.00 8.3 0.7 35.7 50.9 86.6 2.63 0.00 OIL GRAVITY Sst, brnsh gry, vf-fsd, st shty, wi cmt, trace carb, no odor, ev med stn, dL gLd fluor ..~ Sst, dk gry, vfsd, stty, shky, wL chit, no odor, strk med stn, dt gtd fluor SlO 10639.00 8.6 19.6 0.6 20.4 34.6 55.0 Z.~ 0.00 ! Sstf brash gry, vfsd, st shLy, wt cmL, no odor, ev reed stn, d! aid fluor Sll 10648.00 3.0 15.0 0.4 19.0 43.8 62.8 2.66 0.00 SSt, brnsh gry, vfsd, st shty, ~t cmt, no odor, ev med sin, d[ gtd fluor COHPANY : CONOCO, INC. CORE TYPE: 4 IN HUD TYPE : WATERBASE .~ tJ..'-t -~ - FORI4ATTON: UNKNOHN ~~1 D E H A L L PETROLEUH TESTING SERV!CE, ~ :~ t, ~' ~ HELL : BADAHI NO.2 FIELD : BADAH! COUNTY: NORTHSLOPE STATE : ALASKA CORE ANALYSTS II C. RESULTS PAGE : 2 FILE NO.: 70103 DATE : APRIL 28, 1992, I I I I I I I' I I I I I I I I I I I ISAMPLE I DEPTH IPERHEABILITYI I NUMaERI ft I md I ~ I .l I I I SATURATIONI I I I I IorAI~I I I.CHESl POROSITYI O/W I O~L WATER TOTAL IDENSlTYIRECOVEREDI ~ I ra.o I (P~rC~.T POrE VOUU. E~I ./c¢ I I ~ ....... I I I I COMMENTS I I I I I LITHOLOGICAL DESCRIPTION ~ I I I I ~ S12 10655.00 2.4 S13 10670.00 <0.1 S14 10684.00 <0.1 S15 10690.00 1.4 S16 10696.00 <0.1 S17 10707.00 2.2 S18 10711.00 1.3 S19 10719.00 7.1' S20 10725.00 <0.1'* 15.4 0.8 24.1 29.9 54.0 2.67 0.00 8.0 0.1 8.1 78.1 8~.2 2.7'5 0.00 7.5 0.0 4.1 89.3 93.4 2.72 0.00 12.1 0.7 26.6 39.2 65.8 2.74 0.00 2.4 0.1 6.5 62.5 69.0 2.75 0.00 9.0 0.5 26.6 56.6 83.2 2.61 0.00 15.5 ***** 0.0 0.0 0.0 2.71 0.00 16.4 1.8 37.8 21.6 59.4 2.70 0.00 17.7 0.1 4.1 68.6 72.7 2.91 0.00 OIL GRAVITY *Fractured Ka **Fractured, Estimated Ka Sst, brnsh gry, vf-fsd, st shly, wl cmt, trace carb, no odor, ev med stn, dl gld fluor Sh, bLk, stty~ st sdy, vwi cmt, no odor, strk med stn, d[ gtd fluor Sh, blk, stty, st sdy, vwl cmt, no odor, strk med stn, dl gld fluor Sst~ bm, vfsd, slty, wl cmt, no odor, strk med stn~ dl g[d fluor Sst, gry, vf-fsd, vwl cmt, calc, no odor, med stn, d[ gld fluor .~td Sst, bm, vfsd~ si shty, lam, wl cmt, no odor, strk med stn, dl gld fluor SSt, bm, vfsd, sl sh[y, lam, w[ cmt, no odor,'-ev med stn, d[ g[d f[uor Sst, bm, vfsd, $l shLy, lam, wl cmt, no odor, ev mod stn, dl gld fluor Sh, dk gry, stty, wl cmt, no odor, strk med stn, dt gld fluor COMPANY : CONOCO, INC. CORE TYPE: 4 IN MUD TYPE : WATERBASE FORMATION: UNKNOUN PETROLEUH TESTTHG SERVTCE, R E¢ E iV E D "ELL : 8AOA"I NO.2 JUN 2 6 1992 Alaska 011 & Gas Cons. Commission Anc~r~DeO E W A L L FI ELD : BADANI COUNTY.' NORTHSLOPE STATE : ALASKA CORE ANALYSIS I[lC. RESULTS PAGE : 3 FILE NO.: 70103 DATE : APRIL 28, 1992 -, I I I I I I I l I I I l I SAMPLE I DEPTH IPERM£ABILITYI I NUMBER I ft I ~d I I ! I I S~l 10730.00 0.6 S22 10792.00 50* S23 10801.00 0.8 S24 10806.00 0.8 S25 10813.00 9.6 S26 10816.00 0,2 S27 10820.00 0.2* S28 10828.00 0.9* S29 10831.00 0.3 I I I I I I I SATURATION I I I I I IlGRAIN IiNCHES I POROSITY I O/g I OIL WATER TOTAL I DENSITY I RECOVEREDI % I RATIO I (PERCENT PORE VOLU. E)I o/cc I I i .. . i I I I 9.2 1.2 39.8 34,2 74.0 2.62 0.00 21.8 ***** 0,0 0.0 0.0 2.70 0.00 7.7 0.5 33,4 61.3 94,7 2.~4 0.00 9.1 0.2 13.4 64.1 77.5 2.66 0.00 17.4 0.6 19.8 35.0 54.8 2.63 0.00 7.4 0.6 36.3 56.2 92.5 2.65 0.00 7.3 0.0 4.3 91.8 96.1 2.68 0.00 8.4 10.2 16.2 78.5 94.7' 2.66 0.00 8.3 0.2 14.6 81.6 96.2 2.68 0.00 COMMENTS OIL GRAVITY *Fractured Ka *Fractured Ka *Fractured Ka I LITHOLOGICAL DESCRIPTION ,,~, I : I Sst, bm, vfsd, SI shty, tam, wt cmt, no odor, strk med stn, d[ gtd fluor Sst, brn, f-md, sL sh[y~ w[ cmt, no odor, no stn, no fluor Sst, brn, vf-fsd, wi cmt, no odor, ev med stn, dL gtd fluor Sst, brn, vfsd, sh[y w/Lam, wi cmt, no odor, strk It stn, dL gtd fluor Sst, brn, vf-fsd, s[ shty, wl cmt, carb/I/"~'no odor, ev med stn, d[ gld fluor Sst, bm, vfsd, shLy w/lam, wL cmt, no odor, strk [t stn, d[ g[d fluor Sst, dk gry, vfsd, a[ty, shty, Lam, wi cmt, no odor, strktt stn, dt g[d fluor Sst, dk wry, vfsd, s[ty, shty, la:n, wt cmt, n~ odor, strk[t stn, dl gld fluor Sst, dk gry, vfsd, stty, shty, LO, l, w| cmt, no odor, strk It stn, dt gtd fluor COHPANY : CONOCO, INC. CORE TYPE: 4 IN MUD TYPE : WATERBASE FORNATION: UNKNOWN WELL : BADAHI NO.2 JUN 2 6 1992 FIELD : BADAN! COUNTY: NORTHSLOPE ~as~Oil&GasCons. Commission STATE : ALASKA Anchor~e SIDEWALL CORE ANALYSIS RESULTS PAGE : 4 FILE NO.: 70103 DATE : APRIL 28, 1992 · I I I I I I I I I SA.PLEJ DEPTH IPERMEAI~ILITYI I NUMSER I f t I md I i I , I I I I I I I J J SATURATION J J J J I~ il GRAIN J INCHES J POROSITY J O/U J OIL WATER TOTAL J DENSITY I RECOVEREDJ % J RATIO J (PERCENT PORE VOLUME)J g/cc J J I I I I I COHHEHTS LITHOLOGICAL DESCRIPIlON S30 10847.00 0.8* S31 10852.00 <0.1 S32 10856.00 <0.1 S33 11508.00 <0.1'* S35 11578.00 0.5 9.4 0.2 15.8 63.6 79.4 2.70 0.00 7.6 ***** 0.0 0.0 0.0 2.76 0.00 4.1 0.4 24.3 53.3 T'/'.6 2.65 0.00 6.7 0.0 0.0 93.0 93.0 2.70 0.00 6.6 0.5 26.8 54.1 80.9 2.64 0.00 *Fractured Ka OIL GRAVITY **Fractured, Estimated Ka Sst, dk gry, vfsd, slty, shJy, Jam, wt cmL, no odor, strk It stn, d[ g[d fluor Sh, dk gry, sd, wi cmL, no odor, strk tt stn, dt gid fluor Sst, gry, fsd, vw[ cmL, catc, fnt odor, ev med stn, di gtd fluor Sh, dk gry, sLty, wi cmt, no odor, no stn, no fluor Sst, gry, vfsd, shty, wi cmt, no odor, st~'~'~t stn, d( gtd fluor · CONPNIV : CONOCO. INC. CORE TIIE: 4 IN NOB TYPE: IgkTEIIBASE FORNATIOII: ttENOlII PETROL TESTZNG SERVZCE, IIELL : .B/idlilZ F]ELB : FAtIITY: NOItTHSLOPE STATE: ALASKA SZO[IdALL CORE ANALYSIS ZNC. RESULTS PAGE : S ~ FILE NO.: 70103 .~ i)~TE : dilLY 09, 1992 ~ .. OriiliN ~ W ~tr~ce fr~fl ~ field s~gcim, grain ~liy o --~ 0 z o C~ o z rll G~ ,% X I1'1 COMPAtIY- : CONOCO, INC. CORE TYPE: 4 IN MUD TYPE : WATERBASE FORMATION: UNKNOWN REc EUM TEST1;ItG SERVICE, INC. WELL : BADAH! NO.2 JUN 2 6 1992 FIELD : BADAHI COUNTY: NORTHSLOPE Alaska 011 & Gas Cons. Commission STATE : ALASKA Anchorage CONVENTIONAL CORE ANALYSIS RESULTS PAGE : 6 FILE NO.: 70103 DATE : APRIL 28, 1992 i I I I ..... ! I I I I I J SATURATION I I I I I I .... I GRAIN SAMPLE I DEPT, IPERMEABILITYI POROSITY I O/W I OIL VATER TOTAL I DENSITY .UMBE. I ft I md I ~ I RATIO I (PERCENT PORE VOLU~E)I g/cc I I I I I I 10736.40 18.9 4.9 56.4 11.6 68.0 2.65 2 10736.41 19.5 5.0 56.4 11.2 67.6 2.67 COMMENTS LITHOLOGICAL DESCRIPTION Sst, [t gry, vf-fsd, stty, w[ cmt, 9d odor, dk stn, g[d fluor Data after cleaning in Azeotrope. HALLIBURTON RESERVOIR SERVICES Anchorage, Alaska CUSTOMER: CONOCO, INC. ~/~/ WELL NAME: BADAMI FIELD: WILDCAT AREA: NORTH SLOPE, ALASKA INTERVAL: 10494- 11082 TEST D.~. C F.. IV F. D 29 MARCH 1992 TEST: DST #1 MAY Alaska 0ii & Gas Cons. Commis$[o. lt Anchorage HRS report coplee have been sent to the following companlee and~or Individuals: # COPIES RECIPIENT CONOCO, INC Attn: Jim Hand 3201 'C' Street, Ste 200 Anchorage, AK 99503 (907} 564-7645 ', iI,CROFILI ED · ~ HALLIBURTON RESERVOIR SERVICES REPORT TICKET NO: 007389 MEMORY GAUGE TICKET NO: 007389 DATE: 29-Mar-92 HALLIBURTON CAMP: Prudhoe Bay TESTER: M. Sachau WITNESS: J. Hand DRILLING CONTRACTOR: Nabors 26E LEGAL LOCATION: S30-T10N-R20E OPERATOR: Conoco, Inc. LEASE NAME: Wildcat WELL NO: 2 TEST NO: One TESTED INTERVAL: 10494.00 - 11082.00 FIELD AREA: Wildcat COUNTY/LSD: North SloDe STATE/PROVINCE: Alaska COUNTRY: USA ft NOTICE: THIS REPORT IS BASED ON SOUND ENGINEERING PRACTICES, BUT BECAUSE OF VARIABLE WELL CONDITIONS AND OTHER INFORMATION WHICH MUST BE RELIED UPON HALLIBURTON MAKES NO WARRANTY, EXPRESS OR IMPLIED AS TO THE ACCURACY OF THE DATA OR OF ANY CALCULATIONS OR OPINIONS EXPRESSED HEREIN. YOU AGREE THAT HALLIBURTON SHALL NOT BE LIABLE FOR ANY LOSS OR DAMAGE, WHETHER DUE'TO NEGLIGENCE OR OTHERWISE ARISING OUT OF OR IN CONNECTION WITH SUCH DATA, CALCULATIONS'.OR.'OPINIONS' TABLE OF CONTENTS SECTION 1: TEST SUMMARY & INFORMATION Summary of Test Results Test Period Summary Pressure vs. Time Plot Test and Formation Data Rate History Table Tool String Configuration Operator Job Log SECTION 2: ANALYSIS Analysis Results Analysis Plots SECTION 3: MEMORY GAUGE DATA HMR Gauge No. 10102 HMR Gauge No. 10102 HMR Gauge No. 10642 HMR Gauge No. 10014 HMR Gauge No. 10629 GRC Gauge No. 77444 GRC Gauge No. 77445 History Plot Reduced Listing History Plot History Plot History Plot History Plot History Plot SECTION 4: SURFACE TEST DATA Wellhead Conditions and Rates Plot of Flow Period Fluid Data Gas Data 1.1 1.2 1.3 1.4 1.5 1.6 1.7 2.1 2.2 3.1.0 3.1.1 3.2.0 3.3.0 3.4.0 3.5.0 3.6.0 4.1.1 4.2.1 4.3.1 Date: 29-Mar-92 Ticket No: 007389 Page No: 1.1 SUMMARY OF TEST Lease Owner: Conoco, Inc. Well No.: 2 County/LSD: North Slope Country: USA Formation Tested: Interval #1 Hole Temp: 182.00 F Total Depth: 11082.00 ft Net Pay: 88.00 ft Gross Tested Interval: 10494.00 - 11082.00 ft Perforated Interval (ft): Barefoot Test Lease Name: Wildcat Test No.: One State/Province: Alaska RECOVERY: Zone flowed oil and gas to surface Production data attached in Section'4 CALCULATED PARAMETERS FOR LIQUID WELL USING SEMI-LOG ANALYSIS: Gauge No: 10102 Gauge Depth: 10537.51 ft X-axis Function .................... Y-axis Function .................... Production Rate (bbl/D) ............ Pressure Intercept (psi) ........... Flow Capacity (md-ft) .............. Permeability (md) .................. Skin Factor ........................ Delta P due to Skin ................ Damage Ratio ....................... Flow Efficiency .................... Theoretical Rate (bbl/D) ........... Radius of Investigation (ft) ....... at Transient Time (hr) ......... Period No.: xj Pressure 342.0 6039.88 560.03 6.36 1.605 610.768 1.358 0.736 464.5 41.06 5.29 10 Period Type: BU~ REMARKS: MTR selected for this analysis 00:59:29 to 04:46:59 on 4-3-92 Date: 29-Mar-92 Ticket No: 007389 Page No: 1.2 TEST PERIOD SUMMARY ID A B B C C D D E E F F G G H H I I J J K Gauge No.: 10102 Depth: 10537.51 ft PERIOD DESCRIPTION TIME 1 2 3 4 5 6 7 8 9 10 Start Draw-down 18:13:59 End Draw-down 18:29:39 Start Build-up 18:29:39 End Build-up 21:14:39 Start Draw-down 21:14:39 End Draw-down 09:59:49 Start Build-up 09:59:39 End Build-up 23:36:49 Start Draw-down 23:36:49 End Draw-down 07:23:39 4-1 Start Build-up 07:23:39 End Build-up 09:28:09 Start Draw-down 09:28:09 End Draw-down 10:30:09 Start Build-up 10:30:09 End Build-up 00:13:49 4-2 Start Draw-down 00:13:49 End Draw-down 23:29:19 Start Build-up 23:29:19 End Build-up 00:00:29 4-4 Blanked off: No PRESSURE (psi) 3-30 3-31 6191.97 4502.21 4502.21 6120.69 6120.69 4556.26 4556.26 6079.59 6079.59 4520.46 4520.46 5041.31 5041.31 4645.37 4645.37 6011.56 6011.56 3720.06 3720.06 5906.57 DURATION 15.67 165.00 765.17 817.00 466.83 124.50 62.00 823.67 1395.50 1471.17 (min) X( (/3 L~ O_ 8 ~ ese No: Gauge No: One ~0~02 Well No: 2 PO h,.?, ~ CD r ~istor? K Company: CO['IOQO, HRS 2OO u? 0 Q© Q 0 A- Date: 29-Mar-92 Ticket No: 007389 Page No: 1.4 TEST AND FORMATION DATA Formation Tested: Interval #1 All Depths Measured From: KB Elevation: 37.00 ft Total Depth: 11082.00 ft Net Pay: 88.00 ft Hole or Casing Size: 17.000 in Gross Tested Interval: 10494.00 - 11082.00 ft Perforated Interval (ft): Barefoot Test HOLE FLUID Type: Mud Weight: 11.50 ibm/gal Viscosity: cp HOLE TEMPERATURE Depth: 10537.00 ft Estimated: 180.00 F Actual: 182.00 F HYDROCARBON PROPERTIES Oil Gravity (API): 19.0 @ 60 F Gas/Oil ratio (ScF/STB): 340.0 Gas Gravity (SG): 0.75 CUSHION DATA TYPE AMOUNT Fresh Water 10440 TVD 9975 WEIGHT 8.33 Note: BOTTOMHOLE SAMPLER DATA Bottle 49853F Time of Sampling 09:48:00 3-31 Sampler Depth 10469 ft Sampler Pressure 1425 psi Transfer Temperature 62 degf Transfer Pressure 4500 psi Outage Taken 25 cc Container Volume 750 cc Bubble Point 2300 psi 49844F 09:48:00 3-31 10469 ft 1425 psi 62 degf 4500 psi 20 cc 750 cc 2300 psi Only one bottomhole sampler functioned. Sample was transferred to two bottles. Date: 29-Mar-92 Ticket No: 007389 Page No: 1.5 RATE HISTORY TABLE Period Test j Prod Rate q(j) Duration Cum. Time t (j) No Type (bbl/D) (hrs) (hrs) 0 0.0 0.00 0.00 1 DD 1 884.0 0.26 0.26 2 BU 2 0.0 2.75 3 . 01 3 DD 3 166.0 12.75 15.76 4 BU 4 0.0 13 . 62 29.38 5 DD 5 196.0 7.78 37.16 6 BU 6 0.0 2.07 39.24 7 DD 7 91.0 1.03 40.27 8 BU 8 0.0 13.73 54.00 9 DD 9 342.0 23.26 77.26 10 BU 10 0.0 24.52 101.78 Note: Rates were derived from following production data. Period 1: Period 3: Period 5: Period 7: Period 9: 9.58 bbl cushion includes blowing down lines 88.35 bbl cushion flowed to tanks 63.59 bbl influx based on fluid level measurements 3.91 bbl influx based on fluid level measurements 315.06 bbl flowed to separator plus 16.18 bbl influx from fluid level measurement. Includes blowing down lines. Date:29-MAR-92 Page no: 1.6.1 Ticket no: TEST STRING 007389 (' CONFIGURATION CROSSOVER .................... S-15 LIFT NIPPLE ............. DRILL PIPE ..................... CROSSOVER .................... S-15 MASTER VALVE .......... O,D. (in) 5.000 J,D, (in) LENGTH (ft) DEPTH 4.275 2.680 2.680 4.700 0.850 1.850 S-15 REMOTE CONTROL VALVE S-15 FLOW TEE DOUBLE PORTED LT-20 SWIVEL ................. S-15 MASTER VALVE .......... 2.680 2.680 2.680 3.680 2.720 1.850 S-15 MASTER VALVE .......... CROSSOVER .................... TlW Valve ...................... DRILL PIPE ..................... DRILL PIPE ..................... DRILL COLLARS ................ DRILL PIPE ..................... CROSSOVER .................... APR-M2 SAFETY CIRCULATING VALVE CROSSOVER .................... DRILL COLLARS ................ CROSSOVER .................... DRAIN VALVE .................. APR OMNI CIRCULATING VALVE . CONTINUED 5.000 5.000 5.000 5.000 6.250 5.030 6,250 5.000 6.250 5.030 5.030 2.680 2.680 3.000 4.000 4.276 3.000 4.276 2.620 2.250 2.620 3.000 2.620 2.250 2.250 1.850 0.800 2462.470 7024.660 739.020 31.970 0.870 7.'540 1.110 92.300 0,940 0.970 21.150 2456.790 9480.690 10217.540 10249.280 10250.150 10257.690 10258.800 10351.100 10352,040 10353.010 10374.160 HRS Date:29-MAR-92 Ticket no: 007389 "(,'" TEST STRING CONFIGURATION Page no: 1.6.2 BI CROSSOVER .................... DRILL COLLARS ................ CROSSOVER .................... DRAIN VALVE .................. LPR-N TESTER VALVE ......... CROSSOVER .................... SAMPLE CHAMBER ............. SAMPLE CHAMBER ............. CROSSOVER .................... BUNDLE CARRIER .............. JAR ............................ VR SAFETY JOINT ............. CROSSOVER .................... RTTS CIRCULATING VALVE ..... RTTS PACKER .................. CROSSOVER .................... TUBING ......................... CROSSOVER .................... BUNDLE CARRIER .............. CROSSOVER .................... TUBING ......................... MULE SHOE .................... TOTAL DEPTH O.D. I.D. (in) (in) 6.25O 2.620 5.000 3.000 6.250 2.620 5.050 2.250 5.030 2.250 4.750 2.250 5.030 2.250 5.030 2.250 5.030 2.250 5.500 2.250 4.630 2.250 4.630 2.250 6.250 2.620 6.500 2.400 8.250 2.400 6.250 2.3OO 2.875 2.441 4.750 2.250 5.500 2.250 4.750 2.250 2.875 2.441 2.875 2.441 LENGTH (ft) 0.750 61.660 1,120 0.970 16.380 0.670 6.840 6.840 1.180 7.770 5.140 4.100 1.190 4.060 5.950 1.240 :31.520 0.650 7.770 0.750 515.740 5.930 HRS DEPTH (ft) 10374.910 10436.470 10437.590 10438.560 10454.940 10455.610 10462.450 10469.290 10470.410 10478.180 10482.480 10486.580 10487.770 10491.580 10497.330 10498.570 10530.090 10530.740 10538.510 10539.260 10855.000 10860.930 11082.00 Date: 29-Mar-92 Ticket No: 007389 Test No: One OPERATOR JOB LOG Type of Flow Measuring Device: HRS Separator Page No: 1.7.1 TIME REMARKS HH :MM: SS 29-Mar-92 04:00:00 12:15:00 13:00:.00 13:30:00 14:11:00 14:45:00 17:34:00 18:36:00 18:45:00 23:30:00 30-Mar-92 02:30:00 03:00:00 03:25:00 05:45:00 06:30:00 06:45:00 07:00:00 07:45:00 08:05:00 08:49:00 11:08:00 11:23:00 11:52:00 12:39:00 13:50:00 14:10:00 14:37:00 15:37:00 16:28:00 16:35:00 16:48:00 17:38:00 17:39:00 17:44:00 18:00:00 18:14:00 18:16:00 18:29:30 18:29:51 19:00:00 21:16:00 21:20:00 31-Mar-92 00:00:00 Charge Tools & Program Gauges Make Up Head & Stand Back. RIH w/Tubing Tailpipe Start HMR's. Pick Up Bundle Carrier. Start In Hole. LPR-N Thru Rotary. M-2 Thru Rotary. Start Running Drill Pipe. Cont. Running Drill Pipe. Tools On Bottom. Space Out. Rig Up Head. Fill Surf. Lines w/160* Brine. Test Kill & Flow LoTorc's. Test Lower Master & Swab. Test Upper Master & Swab. Pump High Vis Pill. Displace w/Brine. Displace w/H20. Finish Displacing w/1690 psi. Set Packer @ 10494 ft. Test Surface Lines. Test Separator & Valves(Fix) Test Manifold Back 5000 psi. Test Manifold Front 5000 psi. Test Safety Valve 5000 psi. Change Seals In 3" Flow Line. Open Well To Manifold 1737 psi Cycle LPR-N. Close LPR-N. Open Well & Bleed Surf. to 0 # Close Manifold. Test Drill Pipe 5000 psi. Bleed Off Drill Pipe. Open LPR-N. 1st Flow 1160 psi. Open Manifold. Close LPR-N. Close Manifold. Blow Down Surf. Lines Twice. Open LPR-N To 10/64 Choke. Open Manifold To Heater Choke. Continue To Flow Well. Date: 29-Mar-92 Test No: One Ticket No: 007389 OPERATOR JOB LOG Type of Flow Measuring Device: HRS Separator Page No: 1.7.2 TIME REMARKS HH :MM: SS 31-Mar-92 09:48:00 10:00:00 10:02:00 10:32:00 10:59:00 14:10:00 14:30:00 14:53:00 17:00:00 17:30:00 17:50:00 21:30:00 22:15:00 23:00:00 23:15:00 23:25:00 23:36:00 23:57:38 1-Apr-92 00:00:00 00:23:00 00:39:00 00:45:00 00:50:00 01:23:00 01:25:00 01:30:00 01:45:00 02:00:00 02:30:00 03:00:00 03:30:00 04:00:00 04:30:00 05:00:00 05:30:00 06:00:00 06:30:00 07:00:00 07:20:00 09:00:00 09:20:00 09:30:00 09:33:00 10:30:00 Press Annulus to trip sampler Close LPR-N & Manifold. Cycle OMNI To Reverse Position Start Reversing Out. Brine Returns, Oil, Mud. Finish Reversing Out. Rig UD BJ To Clear Flowlines. Rig Steam To Flow Lines. Continue To Clear Lines & Tank Rig Up & Test BJ N2 Lines. Start N2 Downhole. Finish N2. Shoot FL. 9548'. Cycle OMNI To Blank Position. Shoot Fluid Level 9140'. Bleed N2 to 3800 Surf. psi. Close Manifold & Cycle OMNI. Open To Well Test Position. ODen Manifold w/3872 psi. Shoot FL 8794'. Shoot FL 8700'. Shoot FL 8600'. Close LPR-N. Shoot FL. Open LPR-N w/3406 Surface psi. Shoot FL 8480'. ODen Manifold. Shoot Fl. 7522 ft Shoot FL 8266'. Shoot FL 8072'. Shoot FL 7883'. Shoot FL 7632'. Shoot FL 7318'. Shoot FL 6941 Shoot FL 6658'. Shoot FL 6344'. Shoot FL 6062'. Shoot FL 5847'. Shoot FL 5559'. Close Manifold. Swab Leaking. Install Tree Cap. Close Master & Blow Down Lines Close Manifold. Open Master. Shoot FL 5873'. Shoot FL 5653'. Date: 29 -Mar- 92 Test No: One Ticket No: 007389 OPERATOR JOB LOG Type of Flow Measuring Device: HRS Separator Page No: 1.7.3 TIME HH :MM: SS REMARKS 1-Apr-92 10:38:00 13:51:00 14:45:00 14:46:00 14:47:00 16:45:00 17:00:00 17:03:00 18:22:00 18:24:00 20:00:00 21:25:00 21:59:00 22:13:00 22:28:00 23:58:00 2-Apr-92 00:14:40 00:27:45 02:04:00 02:06:00 02:30:00 02:50:00 03:25:00 03:30:00 03:55:00 04:03:00 04:22:00 23:16:00 23:30:30 3-Apr-92 01:18:00 01:20:00 01:30:00 23:58:00 4-Apr-92 00:02:00 01:08:00 01:20:00 02:10:00 02:11:00 03:15:00 03:45:00 04:00:00 05:22:00 Close master, rig up SWS RIH w/Schlumberger. Open Well To Manifold. To Monitor Perf. Shot. W/L Could Not Pass 10468. POOH Shoot FL 3235'. Shoot FL 3141'. Close LPR-N. Shoot FL 3235'. Open Manifold & Bleed Press 0# Rig Up Otis Lubricator Shoot Fl. 2748 ft. Make Up GRC Gauges 77444,77445 Pressure Test Lubricator R.I.H. w/Wireline Shoot F1 2921 Ft. Open LPR-N Open Manifold to Flow Lines Shut manifold, Shoot Fi 2010 ft Open manifold and well R.I.H. to check depth of fill P.O.O.H. w/ Wireline & Gauges Fluid to surface Close manifold to catch sample Otis to surface with gauges Shut in well to rig down Lub. Open well to separator Trip sampler at 3200 psi Close in at LPR-N for build-up Close upper master Blow down surface lines Continue Build -Up Open master valve to manifold Cycle OMNI to circulating post Reverse well fluid, 19.5 bbl Start full reverse Mud to surface Shut down to blow out lines Pump diesel to clear lines Continue to blow lines w/ air Rig down surface lines Cycle Omni to well test post. Date: 29-Mar-92 Test No: One Ticket No: 007389 OPERATOR JOB LOG Type of Flow Measuring Device: HRS Separator Page No: 1.7.4 TIME REMARKS HH:MM:SS 4-Apr-92 05:55:00 06:00:00 06:05:.00 06:20:00 07:08:00 07:20:00 07:45:00 09:00:00 09:20:00 09:45:00 10:30:00 11:23:00 Rig up to bullhead into well Open LPR-N Bullhead into formation 3bbls Cycle omni to cir. position Open by-pass on packer PumD down annulus 70 bbl Shut down observe well 30 bbls returned to pits Rig down surface lines & tree Unseat packer Stand tree back Start to P.O.O.H. w drillpipe Date: 29 -Mar- 92 Ticket No: 007389 Page No: 2.1.1 RESERVOIR PARAMETERS USING SEMI-LOG METHOD FOR LIQUID WELLS Oil Gravity: ...................... Gas Gravity: Gas/Oil Ratio: .................... Well Bore Radius: ................. Net Pay: ......................... Porosity: .... Water Salinity Fluid Properties Reference: ...... Formation Temperature: ........... Viscosity: ................... Formation V~e Factor Total System Compressibility: .... Bubble Point: .................... Gauge number: Gauge Depth (ft): Test Period: Period Type: X-axis Function: Y-axis Function: Period Start Press. (psi): y Intercept (91 Units): Pressure Intercept (psi): Slope (#2 Units): Sy (91 units): Production Rate (bbl/D): Flow Capacity (md-ft): Permeability (md): Skin Factor: Delta P due to Skin (psi): Damage Ratio: Flow Efficiency: Theoretical Rate (bbl/D): Rad. of Investigation (ft): at Transient Time ( hr): 19.0 API@ 60 F ...................... . ...... 0.~0 s~ ..... ~0.0 sc~s~ ................. . ......... 0.70~ ~t ................. 8~.00 et ............................ 6.6i~0.00 ~ % SALT ........ 6121· 0 psi ............................ 3.750 cp .... A~ 666 x i0i'~v~ ~o~zsvo~ ^-6 vol/vol/psi ......... 2782 39 psi · · · · · · · · · · · · · · · · · · · · · · · · · · 10102 10102 10537.51 10537.51 10 10 Build-up Build-up xj xj Pressure Pressure 3720.06 3720.06 6039.882 6078.71 6039.882 6078.71 438.017 497.04 0.126 1.4361 Note: REMARKS: 342.0 342.0 560.03 493.53 6·36 5.61 1.605 1.034 610.768 446.580 1.358 1.234 0.736 0.810 464.5 422.04 41.06 64.61 5.29 24.519 91 Units = psi for Pressure Y-axis function. 91 Units = psi/bbl/D for dp/dq Y-axis function. 92 Units = psi/cy for Pressure Y-axis function. 92 Units = psi/cy/bbl/D for dp/dq Y-axis function. MTR for Period 10: 00:59:29 to 04:46:59 Additional analysis run using points 06:47:49 4-3 to 00:00:29 4-4-92 4-3 -92 Pressure Vs Delta Time 6.4 6.0 X 4.4 4.0 tes~ N~): 'On& ' I ' ' ' Gouge No: 10102 - PeFiod No: 1 Well: 2 - Company: Conoco, Inc. _ Analyst: M. Sachau -- I I I I ' ' ' I I I I I ' ' ' I ' ' ' I ' I I I ' ' ' I ' ' ' I ' ' ' -0.04 0.00 0.04 0.08 0.12 0.16 0.20 0.24 0.28 0.32 Delt~ Time (hours) initial Flow Z Pressure Vs Delta Time 6.9 tI X I · I I . ~ I ~ I ~ ~ ~ I ~ ~ ~ I ~ ~ ~ I 0.~ 0.8 1.2 1.6 2.0 Delta Time (hours) I Test No: One I i Gauge No: 10102 Period No: 2 Well: 2 I Company: Conoco, Inc. I ~Ana?sti M. Sachau · . I I I I I I 2.4 2.8 Initial Buildup I Z 0 0 --.4 O0 Z Pressure Vs Delta Time X 6.5 6.0 5.7 5.4 5.1 4.8 4.5 I I [ I I I I I I I I I [ I [ I I I [ I ''~est ~):'' One I - Gouge No: 10102 Period No: 3 - Well: 2 - Company: Conoco, Inc. - Analyst: M. Sachau _- I I J I I [ I i I I I I I I ii 14 16 Delte Time (hours) 2nd Flow 0 o -,4 O4 CO Pressure Vs Delte Time X 6.5 6.0 5.5 5.0 4.5 4.0 3.5 Gauge No: 10102 Period No: 5 Well: 2 Company: Conoco, Inc. Analyst: M. Sachau ._. "~~~~~~~~~jj~~~~~j~jjjjjjjjjjjjjjjj~~jj~j~~~~~~~~~j~~~~~~~~~j~~~~~~~~~j~~~~~~~~~j~~~j~~~~~" -1 0 1 2 3 4 5 6 7 8 Delta Time (hours) 3rd Flow Pressure Vs Delta Time 6.6 6.0 X 3.6 3.0 '1 t~ N&: 'o~& ' I''' _ I Gauge No: 10102 ; Period No: 9 - Well: 2 _- Company: Conoco, Inc. - Analyst: M. Sachau - Delta Time (hours) 4th Flow 0 0 ..j (3o Z Pressure Vs Delta Time 6.5 6.0 X 4.0 3.5 Test No: One Gauge No: 10102 Period No: 10 Well: 2 I ~ompany: Conoco, Inc, nal?sti M. Sachau I I I I I I I 24 28 Delta Time (hours) Buildup 0 0 --4 04 Oo DERIVATIVE LOG-LOG PLOT 102 10 1 I I I I ! I I ! I I I I I I I i I I ! I I I I ! ' I I ] I I I [ ! I - Test No: One - Gauge No: 10102 - period No: 10 - Well: 2 _ Company: ConocO, Inc. Anolyst: M. Sochou - Tronsient Time: 101.78 hr ! I I I - ~ 'echnique: Derive[ive ' ~ ~ Slope Between Pts. I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 10 -3 10 -2 10 -1 10 o 10 ~ 10 2 Equivolen( Time Buildup 0 0 --4 04 OO SEMI-LOG PLOT 6.5 6.0 X 4.0 3.5 I I I I I I I I - .% --Test No: One _ Gauge No: 10102 Period No: 10 - Well: 2 _ Company: Conoco, Inc. Analyst: M. Sachau Transient Time: 101.78 hr I I I I I I II/ 10 o 10 ~ I I I I I I I J I I i I I I I Iii 102 I Jl I I I I '-J I i I II I I I Slope = 458.02 psi/cy ' Y at 1 = 6059.9 psi J kh = 560.0 md-ft I k = 6.364 md j Skin = 1.61 · ! I I I I I I I I I I I I I I I 10 4 10 5 I I I I I I 0 _ 0 - O0 -- Superposition Time Buildup SEMI-LOG PLOT 6.5 6.0 X 4.0 3.5 f [ i ! I I [ t Ill I ! ! I ! I I I ! I I I I I 1 -- Test No: One _ Gauge No: 10102 Period No: 10 - Well: 2 _ Company: Conoco, Inc. Analyst: M. Sachau Transient Time: 101.78 hr I I I I I I II / 10 o 10 1 I I ~ I I II 10 2 I I I I I I I [ I I I I I I I I I I I Slope = z~97.0z~ psi/c¥ - Y at 1 = 6078.7 psi kh = 493.5 md-ft - k = 5.608 md - Skin = 1.05 _ I I I I I I I I 10 3 10 4 I I I I I I I I ~0s Superposition Time Buildup Z 0 0 ~4 Z 8 0 ~es[ No: One Gauge No: 10 E ~ / ~o HRS ~4 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.1 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 29-Mar-92 Data Print Frequency: 04:00:00 12:15:00 13:00:.00 13:30:00 13:39:04 13.329 70.781 14:11:00 14:39:04 16.171 84.276 14:45:00 15:43:04 24.206 55.192 16:47:04 43.166 52.850 17:34:00 17:47:04 99.779 53.381 18:36:00 18:45:00 18:51:04 196.491 53.805 19:07:04 425.558 52.284 19:23:04 660.662 54.434 19:35:04 897.701 56.688 19:47:04 1130.926 58.175 20:07:04 1355.862 63.711 20:27:04 1617.699 68.316 20:47:04 1905.100 72.106 21:07:04 2173.733 74.925 21:27:04 2391.463 80.772 21:43:04 2634.564 84.428 22:03:04 2861.002 88.002 22:23:04 3153.906 92.865 22:43:04 3396.009 96.510 23:07:04 3645.445 103.889 23:23:04 3981.512 108.771 23:30:00 23:59:04 4194.815 118.444 30-Mar-92 00:11:04 4461.091 123.173 00:35:04 4734.278 132.031 00:55:04 4999.776 134.880 01:11:04 5308.108 137.880 01:19:04 5556.124 141.625 01:39:39 5765.309 147.386 01:47:59 5976.956 151.809 02:01:29 6196.913 157.026 02:23:39 5964.969 164.046 02:23:59 6190.322 164.099 02:30:00 03:00:00 03:12:39 6392.752 164.775 Charge Tools & Program Gauges Make Up Head & Stand Back. RIH w/Tubing Tailpipe Start HMR's. Pick Up Bundle Carrier. Start In Hole. LPR-N Thru Rotary. M-2 Thru Rotary. Start Running Drill Pipe. Cont. Running Drill Pipe. Tools On Bottom. Space Out. Date: 29-Mar-92 Ticket No: (" 007389 Page No: 3.1.2 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 30 -Mar- 92 03:25:00 Data Print Frequency: 1 Rig Up Head. 03:36:19 6112.619 166.488 03:46:19 6333.781 165.943 04:47:49 6254.622 168.471 05:45:00 05:48:49 6237.717 168.828 06:30:00 06:45:00 06:50:49 6225.689 169.132 07:00:00 07:45:00 07:49:29 6448.867 169.433 08:05:00 08:48:49 6247.854 146.712 08:49:00 09:49:09 6372.204 143.127 10:49:19 6379.130 138.319 11:05:39 6178.084 139.623 11:08:00 11:23:00 11:52:00 12:05:49 6159.026 144.358 12:39:00 13:05:49 6163.634 148.509 13:50:00 14:05:59 6166.293 152.063 14:10:00 14:37:00 15:06:39 6167.991 154.904 15:37:00 16:07:29 6168.738 157.345 16:28:00 16:35:00 16:48:00 17:08:49 6179.274 159.247 17:38:00 17:39:00 17:44:00 18:00:00 18:09:59 6180.481 160.841 18:13:49 6184.629 160.903 Fill Surf. Lines w/160' Brine. Test Kill & Flow LoTorc's. Test Lower Master & Swab. Test Upper Master & Swab. Pump High Vis Pill. Displace w/Brine. Displace w/H20. Finish Displacing w/1690 psi. Set Packer @ 10494 ft. Test Surface Lines. Test Separator & Valves(Fix) Test Manifold Back 5000 psi. Test Manifold Front 5000 psi. Test Safety Valve 5000 psi. Change Seals In 3" Flow Line. Open'Well To Manifold 1737 psi Cycle LPR-N. Close LPR-N. Open Well & Bleed Surf. to Close Manifold. Test Drill Pipe 5000 psi. Bleed Off Drill Pipe. 0 # Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.3 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 Gauge Depth: 10537.51 ft TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) COMMENTS 30-Mar-92 18:13:59 0.0000 18:14:00 18:14:09 0.0028 18:14:19 0.0056 18:14:29 0.0083 18:14:39 0.0111 18:14:59 0.0167 18:15:19 0.0222 18:15:49 0.0306 18:16:00 18:16:09 0.0361 18:16:19 0.0389 18:16:29 0.0417 18:16:39 0.0444 18:16:49 0.0472 18:16:59 0.0500 18:17:19 0.0556 18:17:29 0.0583 18:17:39 0.0611 18:17:49 0.0639 18:17:59 0.0667 18:18:09 0.0694 18:18:19 0.0722 18:18:29 0.0750 18:18:39 0.0778 18:19:19 0.0889 18:19:29 0.0917 18:21:09 0.1194 18:27:19 0.2222 18:29:30 18:29:39 0.2611 Data Print Frequency: 1 *** Start of Period 1 *** 6191.974 160.901 6020.698 160.902 5479.765 160.693 5450.563 160.731 5491.777 160.767 5522.960 160.843 5557.338 160.923 5600.147 161.042 5554.138 161.123 5467.048 161.134 5380.149 161.145 5307.271 161.156 5246.108 161.167 5187.196 161.188 5075.946 161.230 4957.695 161.252 4844.096 161.275 4751.215 161.296 4675.925 161.318 4616.805 161.339 4572.966 161.360 4537.497 161.381 4509.748 161.426 4540.988 161.588 4504.825 161.616 4479.037 161.814 4506.743 162.073 Open LPR-N. 1st Flow 1160 psi. Open Manifold. Close LPR-N. 4502.215 162.196 *** End of Period 1 *** Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.4 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 30-Mar- 92 18:29:49 0.0028 18:29:51 18:29:.59 0.0056 18:30:09 0.0083 18:30:19 0.0111 18:30:29 0.0139 18:30:39 0.0167 18:30:49 0.0194 18:30:59 0.0222 18:31:09 0.0250 18:31:19 0.0278 18:31:29 0.0306 18:31:39 0.0333 18:31:49 0.0361 18:31:59 0.0389 18:32:09 0.0417 18:32:19 0.0444 18:32:39 0.0500 18:32:59 0.0556 18:33:19 0.0611 18:33:39 0.0667 18:33:59 0.0722 18:34:19 0.0778 18:34:39 0.0833 18:34:59 0.0889 18:35:19 0.0944 18:35:39 0.1000 18:36:19 0.1111 18:36:59 0.1222 18:37:39 0.1333 18:38:19 0.1444 18:38:59 0.1556 18:39:39 0.1667 18:40:39 0.1833 18:41:39 0.2000 18:42:39 0.2167 18:44:19 0.2444 18:45:39 0.2667 18:48:39 0.3167 18:50:19 0.3444 18:52:39 0.3833 18:55:59 0.4389 19:00:00 19:00:39 0.5167 19:10:49 0.6861 Data *** 4548 Print Frequency: 1 Start of Period 2 *** .421 162.204 4608.475 162.212 4664.095 162.219 4716.062 162.227 4763.715 162.235 4808.345 162.243 4849.971 162.251 4889.309' 162.259 4926.558 162.267 4961.435 162.274 4994.434 162.282 5025.693 162.290 5055.658 162.298 5083.867 162.306 5111.127 162.309 5136.995 162.313 5185.505 162.320 5230.654 162.327 5272.872 162.334 5312.369 162.341 5348.873 162.349 5381.882 162.356 5413.087 162.363 5443.252 162.371 5471.161 162.378 5496.387 162.386 5541.244 162.401 5581.648 162.416 5618.794 162.431 5651.452 162.447 5679.287 162.462 5705.119 162.478 5739.370 162.501 5768.965 162.525 5795.167 162.548 5825.529 162.588 5851.154 162.619 5881.345 162.691 5906.812 162.730 5932.526 162.779 5959.416 162.825 5985.889 162.879 6011.774 162.996 Close Manifold. Blow Down Surf. Lines Twice. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.5 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 30-Mar-92 Data Print Frequency: 19:29:49 1.0028 6037.264 163.185 19:44:29 1.2472 6009.923 163.323 19:49:59 1.3389 6035.831 163.380 19: 59 :.09 1.4917 6061. 287 163.493 20:20:29 1.8472 6086.958 163.811 21:05:29 2.5972 6112.113 164.392 21:14:09 2.7417 6120.409 164.538 21:14:39 2.7500 6120.687 164.547 21:16:00 Open LPR-N To 10/64 Choke. End of Period 2 *** Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.6 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 30-Mar-92 Data Print *** Start 21:16:09 0.0250 5840.560 21:16:19 0.0278 5559.739 21:16:29 0.0306 5343.056 21:16:59 0.0389 5383.635 21:17:29 0.0472 5417.149 21:17:59 0.0556 5455.472 21:18:39 0.0667 5498.704 21:19:09 0.0750 5450.928 21:19:19 0.0778 5366.168 21:19:29 0.0806 5290.485 21:19:39 0.0833 5206.021 21:19:49 0.0861 5101.951 21:19:59 0.0889 5013.945 21:20:00 21:20:09 0.0917 4931.946 21:20:19 0.0944 4867.967 21:20:29 0.0972 4811.837 21:20:39 0.1000 4773.412 21:20:49 0.1028 4736.091 21:20:59 0.1056 4704.518 21:21:09 0.1083 4674.749 21:21:29 0.1139 4637.169 21:21:59 0.1222 4607.509 21:27:59 0.2222 4638.104 21:28:59 0.2389 4667.325 21:30:39 0.2667 4641.176 21:31:29 0.2806 4615.972 21:42:39 0.4667 4646.742 22:00:59 0.7722 4614.549 22:06:29 0.8639 4642.416 22:06:49 0.8694 4614.864 22:08:59 0.9056 4574.995 22:09:09 0.9083 4607.201 22:10:29 0.9306 4633.458 22:10:39 0.9333 4605.670 22:19:19 1.0778 4580.488 22:22:19 1.1278 4539.408 22:23:29 1.1472 4576.783 22:25:49 1.1861 4616.193 22:25:59 1.1889 4647.431 22:26:19 1.1944 4602.451 22:26:29 1.1972 4567.141 22:27:39 1.2167 4595.732 22:27:59 1.2222 4562.738 22:36:59 1.3722 4528.240 Frequency: of Period 3 164.482 164.395 164.307 164.386 164.466 164.530 164.607 164.631 164.618 164.604 164.590 164.577 164.563 164.550 .164.557 164.563 164.570 164.576 164.582 164.596 164.622 164.662 165.033 165.063 165.093 165.098 165.237 165.879 166.055 166.065 166.125 166.129 166.164 166.169 166.394 166.469 166.497 166.554 166.557 166.566 166.571 166.588 166.592 166.769 Open Manifold To Heater Choke. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.7 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 Gauge Depth: TIME D TIME PRESSURE TEMP HH:MM: SS (min) (psi) (F) COMMENTS 30-Mar-92 Data Print Frequency: 22:37:09 1.3750 4584.880 166.771 22:39:29 1.4139 4559.365 166.818 22:51:29 1.6139 4585.606 167.138 22:51:.39 1.6167 4558.128 167.143 22:53:09 1.6417 4585.652 167.176 22:53:49 1.6528 4560.453 167.192 22:54:09 1.6583 4612.612 167.198 22:54:39 1.6667 4554.885 167.210 23:16:49 2.0361 4595.336 167.721 23:17:09 2.0417 4566.412 167.727 23:29:09 2.2417 4624.134 167.884 23:29:49 2.2528 4593.371 167.902 23:29:59 2.2556 4554.976 167.900 23:48:09 2.5583 4596.755 168.315 23:48:19 2.5611 4722.848 168.331 23:48:39 2.5667 4610.055 168.335 23:49:49 2.5861 4578.210 168.333 23:58:29 2.7306 4552.650 168.452 23:59:59 2.7556 4578.359 168.472 31-Mar-92 00:00:00 00:02:19 00:02:59 00:03:19 00:23:09 00:23:29 00:34:29 00:38:09 00:41:19 00:43:19 01:29:49 01:31:49 01:32:49 01:32:59 01:33:39 01:34:29 01:34:39 02:02:39 02:03:29 02:05:49 02:20:19 02:22:59 02:23:19 02:25:49 02:26:09 02:26:19 2.7944 4644.048 168.521 2.8056 4597.964 168.538 2.8111 4569.401 168.532 3.1417 4600.869 168.714 3.1472 4573.518 168.717 3.3306 4547.130 168.836 3.3917 4574.051 168.909 3.4444 4601.021 168.968 3.4778 4574.612 168.996 4.2528 4548.784 169.751 4.2861 4582.559 169.788 4.3028 4621.991 169.825 4.3056 4677.215 169.830 4.3167 4650.280 169.836 4.3306 4614.514 169.817 4.3333 4570.719 169.814 4.8000 4603.813 170.257 4.8139 4631.426 170.271 4.8528 4602.520 170.273 5.0944 4568.859 170.331 5.1389 4542.298 170.388 5.1444 4595.953 170.394 5.1861 4722.677 170.488 5.1917 4678.723 170.509 5.1944 4590.517 170.500 Continue To Flow Well. 10537.51 ft Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.8 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 31-Mar-92 Data Print Frequency: 02:26:49 5.2028 4877.165 170.566 02:26:59 5.2056 4737.486 170.554 02:27:19 5. 2111 4693. 686 170. 523 02:27:29 5.2139 4667.289 170.508 02:27:49 5.2194 4629.966 170.492 02:32:39 5.3000 4661.889 170.472 02:34:09 5.3250 4694.208 170.491 02:40:29 5.4306 4723.368 170.607 02:41:39 5.4500 4766.201 170.672 02:41:49 5.4528 4793.077 170.683 02:42:09 5.4583 4841.025 170.706 02:42:29 5.4639 4885.687 170.729 02:42:59 5.4722 4953.358 170.763 02:43:19 5.4778 4999.802 170.785 02:43:49 5.4861 5063.002 170.802 02:44:09 5.4917 5101.250 170.813 02:44:29 5.4972 5136.707 170.825 02:44:49 5.5028 5169.513 170.836 02:45:19 5.5111 5213.145 170.853 02:45:39 5.5167 5238.169 170.865 02:46:59 5.5389 5272.140 170.912 02:47:19 5.5444 5297.944 170.923 02:47:39 5.5500 4859.267 170.813 02:47:49 5.5528 4913.401 170.810 02:47:59 5.5556 4852.722 170.809 02:48:09 5.5583 4827.028 170.808 02:48:19 5.5611 4732.615 170.809 02:48:29 5.5639 464'4.591 170.809 02:48:49 5.5694 4610.545 170.806 02:49:19 5.5778 4637.253 170.800 03:50:39 6.6000 4635.567 171.227 04:50:39 7.6000 4632.516 171.725 05:00:49 7.7694 4677.946 171.942 05:01:29 7.7806 4647.539 171.966 05:01:39 7.7833 4622.237 171.972 05:03:09 7.8083 4593.442 172.025 05:03:49 7.8194 4630.548 172.048 05:04:39 7.8333 4671.014 172.065 05:15:29 8.0139 4645.857 172.069 05:20:09 8.0917 4672.684 172.140 05:20:19 8.0944 4707.764 172.142 05:20:49 8.1028 4736.552 172.149 05:21:09 8.1083 4764.713 172.153 05:21:29 8.1139 4791.273 172.158 05:21:49 8.1194 4833.142 172.162 05:22:19 8.1278 4873.803 172.169 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.9 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 31-Mar-92 Data Print Frequency: 05:22:59 8.1389 4912.474 172.179 05:23:29 8.1472 4945.482 172.186 05:24:29 8.1639 4986.871 172.200 05:24:.49 8.1694 5014.556 172.205 05:25:09 8.1750 5045.800 172.209 05:25:29 8.1806 5072.920 172.214 05:25:59 8.1889 5108.694 172.221 05:26:29 8.1972 5139.302 172.228 05:27:09 8.2083 5175.394 172.238 05:27:39 8.2167 5202.767 172.245 05:28:19 8.2278 5233.373 172.254 05:29:29 8.2472 5258.464 172.272 05:31:59 8.2889 5226.235 172.281 05:32:49 8.3028 5182.095 172.284 05:32:59 8.3056 5144.209 172.286 05:33:19 8.3111 5116.729 172.276 05:33:29 8.3139 5045.925 172.273 05:33:49 8.3194 5018.679 172.263 05:33:59 8.3222 4991.402 172.259 05:34:09 8.3250 4960.567 172.255 05:34:29 8.3306 4920.878 172.245 05:34:49 8.3361 4885.513 172.236 05:35:09 8.3417 4859.822 172.227 05:35:39 8.3500 4834.546 172.215 05:36:39 8'.3667 4805.640 172.192 06:36:49 9.3694 4811.073 172.271 06:37:49 9.3861 4782.027 172.276 06:37:59 9.3889 4743.137 172.277 06:38:29 9.3972 4784.646 172.278 06:40:19 9.4278 4723.520 172.287 06:40:39 9.4333 4773.855 172.288 06:40:59 9.4389 4739.968 172.290 06:41:09 9.4417 4708.917 172.291 06:41:29 9.4472 4808.713 172.290 06:41:39 9.4500 4782.002 172.292 06:43:49 9.4861 4750.005 172.301 06:44:19 9.4944 4797.721 172.302 06:44:29 9.4972 4734.805 172.304 06:44:39 9.5000 4706.935 172.305 06:44:59 9.5056 4784.729 172.305 06:45:09 9.5083 4752.635 172.306 06:45:19 9.5111 4717.009 172.308 06:45:59 9.5222 4756.486 172.310 06:47:19 9.5444 4730.963 172.317 06:47:39 9.5500 4756.772 172.318 06:47:49 9.5528 4782.623 172.318 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.10 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 31-Mar-92 Data Print Frequency: 06:48:19 9.5611 4751.594 172.321 06:48:29 9.5639 4810.966 172.321 06:50:09 9.5917 4774.555 172.329 07:01:.09 9.7750 4810.802 172.416 07:04:19 9.8278 4847.189 172.457 07:04:39 9.8333 4819.367 172.462 07:06:19 9.8611 4850.647 172.513 07:06:39 9.8667 4824.694 172.533 07:07:39 9.8833 4795.346 172.592 07:10:09 9.9250 4825.049 172.736 07:18:39 10.0667 4867.065 173.005 07:19:09 10.0750 4899.379 173.007 07:19:19 10.0778 4857.495 173.009 07:20:09 10.0917 4892.222 173.013 07:20:39 10.1000 4919.431 173.006 07:21:09 10.1083 4891.449 173.000 07:21:29 10.1139 4861.181 172.996 07:22:19 10.1278 4896.300 172.984 07:25:29 10.1806 4940.506 172.941 07:26:39 10.2000 4900.331 172.926 07:27:19 10.2111 4926.859 172.917 07:28:39 10.2333 4761.863 172.860 07:28:49 10.2361 4878.132 172.895 07:28:59 10.2389 4729.639 172.875 07:29:19 10.2444 4859.012 172.910 07:29:29 10.2472 4786.877 172.918 07:29:39 10.2500 4941.590 172.922 07:29:49 10.2528 4913.723 172.920 07:29:59 10.2556 4881.664 172.918 07:30:59 10.2722 4910.322 172.904 07:31:19 10.2778 4868.543 172.900 07:32:09 10.2917 4905.477 172.895 07:32:39 10.3000 5003.012 172.892 07:35:29 10.3472 4973.978 172.884 07:38:19 10.3944 4941.495 172.851 07:38:49 10.4028 4913.226 172.845 07:39:59 10.4222 4885.420 172.832 07:41:49 10.4528 4854.472 172.810 07:52:09 10.6250 4823.409 172.810 07:52:19 10.6278 4783.788 172.806 07:52:29 10.6306 4749.520 172.801 07:52:39 10.6333 4806.709 172.795 07: 55: 19 10. 6778 4767. 629 172. 844 07:56:39 10.7000 4798.187 172.860 07: 59:19 10.7444 4835. 381 172. 889 08:01:19 10.7778 4860.410 172.904 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.11 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 31 -Mar- 92 08:05:29 08:06:19 08:06:39 08:07:39 08:08:19 08:08:29 08:10:19 08:11:09 08:12:29 08:15:59 08:16:09 08:16:29 08:16:49 08:25:09 08:25:39 08:25:49 08:26:09 08:29:09 08:31:49 08:32:29 08:32:59 08:33:29 08:33:39 08:36:19 08:36:59 08:37:09 08:38:19 08:38:29 08:38:49 08:39:09 08:40:39 08:41:39 08:41:49 08:42:09 08:44:29 08:44:39 08:45:29 08:45:39 08:45:49 08:45:59 08:46:29 08:46:59 08:47:29 08:49:39 08:50:39 08:50:49 Data Print Frequency: 10.8472 4886.846 172.948 10.8611 4846.788 172.956 10.8667 4815.165 172.959 10.8833 4757.111 172.969 10.8944 4813.768 172.973 10.8972 4774.857 172.975 10.9278 4806.884 172.990 10.9417 4779.946 172.998 10.9639 4816.199 173.008 11.0222 4843.065 173.037 11.0250 4878.835 173.038 11.0306 4850.510 173.041 11.0361 4825.050 173.044 11.1750 4890.655 173.068 11.1833 4917.786 173.069 11.1861 4881.195 173.070 11.1917 4825.196 173.072 11.2417 4851.054 173.080 11.2861 4879.780 173.112 11.2972 4908.085 173.121 11.3056 4878.961 173.129 11.3139 4848.121 173.137 11.3167 4821.820 173.140 11.3611 4795.032 173.203 11.3722 4763.061 173.214 11.3750 4805.471 173.216 11.3944 4832.365 173.259 11.3972 4928.517 173.264 11.4028 4960.539 173.277 11.4083 4993.633 173.290 11.4333 5036.583 173.266 11.4500 4988.063 173.271 11.4528 4939.840 173.272 11.4583 4986.509 173.270 11.4972 4951.067 173.268 11.5000 4978.036 173.267 11.5139 4890.588 173.259 11.5167 4850.489 173.255 11.5194 4877.112 173.249 11.5222 4840.355 173.245 11.5306 4878.957 173.244 11.5389 4922.831 173.270 11.5472 4884.166 173.284 11.5833 4911.572 173.286 11.6000 4965.637 173.283 11.6028 4932.509 173.283 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.12 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 31-Mar-92 Data Print Frequency: 08:50:59 11.6056 5018.830 173.293 08:51:19 11.6111 4958.351 173.294 08:51:39 11.6167 4925.193 173.271 08:51:.49 11.6194 5060.007 173.291 08:52:09 11.6250 5114.171 173.311 08:52:29 11.6306 5148.662 173.309 08:53:09 11.6417 5174.583 173.304 08:55:39 11.6833 5138.167 173.270 09:02:09 11.7917 5168.375 173.288 09:09:19 11.9111 5195.389 173.298 09:25:49 12.1861 5256.655 173.269 09:26:09 12.1917 5197.785 173.269 09:26:19 12.1944 5133.112 173.270 09:26:39 12.2000 5234.282 173.267 09:26:49 12.2028 5183.077 173.267 09:26:59 12.2056 5152.382 173.267 09:27:19 12.2111 5124.247 173.267 09:27:29 12.2139 5263.623 173.263 09:27:59 12.2222 5228.803 173.262 09:28:19 12.2278 5144.443 173.263 09:28:29 12.2306 5256.942 173.260 09:28:49 12.2361 5289.307 173.258 09:29:29 12.2472 5160.693 173.258 09:29:39 12.2500 5064.439 173.246 09:29:59 12.2556 5170.232 173.249 09:30:29 12.2639 5090.004 173.257 09:30:39 12.2667 5023.346 173.225 09:30:49 12.2694 4889.562 173.193 09:30:59 12.2722 5047.341 173.204 09:31:09 12.2750 4961.499 173.219 09:31:29 12.2806 4931.862 173.205 09:31:59 12.2889 4901.132 173.185 09:32:09 12.2917 4812.945 173.168 09:32:19 12.2944 4762.472 173.150 09:32:39 12.3000 4689.840 173.114 09:32:49 12.3028 4655.601 173.095 09:33:09 12.3083 4609.180 173.077 09:33:29 12.3139 4579.563 173.059 09:34:49 12.3361 4553.232 172.984 09:38:49 12.4028 4587.585 172.879 09:38:59 12.4056 4617.097 172.883 09:39:39 12.4167 4666.799 172.899 09:39:49 12.4194 4694.288 172.903 09:39:59 12.4222 4723.113 172.907 09:40:39 12.4333 4752.740 172.898 09:41:19 12.4444 4712.599 172.881 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.13 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 Gauge Depth: 10537.51 ft TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) COMMENTS 31-Mar-92 Data Print Frequency: 09:41:49 12.4528 4677.280 172.868 09:42:09 12.4583 4748.443 172.867 09:42:19 12.4611 4681.420 172.872 09:44:.49 12.5028 4718.386 172.921 09:45:09 12.5083 4788.002 172.938 09:45:29 12.5139 4852.068 172.954 09:45:49 12.5194 4895.204 172.972 09:46:09 12.5250 4921.333 172.989 09:46:29 12.5306 4954.494 173.007 09:46:59 12.5389 4990.265 173.033 09:47:09 12.5417 5017.990 173.041 09:47:29 12.5472 5060.892 173.059 09:47:49 12.5528 5089.269 173.076 09:48:00 09:48:09 12.5583 5115.214 173.094 09:48:39 12.5667 5075.826 173.093 09:48:49 12.5694 5115.222 173.073 09:48:59 12.5722 5063.450 173.054 09:49:09 12.5750 4879.154 173.038 09:49:19 12.5778 4690.339 173.009 09:49:29 12.5806 4615.052 172.976 09:49:49 12.5861 4646.211 172.995 09:52:59 12.6389 4618.701 173.052 09:53:29 12.6472 4591.097 173.051 09:54:09 12.6583 4621.870 173.058 09:54:19 12.6611 4649.143 173.062 09:54:29 12.6639 4622.830 173.067 09:54:49 12.6694 4653.089 173.075 09:54:59 12.6722 4737.160 173.078 09:55:09 12.6750 4624.194 173.085 09:55:19 12.6778 4576.614 173.077 09:55:39 12.6833 4540.852 173.060 09:57:39 12.7167 4570.477 173.021 09:59:39 12.7500 4557.114 173.005 09:59:49 12.7528 4556.256 173.004 10:00:00 *** End of Period 3 Press Annulus to trip sampler Close LPR-N & Manifold. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.14 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 Gauge Depth: 10537.51 ft TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) COMMENTS 31 -Mar- 92 Data Print Frequency: 1 *** Start of Period 4 *** 10:00:39 0.0139 4581.686 173.027 10:00:49 0.0167 4609.848 173.033 10:01:.09 0.0222 4674.438 173.044 10:01:19 0.0250 4705.715 173.050 10:01:29 0.0278 4736.064 173.055 10:01:39 0.0306 4765.352 173.061 10:01:49 0.0333 4793.612 173.067 10:01:59 0.0361 4820.777 173.073 10:02:00 10:02:09 0.0389 4847.148 173.078 10:02:19 0.0417 4872.465 173.084 10:02:39 0.0472 4920.939 173.098 10:02:59 0.0528 4965.961 173.113 10:03:19 0.0583 5008.370 173.127 10:03:39 0.0639 5047.387 173.141 10:03:59 0.0694 5083.761 173.155 10:04:19 0.0750 5118.110 173.170 10:04:39 0.0806 5150.234 173.184 10:04:59 0.0861 5180.369 173.199 10:05:19 0.0917 5208.701 173.213 10:05:39 0.0972 5235.083 173.228 10:06:19 0.1083 5283.611 173.257 10:06:59 0.1194 5326.683 173.286 10:07:29 0.1278 5356.332 173.308 10:07:59 0.1361 5115.905 173.267 10:08:09 0.1389 5014.361 173.208 10:08:59 0.1528 5043.505 173.250 10:09:29 0.1611 5073.645 173.275 10:10:19 0.1750 5109.439 173.316 10:10:39 0.1806 5146.723 173.329 10:10:59 0.1861 5181.523 173.342 10:11:19 0.1917 5213.023 173.355 10:11:39 0.1972 5251.076 173.368 10:11:49 0.2000 5201.897 173.376 10:12:39 0.2139 5232.721 173.410 10:14:09 0.2389 5271.125 173.475 10:14:29 0.2444 5297.730 173.487 10:14:59 0.2528 5334.079 173.505 10:16:09 0.2722 5363.909 173.547 10:17:09 0.2889 5394.301 173.583 10:18:09 0.3056 5422.224 173.619 10:20:39 0.3472 5462.222 173.695 10:21:09 0.3556 5493.326 173.710 10:22:29 0.3778 5523.998 173.741 10:22:49 0.3833 5487.155 173.749 Cycle OMNI To Reverse Position Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.15 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 31 -Mar- 92 10:23:59 0.4028 10:24:39 0.4139 10:25:19 0.4250 10:26:.19 0.4417 10:28:09 0.4722 10:28:49 0.4833 10:30:29 0.5111 10:32:00 10:36:09 0.6056 10:37:49 0.6333 10:39:49 0.6667 10:43:39 0.7306 10:47:49 0.8000 10:54:19 0.9083 10:59:00 11:09:09 1.1556 11:33:29 1.5611 11:53:39 1.8972 12:34: 09 2. 5722 13:36:09 3.6056 14:10:00 14:30:00 14:36:39 4.6139 14: 53: 00 15:38:19 5.6417 16:39:59 6.6694 17:00:00 17:30:00 17:40:29 7.6778 17:50:00 18:40:49 8.6833 19:41:39 9.6972 20:43:39 10.7306 21:30:00 21:45:39 11.7639 22:15:00 22:46:29 12.7778 23:00:00 23:15:00 23:25:00 23:36:00 23:36:29 13.6111 23:36:49 13. 6167 Data Print Frequency: 1 5522.923 173.773 5553.124 173.790 5584.400 173.808 5611.996 173.834 5638.719 173.869 5664.757 173.873 5690.170 173.882 Start Reversing Out. 5715.795 173.910 5741.958 173.919 5767.712 173.928 5793.559 173.948 5819.987 173.969 5845.571 173.967 Brine Returns, Oil, Mud. 5870.900 173.933 5896.393 173.836 5922.036 173.767 5947.054 173.636 5963.813 173.493 Finish Reversing Out. Rig Up BJ To Clear Flowlines. 5976.092 173.419 Rig Steam To Flow Lines. 6001.217 173.412 6020.295 173.421 Continue To Clear Lines & Tank Rig Up & Test BJ N2 Lines. 6033.218 173.439 Start N2 Downhole. 6036.187 173.465 6045.986 173.505 6053.063 173.568 Finish N2. Shoot FL. 9548'. 6059.447 173.632 Cycle OMNI To Blank Position. 6065.924 173.722 Shoot Fluid Level 9140'. Bleed N2 to 3800 Surf. psi. Close Manifold & Cycle OMNI. Open To Well Test Position. 6070.056 173.786 6079.587 173.786 *** End of Period 4 *** Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.16 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 31 -Mar- 92 23:36:59 0.0028 23:37:09 0.0056 23:37:19 0. 0083 23:43: 59 0. 1194 23:44:59 0. 1361 23:45: 59 0. 1528 23:46:39 0.1639 23:57:38 23: 57: 59 0.3528 23:58:39 0.3639 23:59:19 0.3750 1-APr-92 00:00:00 00:00:09 0.3889 00:00:49 0.4000 00: 01:49 0.4167 00:02:39 0.4306 00:03:39 0.4472 00:04:39 0.4639 00:05:29 0.4778 00: 06:29 0. 4944 00:07:29 0.5111 00:08:29 0.5278 00:09:19 0.5417 00:10:19 0.5583 00:11:19 0.5750 00:11:49 0.5833 00:12:09 0.5889 00:12:39 0.5972 00:13:09 0.6056 00: 13:49 0. 6167 00:14:29 0.6278 00: 15: 59 0. 6528 00:16:19 0.6583 00:17:19 0.6750 00:18:49 0.7000 00:19:29 0.7111 00:20:09 0.7222 00:20:59 0.7361 00:21:49 0.7500 00:22:49 0.7667 00:23:00 00:23:49 0.7833 00:25:09 0.8056 00:26:29 0.8278 Data 6043.029 5884.341 5818.018 5846.234 5877.525 5903.183 5824.789 Print Frequency: 1 Start of Period 5 *** 173.787 173.750 173.712 173.718 173.722 173.725 173.730 5782.482 5752.931 5725.091 173.754 173.754 173.754 Open Manifold w/3872 psi. 5691.351 5664.986 5627.183 5596.125 5559.659 5524.117 5495.446 5460.734 5428.046 5400.921 5375.822 5349.145 5384.606 5435.947 5464.232 5499.761 5530.269 5559.725 5588.226 5615.314 5579.812 5616.837 5642.760 5681.513 5710.624 5746.765 5778.319 5811.287 5838.792 5870.307 5896.013 173.745 173.737 173.724 173.713 173.700 173.687 173.681 173.680 173.680 173.679 173.678 173.678 173.690 173.708 173.721 173.740 173.760 173.773 173.786 173.816 173.822 173.840 173.877 173.893 173.909 173.929 173.950 173..974 173.999 174.032 174.065 Shoot FL 8794'. Shoot FL 8700'. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.17 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 1-Apr-92 Data Print 00:28:09 0.8556 5921.542 00:30:29 0.8944 5948.986 00:30:49 0.9000 5427.974 00:30:59 0.9028 5226.938 00:35:49 0.9833 5252.395 00:39:00 00:44:39 1.1306 5277.642 00:45:00 00:45:49 1.1500 5313.896 00:46:09 1.1556 5350.817 00:46:29 1.1611 5385.409 00:46:49 1.1667 5417.200 00:47:09 1.1722 5446.757 00:47:29 1.1778 5474.521 00:47:49 1.1833 5500.644 00:48:29 1.1944 5548.313 00:49:09 1.2056 5590.364 00:49:49 1.2167 5627.792 00:50:00 00:50:29 1.2278 5661.137 00:51:19 1.2417 5698.014 00:51:59 1.2528 5724.023 00:52:59 1.2694 5758.305 00:54:09 1.2889 5792.311 00:55:09 1.3056 5817.516 00:56:29 1.3278 5845.299 00:58:09 1.3556 5873.570 01:00:09 1.3889 5900.956 01:02:39 1.4306 5926.745 01:06:09 1.4889 5952.341 01:11:29 1.5778 5977.841 01:20:29 1.7278 6003.042 01:21:49 1.7500 5270.089 01:21:59 1.7528 5310.007 01:23:00 01:25:00 01:30:00 01:31:19 1.9083 5283.059 01:32:19 1.9250 5251.839 01:33:19 1.9417 5221.816 01:34:09 1.9556 5196.813 01:35:09 1.9722 5167.035 01:36:09 1.9889 5139.044 01:37:09 2.0056 5109.670 01:38:19 2.0250 5077.094 01:39:19 2.0417 5049.191 Frequency: 174.106 174.164 174.053 173.932 173.969 173.965 173.975 173.977 173.980 173.982 173.985 173.994 174.004 174.023 174.042 174.061 174.081 174.102 174.115 174.135 174.157 174.176 174.201 174.232 174.270 174.302 174.335 174.371 174.433 174.213 174.212 174.173 174.164 174.154 174.143 174.124 174.105 174.086 174.064 174.045 Shoot FL 8600'. Close LPR-N. Shoot FL. Open LPR-N w/3406 Surface psi. Shoot FL 8480'. Open Manifold. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.18 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 1-Apr-92 01:40:19 2.0583 01:41:19 2.0750 01:42:29 2.0944 01:43:29 2.1111 01:45:00 01:45:49 2.1500 01:46:49 2.1667 01:47:49 2.1833 01:49:09 2.2056 01:50:29 2.2278 01:51:39 2.2472 01:52:59 2.2694 01:56:19 2.3250 02:00:00 02:23:09 2.7722 02:30:00 02:31:49 2.9167 02:39:09 3.0389 03:00:00 03:04:19 3.4583 03:05:09 3.4722 03:05:59 3.4861 03:06:49 3.5000 03: 07:49 3.5167 03: 08:49 3. 5333 03:09:49 3.5500 03:10:49 3.5667 03:11:49 3.5833 03:12:49 3.6000 03:13:59 3.6194 03:14:59 3.6361 03:16:09 3.6556 03:17:09 3.6722 03:18:19 3.6917 03:19:29 3.7111 03:20:49 3.7333 03:21:59 3.7528 03:23:19 3.7750 03:26:09 3.8222 03:29:29 3.8778 03:30:00 03:31:49 3.9167 03:34:59 3.9694 03:36:39 3.9972 03:38:49 4.0333 03:40:29 4.0611 Data Print Frequency: 1 5022.277 174.027 4995.083 174.008 4964.045 173.986 4937.672 173.967 4904.692 173.936 4877.071 173.932 4851.243 173.927 4819.479 173.921 4787.331 173.916 4761.593 173.910 4731.382 173.905 4705.253 173.916 Shoot Fi. 7522 ft 4730.483 174.728 4756.408 174.983 4781.426 175.128 4754.031 175.399 4725.020 175.386 4698.297 175.362 4672.795 175.335 4642.277 175.296 4612.462 175.256 4583.741 175.215 4554.904 175.178 4526.785 175.150 4498.036 175.123 4468.097 175.090 4441.171 175.063 4413.330 175.030 4388.157 175.002 4359.086 174.970 4332.287 174.938 4300.776 174.900 4275.304 174.868 4247.194 174.866 4219.387 174.861 4245.320 174.854 4195.287 174.851 4166.758 174.844 4129.119 174.840 4102.911 174.833 4076.278 174.827 Shoot FL 8266'. Shoot FL 8072'. Shoot FL 7883'. Shoot FL 7632'. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.19 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 1-ADr-92 Data Print Frequency: 03:42:19 4.0917 4049.631 174.825 03:44:19 4.1250 3996.391 174.825 03:47:09 4.1722 4024.530 174.809 03:47:29 4.1778 3963.126 174.807 03:48:19 4.1917 3936.561 174.798 03:50:19 4.2250 3889.013 174.814 03:52:49 4.2667 3920.506 174.833 03:53:49 4.2833 3946.897 174.844 03:55:09 4.3056 3893.814 174.859 03:58:59 4.3694 3923.715 174.885 03:59:59 4.3861 3898.579 174.889 04:00:00 04:00:49 4.4000 3939.185 174.896 04:03:09 4.4389 3910.730 174.927 04:05:29 4.4778 3940.165 174.987 04:06:59 4.5028 3970.538 175.028 04:07:29 4.5111 3913.976 175.011 04:07:39 4.5139 3844.898 175.020 04:07:49 4.5167 3915.323 175.026 04:08:19 4.5250 3943.561 175.037 04:10:09 4.5556 3970.293 175.029 04:10:19 4.5583 3870.430 175.028 04:15:29 4.6444 3843.285 175.014 04:17:19 4.6750 3868.853 175.047 04:18:29 4.6944 3841.055 175.069 04:18:39 4.6972 3892.448 175.071 04:18:59 4.7028 3858.732 175.078 04:19:49 4.7167 3886.031 175.091 04:24:39 4.7972 3922.858 175.148 04:25:29 4.8111 3947.893 175.166 04:26:09 4.8222 3980.596 175.190 04:27:09 4.8389 4010.511 175.228 04:29:09 4.8722 3970.876 175.305 04:30:00 04:30:09 4.8889 4000.492 175.345 04:30:39 4.8972 4032.883 175.370 04:31:19 4.9083 4068.264 175.404 04:31:39 4.9139 4107.033 175.409 04:32:09 4.9222 4049.107 175.401 04:32:19 4.9250 4017.369 175.398 04:32:39 4.9306 3982.589 175.396 04:33:09 4.9389 3955.272 175.397 04:34:49 4.9667 3922.367 175.400 04:36:19 4.9917 3954.171 175.402 04:42:29 5.0944 3982.338 175.430 04:45:59 5.1528 4007.516 175.49.7 Shoot FL 7318'. Shoot FL 6941 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.20 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (min) (psi) (F) Gauge DeDth: COMMENTS 10537.51 ft 1-Apr-92 Data Print Frequency: 04:46:29 5.1611 4099.450 175.509 04:47:09 5.1722 4055.898 175.518 04:47:39 5.1806 4011.185 175.503 04:50:49 5.2333 4037.216 175.513 04:53:39 5.2806 4062.601 175.534 05:00:00 05:00:09 5.3889 4088.950 175.617 05:02:29 5.4278 4129.089 175.653 05:07:49 5.5167 4161.134 175.706 05:21:49 5.7500 4187.640 175.831 05:25:19 5.8083 4160.465 175.876 05:28:09 5.8556 4189.565 175.912 05:29:29 5.8778 4216.614 175.922 05:30:00 05:33:49 5.9500 4184.623 175.947 05:38:29 6.0278 4210.615 175.985 05:41:09 6.0722 4247.226 176.026 05:48:09 6.1889 4273.927 176.151 05:52:'09 6.2556 4301.357 176.226 05:54:09 6.2889 4327.126 176.277 05:58:49 6.3667 4276.712 176.339 05:59:29 6.3778 4240.869 176.348 06:00:00 06:06:49 6.5000 4268.227 176.396 06:09:59 6.5528 4294.670 176.454 06:14:19 6.6250 4320.942 176.563 06:17:59 6.6861 4346.470 176.662 06:23:19 6.7750 4373.174 176.779 06:28:09 6.8556 4399.330 176.866 06:30:00 06:32:09 6.9222 4424.788 176.937 06:36:29 6.9944 4451.188 177.012 06:39:59 7.0528 4482.044 177.059 06:47:39 7.1806 4508.560 177.135 06:53:29 7.2778 4535.532 177.220 07:00:00 07:02:09 7.4222 4560.994 177.232 07:16:49 7.6667 4531.202 177.187 07:20:00 07:23:29 7.7778 4520.049 177.179 07:23:39 7.7806 4520.464 177.178 *** End of Period 5 Shoot FL 6658'. Shoot FL 6344'. Shoot FL 6062'. Shoot FL 5847'. Shoot FL 5559'. Close Manifold. Swab Leaking. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.21 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 1-Apr-92 Data Print Frequency: 1 *** Start of Period 6 *** 07:28:29 0.0806 4545.572 177.172 07:32:59 0.1556 4572.024 177.214 07:38:59 0.2556 4597.938 177.302 07:43:59 0.3389 4623.956 177.370 07:48:49 0.4194 4652.598 177.375 07:54:19 0.5111 4677.951 177.360 08:00:49 0.6194 4705.231 177.343 08:05:49 0.7028 4731.174 177.329 08:12:19 0.8111 4757.004 177.312 08:17:59 0.9056 4783.447 177.300 08:23:59 1.0056 4808.841 177.287 08:29:59 1.1056 4833.937 177.278 08:35:49 1.2028 4859.396 177.261 08:41:19 1.2944 4884.477 177.236 08:48:39 1.4167 4909.859 177.224 08:54:29 1.5139 4935.318 177.242 09:00:00 09:02:09 1.6417 4960.690 177.243 09:08:49 1.7528 4986.608 177.261 09:19:29 1.9306 5012.040 177.242 09:20:00 09:26:29 2.0472 09:27:59 2.0722 09:28:09 2.0750 09:30:00 09:33:00 Install Tree Cap. Close Master & Blow Down Lines 5037.217 177.255 5042.758 177.253 5041.306 177.253 Close Manifold. Shoot FL 5873'. *** End of Period 6 *** Open Master. Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.22 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 1-Apr-92 Data Print Frequency: 1 *** Start of Period 7 *** 09:34:19 0.1028 5003.460 177.244 09:35:19 0.1194 4977.105 177.227 09:36:09 0.1333 4949.355 177.217 09:37:09 0.1500 4919.588 177.205 09:37:59 0.1639 4891.675 177.196 09:38:59 0.1806 4864.295 177.184 09:39:49 0.1944 4838.781 177.175 09:40:39 0.2083 4808.891 177.163 09:41:49 0.2278 4781.895 177.140 09:43:09 0.2500 4752.421 177.124 09:43:59 0.2639 4727.169 177.112 09:47:19 0.3194 4700.277 177.061 09:48:59 0.3472 4739.516 177.035 09:49:09 0.3500 4671.916 177.033 09:49:39 0.3583 4633.431 177.027 09:49:49 0.3611 4595.699 177.025 09:50:09 0.3667 4558.487 177.020 09:50:59 0.3806 4533.249 177.008 10:01:19 0.5528 4565.425 177.078 10:14:19 0.7694 4608.083 177.252 10:16:59 0.8139 4635.849 177.283 10:29:49 1.0278 4643.587 177.424 10:30:00 10:30:09 1.0333 4645.368 177.427 *** End of Peri Shoot FL 5653'. od 7 *** 10537.51 ft Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.23 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 1-Apr-92 Data Print Frequency: 1 *** Start of Period 8 *** 10:35:39 0.0917 4673.971 177.460 10:38:00 10:41:49 0.1944 4700.921 177.513 10:47:59 0.2972 4727.224 177.525 10:54:29 0.4056 4753.775 177.539 11:01:49 0.5278 4779.590 177.545 11:08:19 0.6361 4805.489 177.510 11:14:29 0.7389 4831.020 177.477 11:20:49 0.8444 4857.066 177.443 11:27:19 0.9528 4883.147 177.426 11:33:39 1.0583 4908.189 177.421 11:40:09 1.1667 4933.735 177.413 11:46:49 1.2778 4959.601 177.403 11:53:29 1.3889 4985.343 177.409 12:00:09 1.5000 5010.773 177.429 12: 07:19 1. 6194 5036. 687 177. 562 12:14:19 1.7361 5062.649 177.725 12:21:39 1.8583 5088.786 177.798. 12:28:49 1.9778 5113.955 177.773 12:36:19 2.1028 5139.424 177.743 12:43:59 2.2306 5165.427 177.713 12:51:39 2.3583 5191.064 177.690 12:59:39 2.4917 5216.679 177.667 13:07:59 2.6306 5242.532 177.651 13:16:19 2.7694 5268.025 177.636 13:24:49 2.9111 5293.503 177.618 13:33:29 3.0556 5318.736 177.611 13:42:19 3.2028 5343.790 177.597 13:51:00 13:51:59 3.3639 5369.228 177.583 14:00:39 3.5083 5395.527 177.575 14:09:09 3.6500 5421.028 177.562 14:17:19 3.7861 5446.575 177.555 14:22:09 3.8667 5472.460 177.555 14:28:59 3.9806 5497.987 177.555 14:35:39 4.0917 5523.180 177.544 14:44:29 4.2389 5554.459 177.541 14:45:00 14:46:00 14:47:00 14:59:09 4.4833 5580.712 177.538 15:37:19 5.1194 5606.397 177.468 15:55:29 5.4222 5631.982 177.489 16:11:49 5.6944 5657.641 177.453 16:28:49 5.9778 5683.103 177.417 Close master, rig up SWS RIH w/Schlumberger. Open Well To Manifold. To Monitor Perf. Shot. W/L Could Not Pass 10468. POOH Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.24 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 1-Apr-92 16:45:00 16:47:29 6.2889 17:00:00 17:03:.00 17:04:09 6.5667 17:05:29 6.5889 17:07:19 6.6194 17: 09:49 6. 6611 17:13:29 6.7222 17:20:19 6.8361 17:34:59 7.0806 18:06:59 7.6139 18:22:00 18:24:00 19:03:59 8.5639 20:00:00 20:05:19 9.5861 21:06:49 10.6111 21:25:00 21:59:00 22:07:19 11.6194 22:13:00 22:28:00 23:08:29 12.6389 23:58:00 2-Apr-92 00:09:39 13.6583 00:13:39 13.7250 00:13:49 13.7278 Data Print 5708.701 5733.903 5761.141 5790.075 5817.290 5842.990 5868.867 5893.876 5919.196 5944.520 5962.892 5976.180 5985.950 5995.662 Frequency: 1 Shoot FL 3235'. 177.373 177.348 177.347 177.349 177.349 177.347 177.342 177.298 177.179 176.967 176.816 176.685 176.604 176.533 Shoot FL 3141'. Close LPR-N. Shoot FL 3235'. Open Manifold & Bleed Press 0# Rig Up Otis Lubricator Shoot Fi. 2748 ft. Make Up GRC Gauges 77444,77445 Pressure Test Lubricator R.I.H. w/Wireline Shoot Fi 2921 Ft. 6004.685 176.481 6008.634 176.482 6011.560 176.482 *** End of Period 8 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.25 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 2 -Apr-92 Data Print Frequency: 1 *** Start of Period 9 *** 00:13:59 0.0028 3545.106 175.714 00:14:09 0.0056 3200.995 175.544 00:14:19 0.0083 3326.913 175.618 00:14:29 0.0111 3478.183 175.691 00:14:39 0.0139 3608.729 175.764 00:14:40 00:14:49 0.0167 3723.949 175.797 00:14:59 0.0194 3827.127 175.830 00:15:09 0.0222 3921.450 175.864 00:15:19 0.0250 4007.882 175.870 00:15:29 0.0278 4087.443 175.876 00:15:39 0.0306 4159.307 175.882 00:15:49 0.0333 4215.505 175.889 00:15:59 0.0361 4253.361 175.896 00:16:19 0.0417 3455.465 175.602 00:16:39 0.0472 3498.387 175.594 00:16:49 0.0500 3568.843 175.606 00:17:09 0.0556 3644.905 175.631 00:17:29 0.0611 3585.410 175.598 00:17:39 0.0639 3386.187 175.555 00:17:49 0.0667 3302.700 175.508 00:18:09 0.0722 3270.241 175.439 00:19:09 0.0889 3219.562 175.307 00:19:29 0.0944 3254.770 175.261 00:19:39 0.0972 3280.340 175.239 00:19:49 0.1000 3351.453 175.231 00:19:59 0.1028 3382.670 175.224 00:20:29 0.1111 3328.776 175.169 00:20:39 0.1139 3355.410 175.144 00:21: 19 0. 1250 3386. 122 175. 076 00: 21:39 0.1306 3278. 217 175. 044 00:21:59 0.1361 3218.145 175.010 00:22:09 0.1389 3247.229 174.991 00:22:19 0.1417 3173.051 174.975 00:22:49 0.1500 3215.612 174.949 00:23:29 0.1611 3253.712 174.935 00:23:39 0.1639 3220.795 174.928 00:23:59 0.1694 3253.306 174.913 00:24:29 0.1778 3284.952 174.897 00:25:39 0.1972 3326.562 174.869 00:25:49 0.2000 3281.068 174.867 00:26:39 0.2139 3311.633 174.873 00:27:19 0.2250 3348.530 174.870 00:27:39 0.2306 3247.656 174.867 00:27:45 Open LPR-N Open Manifold to Flow Lines Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.26 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 2-Apr-92 Data Print Frequency: 00:28:09 0.2389 3273.714 174.864 00:29:09 0.2556 3303.029 174.884 00:30:29 0.2778 3352.781 174.907 00:30:.39 0.2806 3294.133 174.911 00:30:49 0.2833 3331.990 174.924 00:30:59 0.2861 3371.836 174.937 00:31:09 0.2889 3400.816 174.950 00:31:39 0.2972 3370.009 174.992 00:31:49 0.3000 3339.815 175.007 00:32:09 0.3056 3388.197 175.033 00:32:39 0.3139 3415.578 175.074 00:32:59 0.3194 3356.733 175.103 00:33:09 0.3222 3388.747 175.116 00:33:19 0.3250 3419.483 175.130 00:33:29 0.3278 3463.215 175.143 00:33:39 0.3306 3515.327 175.155 00:33:49 0.3333 3570.399 175.177 00:33:59 0.3361 3611.706 175.199 00:34:09 0.3389 3656.023 175.220 00:34:19 0.3417 3696.901 175.242 00:34:29 0.3444 3723.519 175.264 00:34:39 0.3472 3752.023 175.286 00:34:49 0.3500 3793.681 175.308 00:34:59 0.3528 3614.685 175.250 00:35:09 0.3556 3311.077 175.195 00:35:19 0.3583 3231.607 175.136 00:36:29 0.3778 3260.845 175.190' 00:37:09 0.3889 3290.511 175.220 00:38:19 0.4083 3316.914 175.275 00:38:49 0.4167 3348.714 175.297 00:39:29 0.4278 3312.498 175.312 00:40:09 0.4389 3343.134 175.313 00:40:29 0.4444 3387.918 175.324 00:40:49 0.4500 3436.291 175.334 00:41:19 0.4583 3381.004 175.352 00:42:29 0.4778 3347.775 175.385 00:42:39 0.4806 3321.088 175.390 00:47:09 0.5556 3348.042 175.525 00:47:49 0.5667 3382.112 175.549 00:48:49 0.5833 3416.922 175.585 00:49:39 0.5972 3442.137 175.609 00:50:09 0.6056 3380.485 175.622 00:50:29 0.6111 3421.791 175.623 00:51:19 0.6250 3451.935 175.666 00:51:49 0.6333 3479.103 175.691 00:52:49 0.6500 3410.900 175.722 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.27 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) 2-Apr-92 Data Print Frequency: 00:54:09 0.6722 3449.068 175.784 00:54:49 0.6833 3485.779 175.818 00:55:59 0.7028 3512.186 175.872 00:56:09 0.7056 3474.835 175.881 00:56:29 0.7111 3505.329 175.896 00:57:09 0.7222 3439.550 175.929 00:58:19 0.7417 3479.969 175.988 00:58:39 0.7472 3429.286 176.002 00:59:19 0.7583 3492.817 176.027 00:59:29 0.7611 3457.856 176.035 00:59:39 0.7639 3409.599 176.042 01:01:59 0.8028 3441.775 176.133 01:02:09 0.8056 3468.481 176.141 01:03:29 0.8278 3506.818 176.190 01:03:49 0.8333 3539.206 176.203 01:05:09 0.8556 3566.627 176.261 01:05:59 0.8694 3594.714 176.296 01:07:39 0.8972 3634.870 176.371 01:09:59 0.9361 3556.052 176.491 01:10:19 0.9417 3593.833 176.505 01:10:49 0.9500 3618.883 176.541 01:10:59 0.9528 3558.856 176.545 01:11:29 0.9611 3584.068 176.557 01:12:59 0.9861 3611.462 176.632 01:15:39 1.0306 3639.650 176.738 01:16:19 1.0417 3672.930 176.765 01:18:19 1.0750 3699.257 176.842 01:19:09 1.0889 3725.605 176.874 01:20:09 1.1056 3681.423 176.913 01:22:09 1.1389 3709.064 176.990 01:22:59 1.1528 3735.007 177.021 01:24:29 1.1778 3760.202 177.069 01:24:59 1.1861 3722.742 177.085 01:25:29 1.1944 3689.602 177.100 01:26:19 1.2083 3715.353 177.124 01:26:39 1.2139 3667.686 177.135 01:27:19 1.2250 3693.243 177.154 01:28:59 1.2528 3720.929 177.202 01:31:29 1.2944 3690.523 177.277 01:32:09 1.3056 3719.175 177.296 01:34:29 1.3444 3749.952 177.364 01:35:39 1.3639 3723.745 177.398 01:35:49 1.3667 3752.358 177.402 01:36:19 1.3750 3787.541 177.416 01:37:19 1.3917 3818.600 177.444 01:37:39 1.3972 3852.340 177.452 Gauge Depth: COMMENTS 10537.51 ft Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.28 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 2-Apr-92 Data Print Frequency: 01:38:09 1.4056 3885.047 177.466 01:39:39 1.4306 3801.017 177.502 01:39:49 1.4333 3754.633 177.499 01:40:.09 1.4389 3787.005 177.500 01:40:49 1.4500 3818.331 177.525 01:43:19 1.4917 3853.707 177.624 01:44:09 1.5056 3880.006 177.657 01:45:09 1.5222 3909.761 177.697 01:47:19 1.5583 3946.152 177.784 01:48:19 1.5750 3973.701 177.823 01:49:39 1.5972 3944.040 177.878 01:53:39 1.6639 3973.372 177.988 01:58:39 1.7472 3998.673 178.107 02:03:49 1.8333 4024.130 178.235 02:04:00 02:06:00 02:08:09 1.9056 40.56.454 178.381 02:08:49 1.9167 4087.135 178.405 02:10:09 1.9389 4120.171. 178.391 02:11:19 1.9583 4019.182 178.353 02:11:29 1.9611 3906.268 178.326 02:11:39 1.9639 3874.545 178.297 02:13:39 1.9972 3847.462 178.273 02:16:59 2.0528 3873.739 178.198 02:20:09 2.1056 3899.916 178.137 02:21:39 2.1306 3933.429 178.122 02:22:39 2.1472 3959.654 178.130 02:23:59 2.1694 3908.248 178.143 02:25:19 2.1917 3935.763 178.155 02:26:39 2.2139 3962.428 178.166 02:27:49 2.2333 3904.403 178.178 02:30:00 02:33:29 2.3278 3931.112 178.244 02:38:09 2.4056 3956.299 178.330 02:39:49 2.4333 3987.596 178.361 02:40:09 2.4389 3959.083 178.368 02:43:09 2.4889 3985.827 178.423 02:50:00 02:50:09 2.6056 4011.685 178.527 02:55:49 2.7000 4036.784 178.614 03:01:09 2.7889 4063.172 178.712 03:06:29 2.8778 4089.075 178.820 03:12:19 2.9750 4114.831 178.939 03:17:09 3.0556 4140.639 179.037 03:22:59 3.1528 4165.714 179.089 03:25:00 Shut manifold, Shoot Fi 2010 ft Open manifold and well R.I.H. to check depth of fill P.O.O.H. w/ Wireline & Gauges Fluid to surface Date: 29-Mar-92 Ticket No: .. 007389 Page No: 3.1.29 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 2-Apr-92 03:25:59 3.2028 03:27:29 3.2278 03:29:59 3.2694 03: 30 :.00 03:35:39 3.3639 03:42:39 3.4806 03:45:39 3.5306 03:48:19 3.5750 03:51:39 3.6306 03: 54:49 3. 6833 03:55:00 03:57:49 3.7333 04:01:39 3.7972 04:02:59 3.8194 04:03:00 04:03:39 3.8306 04:04:19 3.8417 04:04:59 3.8528 04:05:39 3.8639 04:06:19 3.8750 04:06:49 3.8833 04:07:29 3.8944 04:08:09 3.9056 04:08:49 3.9167 04:09:29 3.9278 04:10:09 3.9389 04:10:49 3.9500 04:11:29 3.9611 04:12:09 3.9722 04:12:49 3.9833 04:13:29 3.9944 04:14:09 4.0056 04:15:09 4.0222 04:16:09 4.0389 04:17:09 4.0556 04:18:09 4.0722 04:19:19 4.0917 04:20:19 4.1083 04:21:29 4.1278 04:21:39 4.1306 04:21:49 4.1333 04:22:00 04:22:49 4.1500 04:23:29 4.1611 04:24:09 4.1722 04:24:49 4.1833 Data Print Frequency: 1 4191.980 179.109 4219.142 179.115 4194.112 179.126 4168.669 179.151 4194.629 179.179 4222.267 179.214 4248.937 179.220 4274.614 179.246 4301.070 179.277 4326.568 179.306 4353.150 179.344 4387.862 179.357 4428.617 179.362 4469.984 179.368 4514.062 179.374 4560.151 179.380 4606.755 179.385 4641.126 179.391 4685.933 179.400 4729.015 179.408 4769.735 179.417 4808.489 179.425 4845.148 179.434 4879.723 179.442 4912.210 179.451 4943.359 179.459 4972.876 179.467 5000.731 179.475 5027.037 179.483 5063.778 179.495 5097.525 179.506 5128.952 179.518 5158.148 179.530 5189.779 179.543 5215.002 179.554 5032.225 179.497 4712.149 179.432 4629.471 179.361 4674.736 179.396 4718.468 179.420 4759.162 179.443 4798.720 179.467 Close manifold to catch sample Otis to surface with gauges Shut in well to rig down Lub. Open well to separator Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.30 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 2-Apr-92 Data Print Frequency: 04:25:19 4.1917 4827.057 179.484 04:25:59 4.2028 4863.238 179.486 04:26:39 4.2139 4897.463 179.489 04:27:.19 4.2250 4929.221 179.491 04:27:59 4.2361 4959.968 179.493 04:28:39 4.2472 4989.092 179.495 04:29:19 4.2583 5016.789 179.498 04:29:59 4.2694 5043.134 179.500 04:30:49 4.2833 5073.991 179.503 04:30:59 4.2861 4961.972 179.471 04:31:09 4.2889 4880.950 179.438 04:31:19 4.2917 4727.849 179.406 04:31:29 4.2944 4598.556 179.375 04:31:39 4.2972 4468.819 179.343 04:31:49 4.3000 4404.080 179.310 04:31:59 4.3028 4361.036 179.276 04:32:09 4.3056 4335.324 179.276 04:32:29 4.3111 4294.104 179.276 04:32:49 4.3167 4264.641 179.276 04:33:29 4.3278 4237.579 179.265 04:39:49 4.4333 4210.797 179.065 04:41:09 4.4556 4185.502 179.023 04:42:39 4.4806 4160.264 179.015 04:44:39 4.5139 4131.254 179.029 04:46:59 4.5528 4104.210 179.041 04:49:39 4.5972 4075.910 178.984 04:52:39 4.6472 4049.388 178.938 04:58:29 4.7444 4023.745 178.883 05:04:49 4.8500 3997.615 178.845 05:09:59 4.9361 3971.567 178.834 05:15:49 5.0333 3946.542 178.820 05:22:19 5.1417 3920.328 178.833 05:28:09 5.2389 3895.047 178.842 05:33:49' 5.3333 3869.223 178.850 05:39:39 5.4306 3844.021 178.858 05:45:19 5.5250 3818.897 178.870 05:52:09 5.6389 3792.387 178.921 05:59:49 5.7667 3766.315 178.983 06:09:49 5.9333 3741.160 178.985 06:23:59 6.1694 3715.962 179.071 07:24:39 7.1806 3740.187 179.361 07:44:39 7.5139 3765.471 179.645 08:05:09 7.8556 3791.254 179.688 08:09:59 7.9361 3817.567 179.679 08:16:19 8.0417 3843.966 179.728 08:57:29 8.7278 3869.408 179.978 Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.31 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 2-Apr-92 Data Print Frequency: 09:57:39 9.7306 3850.691 180.178 10:14:49 10.0167 3825.616 180.203 10:27:39 10.2306 3800.350 180.191 10:40:09 10.4389 3774.478 180.174 10:50:39 10.6139 3748.644 180.171 11:06:09 10.8722 3722.759 180.184 12:06:09 11.8722 3698.365 180.158 13:06:19 12.8750 3688.228 180.491 14:07:19 13.8917 3663.064 180.634 15:08:09 14.9056 3661.310 180.812 16:08:59 15.9194 3664.290 180.971 17:09:09 16.9222 3671.782 181.134 18:10:39 17.9472 3687.932 181.246 19:11:09 18.9556 3690.046 181.311 20:11:39 19.9639 3693.847 181.403 21:12:09 20.9722 3708.637 181.497 22:12:49 21.9833 3715.866 181.598 23:13:19 22.9917 3720.138 181.680 23:16:00 23:29:09 23.2556 3721.181 181.722 23:29:19 23.2583 3720.061 181.726 *** End of Period 9 Trip sampler at 3200 psi Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.32 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 2-Apr-92 Data Print Frequency: 1 *** Start of Period 10 *** 23:29:29 0.0028 3790.065 181.728 23:29:39 0.0056 3844.668 181.731 23:29:49 0.0083 3892.656 181.733 23:29:59 0.0111 3937.837 181.736 23:30:09 0.0139 3980.746 181.738 23:30:19 0.0167 4021.250 181.741 23:30:29 0.0194 4060.103 181.744 23:30:30 23:30:39 0.0222 4096.303 181.747 23:30:49 0.0250 4130.845 181.750 23:30:59 0.0278 4164.084 181.753 23:31:09 0.0306 4195.802 181.755 23:31:19 0.0333 4226.100 181.758 23:31:29 0.0361 4255.019 181.761 23:31:39 0.0389 4282.614 181.764 23:31:49 0.0417 4309.131 181.767 23:31:59 0.0444 4334.694 181.770 23:32:19 0.0500 4382. 886 181. 777 23:32:39 0.0556 4427.321 181.783 23:33: 09 0. 0639 4487. 466 181. 792 23:33:29 0.0694 4523.917 181.799 23:33:49 0.0750 4557.511 181. 805 23: 34: 09 0. 0806 4588. 759 181. 812 23:34:29 0.0861 4617.972 181.818 23:34: 49 0. 0917 4645. 406 181. 825 23: 35: 09 0. 0972 4671. 111 181. 831 23:35:49 0.1083 4717. 963 181. 845 23:36:29 0.1194 4759.670 181.858 23:37:09 0.1306 4797.012 181.872 23:37:49 0.1417 4830.692 181.885 23:38:29 0.1528 4861. 132 181. 899 23:39:09 0.1639 4889.058 181.913 23:39:49 0.1750 4914.517 181.927 23:40:49 0.1917 4949. 000 181. 947 23:41:49 0.2083 4979.412 181.968 23:42:49 0.2250 5006.687 181.989 23:44: 09 0.2472 5038. 760 182. 017 23:45:29 0.2694 5067.105 182.045 23:47: 09 0.2972 5097. 877 182. 065 23:48:49 0.3250 5124.676 182.082 23:50:39 0.3556 5150.300 182.091 23:52:59 0.3944 5178.639 182.102 23:55:39 0.4389 5206.293 182.114 23: 58: 29 0.4861 5231. 590 182. 107 3 -Apr-92 00: 01:49 0. 5417 5257. 481 182. 095 Close in at LPR-N for build-up Date: 29-Mar-92 Ticket No: 007389 Page No: 3 .1.33 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 Gauge Depth: 10537.51 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) COMMENTS 3-Apr-92 00:05:49 0.6083 00:10:09 0.6806 00:15:09 0.7639 00:20:.49 0.8583 00:27:29 0.9694 00:35:39 1.1056 00:45:29 1.2694 00:56:59 1.4611 01:10:39 1.6889 01:18:00 01:20:00 01:26:09 1.9472 01:30:00 01:44:09 2.2472 02:05:39 2.6056 02:30:39 3.0222 02:59:59 3.5111 03:34:19 4.0833 04:15:29 4.7694 05:05:09 5.5972 06:02:59 6.5611 07:03:29 7.5694 08:04:59 8.5944 09:06:19 9.6167 10:06:59 10.6278 11:07:49 11.6417 12:08:39 12.6556 13:08:49 13.6583 14:08:49 14.6583 15:10:19 15.6833 16:10:29 16.6861 17:11:49 17.7083 18:12:09 18.7139 19:12:09 19.7139 20:12:59 20.7278 21:13:49 21.7417 22:14:49 22.7583 23:15:59 23.7778 23:58:00 23:58:59 24.4944 4-Apr-92 00:00:29 24.5194 00:01:09 00:01:19 00:01:39 Data Print Frequency: 5284.203 182.079 5309.415 182.063 5334.571 182.044 5359.767 182.015 5385.134 181.973 5411.027 181.905 5437.206 181.821 5462.925 181.722 5488.804 181.605 5514.304 181.468 5539.808 181.316 5565.496 181.138 5590.770 180.944 5616.060 180.742 5641.229 180.525 5666.426 180.306 5691.920 180.071 5716.977 179.835 5739.035 179.647 5758.361 179.492 5775.115 179.355 5789.899 179.229 5803.374 179.143 5815.517 179.068 5826.436 179.008 5836.597 178.951 5846.134 178.908 5854.761 178.863 5862.950 178.823 5870.505 178.802 5877.580 178.780 5884.295 178.761 5890.697 178.756 5896.723 178.734 5902.528 178.721 5906.423 178.733 Close upper master Blow down surface lines Continue Build -Up Open master valve to manifold 5906.568 178.733 *** End of Period 10 *** 5506.716 178.606 3896.242 178.128 3684.793 178.026 ft Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.34 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 Gauge Depth: 10537.51 ft TIME D TIME PRESSURE TEMP HH:MM:SS (min) (psi) (F) COMMENTS 4-Apr-92 00:02:00 00:04:09 3906.701 00:04:39 4135.319 00:05:49 4384.902 00:06:49 4630.170 00:08:19 4851.558 00:11:19 5065.366 00:12:29 4602.568 00: 12:39 3887.282 00:15:49 4139.665 00:16:39 3802.430 00:20:09 4053.488 00:20:49 4276.858 00:21:39 4502.953 00:22:39 4706.217 00:23:59 4914. 821 00:26:09 5143.986 00:28:49 5348.226 00:34:29 5550.641 00:53:59 5750.943 01:08:00 01:20:00 01:54:49 5853.319 02:10:00 02:11:00 02:56: 09 5878. 632 03:15:00 03:45:00 03:56:39 5896.136 04:00:00 04:57:29 5903.974 05:22:00 05:48:59 6517.289 05:50:19 6316.183 05:54:19 6112.344 05:55:00 06:00:00 06:04:39 6488.714 06:04:59 6745.452 06:05:00 06:05:29 7001.336 06:05:49 7211.659 06:06:19 7489.844 06:12:49 7043.291 06:13: 09 6607.465 06:13:29 6379.825 Data Print Frequency: 1 Cycle OMNI to circulating Dost 178.099 178.150 178.180 178.244 178.343 178.545 178.410 178.212 178.462 178.345 178.524 178.603 178.662 178.720 178.787 178.873 178.983 179.200 179.504 179.499 179.380 179.282 179.211 179.328 179.244 179.138 179.072 179.130 179.184 179.178 179.101 174.122 173.840 173.527 Reverse well fluid, 19.5 bbl Start full reverse Mud to surface Shut down to blow out lines Pump diesel to clear lines Continue to blow lines w/ air Rig down surface lines Cycle Omi to well test post. Rig up to bullhead into well Open LPR-N Bullhead into formation 3bbls Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.35 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (min) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 4-Apr-92 06:20:00 06:20:19 6649.115 172.866 06:23:19 6446.726 172.556 06:26:49 6245.344 172.481 06:46:49 6042.365 173.122 07:08:00 07:12:29 6348.366 174.313 07:16:19 6569.343 175.122 07:16:39 6956.966 175.301 07:16:59 7286.212 175.467 07:17:59 7488.513 175.721 07:20:00 07:45:00 07:46:09 7270.186 166.695 07:47:29 6992.068 165.988 07:48:29 6701.182 165.393 07:49:19 6499.520 164.947 07:52:59 6299.321 163.713 08:53:59 6255.514 165.512 09:00:00 09:20:00 09:45:00 09:46:19 6024.454 167.250 10:18:49 6267.548 168.060 10:30:00 10:35:19 6033.531 168.758 10:55:29 5827.137 168.937 11:10:09 5626.889 164.786 11:23:00 11:37:49 5413.866 157.786 11:54:29 5654.821 154.343 12:04:59 5453.210 153.674 12:11:29 5237.784 149.789 12:27:39 5031.322 140.547 12:39:29 4815.194 136.980 12:50:49 4595.115 133.874 13:05:39 4373.242 129.467 13:16:09 4171.045 125.121 13:25:49 3959.522 120.667 13:37:39 3756.705 115.455 13:46:19 3551.313 110.972 13:56:29 3348.629 105.804 14:06:49 3140.127 100.664 14:16:39 2917.276 96.553 14:29:29 2713.700 91.928 14:39:59 2511.140 87.674 Data Print Frequency: 1 Cycle omni to cir. position Open by-pass on packer Pump down annulus 70 bbl Shut down observe well 30 bbls returned to pits Rig down surface lines & tree Unseat packer Stand tree back Start to P.O.O.H. w drillpipe Date: 29-Mar-92 Ticket No: 007389 Page No: 3.1.36 PRESSURE VS TIME HALLIBURTON Gauge No.: 10102 Memory Recorder No.: 20113 TIME D TIME PRESSURE TEMP HH:MM: SS (rain) (psi) (F) Gauge Depth: COMMENTS 10537.51 ft 4-Apr-92 Data Print 14:50:39 2305.751 15:00:29 2104.443 15:12:49 1900.336 15:22:29 1694.206 15:33:49 1492.498 15:45:09 1287.782 15:54:59 1087.501 16:02:49 880.796 16:10:59 672.554 16:38:59 461.024 17:00:09 245.704 18:00:49 135.221 19:00:59 50.368 20:01:09 57.940 21:01:09 51.666 21:57:59 28.683 Frequency: 83.560 79.766 75.168 71.972 68.658 66.032 63.980 62.426 61.191 59.931 61.678 65.777 66.912 66.350 64.555 49.754 X 7.0 Test No; Gauge No; 6,0 5,0 1,0 0,0 One 106~2 ,ressD ur,s/Temperature History Well No; 2 Corrpany: T Conoco, fNC. C4 7~0 6~0 5~0 4.0 3.0 2.0 '1.0 0.0 Test Gauge No; One No: 10014 Pressure/Temperature Well No: 2 T I' T I T History T Company: Conoco, T [ T'-'-- '- tNC. c} C) £ L HRS 2C0 4 0 3> 0 Z 4 Test No: Gauge No: CZ.b, One 10629 Pressure,/Tem?er at ure Well No: 2 History LQ ELD Cornpany: Conoco, INC. T T J HRS Z 5 CD x 3 Pr~ssure/T~mperature History Test No: One Gauge No: 77~$&~ Well No; ~2 Company; Conoco, Inc. / / hOe o ~,-,e 0 o 0 4 Pressure/Temperature History Test No: One Gauge No: 77/+4,5 WeJl No: Company: Conoc:o~ tnc~ bO bO o ~CD CD Z Badan~ ~ DST#1 29-Mar-92 '~rrle OUme (hrs) Whp (P~) Gas Oilmtr Tank Csg Rat~ Rate Rat~ (~,~) (rnoVd~) (bbVda) (bbVda) 30-Mar-92 12:00:00 0.9300 0.00 0.00 0.00 12:30:00 0.5(X}O 0.00 0.00 0.00 13:00:00 1.0000 2228.00 0.00 0.00 13:15:0o 1.2500 4849.50 0.00 0.0o 13:30:00 1.50(X) 0.00 0.00 0.93 13:45.'00 1.7500 0.93 0.93 0.93 14:00:00 2.0000 4440.75 0.00 0.00 14:15:00 2.2500 4967.50 0.00 0.00 14:30:00 2.5000 1386.50 0.00 0.00 14:45:00 2.7500 4951.00 0.00 0.00 15:00:00 3.0(XX) 0.00 0.00 0.00 15:15:00 3.2500 0.00 0.00 0.00 15:30:00 3.5000 0.00 0.00 0.00 15:45:00 3.7667 0.00 47.06 0.00 16:00:00 4.0000 3.93 38.83 0.00 16:15.1X) 4.2500 4894.50 32.8~ 0.00 16:30:00 4.5000 1736.75 34.41 0.00 16:45:00 4.7500 1802.50 37.46 1404.00 17:00:00 5.0000 1672.50 38.64 1.10 17:15:00 5.2667 1658.75 41,35 0.56 17:30:00 5.SiXX) 1648.75 42.46 0.54 17:45:00 5.7500 312.43 60.87 70.50 18:00:00 6.0000 5016.75 55.21 64.66 GOR Page No. 4.1.1 Sk>w down lines and pressure test Rernmks Badami ~2 DST~ 29-Mar-92 Tim Dlime Whp Wht (hm) (psig) (degf) Gas Oilmtr Tank Csg Rate Rate Rate (r~) (moVda) (bbVda) (bbVda) 30-Mar-92 18:15:00 6.25(X:) 1089.00 52.71 1433.75 18.20:00 6.3333 18:25:00 6.4167 18.29:00 6.4833 18:30:00 6.5000 2.73 90.03 67.36 18:45:00 6.7500 0.03 80.78 1.26 19.00:03 7.0000 0.00 73.10 1.19 19:15:00 7.2500 0.00 67.02 0.39 19:30:00 7.5000 0.00 60.43 0.30 19:45.'(X) 7.7500 0.00 56.94 0.76 20:00:03 8.(XX)O 0.00 54.59 0,75 20:15:00 8.25(X) 0.00 52.65 0.00 21:03:00 9.00(X) 0.00 47.74 0.00 21:15:00 9.2500 0.03 46.39 35.79 21:30:00 9.5(X)0 49.72 80.65 1458.50 21:45:00 9.75(X) 13.92 52.31 1442.63 22:00:00 10.0000 15.52 81.27 1469.37 22:15:00 10.2417 17.38 79.10 1433.75 22:20:00 10.5003 23.52 77.32 1469.50 10.7503 11.00(X) 11~5(X) 11.50(X) 11.7500 450.09 120.02 750.15 400.08 240.05 GOR Remarks Page No. 4.1 ~. InilJal llow pedod was from 18:16:00 to 18~9:00 Flowed back 3.75 bbl Own well for 2nd flow at 21:18 10.03 75.52 1445.75 23.18 74.95 1479.25 8.15 74.02 1490.75 35.17 73.22 1471.00 18.00 72.13 1452.75 420.03 Badami #2 DST#1 29-Mar-92 01:00.~:)0 01:15:00 01:30:00 01:45:00 ., 02:00:00. 02:15:00 02:30:00 02:45:00 ,, 03:15:00 03:45:00 04:15:00 DUmo 12.0000 12.2342 12.5(XX) 12.7500 VVhp (~) 27.67 9.08 17.82 19.16 Wht 71.63 70.99 70.09 69.41 Gas Oilmtr Tank C,sg Rate Rate Rate (p~) (ncr/da) (b~Vc~) (U=Vda) 1496.13 1478.63 1462.88 1499.00 40.01 180.04 GOR Page No. 4.1.3 Rernatks 13.0000 13.2500 13.5000 13.7500 14.0000 14.2500 14.5(XX) 14.7500 15.0000 15.2500 15.5000 15.75(X) 16.0000 16.2500 16.5000 15.32 12.00 0.00 16.08 23.88 16.88 0.00 0.08 21.12 24.87 23.27 23.70 1483.50 1496.88 1482.50 1497.50 1486.25 1528.25 1513.88 1503.88 1495.38 1486.38 1477,50 1500.25 1492.76 1485.63 1510.38 40.01 120.02 140.08 200.04 120.02 40.01 60.01 80.02 16.7500 17.0000 17.2500 17.5000 17.7500 20.27 19.70 19.00 0.00 12.83 61.44 61.14 60.91 59.04 50.34 1503.88 1466.13 1492.63 1487.50 1482.63 120.02 380.07 T~me 07:15:00 07:45:00 08:15:00 08:30:00 09:00:00 09:15;00 10:00:00 10:15:00 10:30:00 10:45:00 11:08:00 11:15:00 11:30:00 11:45:00 DIJBO (hrs) 18.0000 18.2500 18.50(X) 18.78(X) 19.0000 19.2500 19.5000 19.7500 20.0000 20.2500 20.50(X) 20.7500 21.0000 21 2.500 21.5000 21.7500 Wellhead Condilions and Rates Whp (P~J) 13.00 14.35 12.20 4.40 6.95 7.40 4.33 12.77 3.13 4.08 6.28 0.00 0.00 4.92 19.10 0.00 0.00 1067.08 Wht 60.06 59.72 59.43 59.02 58.72 58.51 58.08 58.~3 57.81 57.71 57.66 56.90 56.51 572.6 56.32 Gas Oilmtr Tank (mo-~) (bbVda) (bbVda) 1478.38 1505.08 1500.50 1495.33 1491.50 146"7.75 1484.25 1480.88 1477.50 1519.50 1516.38 1512.37 1509.50 1505.12 1497.75 2128.38 1453.25 GOR Remad~ Page No. 4.1.4 Shut in LPR-N at 10:00 Cycly OMNI to (::irc Pos Reverse to Tank 4 56.97 69.35 73.88 72.68 71.80 268.13 302.38 302.50 327.75 215.75 Mud to surf @ 11:03 Badamie2 DST#1 29-Mar-92 31-Mar-92 12.130:00 12:15:00 12:30:00 12:45:00 13:00.~:X) 13:15:00 18:30:00 13:45:00 14:oo:oo 14:15:00 14:30:00 14:45:00 15.00:00 15:15:00 15:30:00 15:45:00 16:00:00 16:15:00 16:30:00 16:45:00 17.1)0:00 17:15:00 17:30:00 17:45:00 Wellhead Condb'or~ and Rates D~me (hrs) 24.0000 24.2500 24.5000 24.7500 Whp 1248.00 1795.75 100.75 94.52 Wht 77.92 8624 78.88 72.64 Gas Oilmtr Tank Csg Rate Rate Rate (l~;) (rno~/da) (bbVda) ( ,bbVda) 1810.63 1996.12 942,00 902.63 GOR (~,a) Rema~s Page No. 4.1.8 201.67 bbi mlumed 0 12:25 Punsed mud plumed tlowlines 88.33 86.72 290.00 184.05 2$.7e 0.93 0.00 0.00 207.73 565.00 67.24 63,30 59.90 56.41 54.19 52.65 51.45 50.56 76,00 76.19 82.67 102.90 93,57 902.75 885.25 872.63 90325 903.38 0.00 0.00 0.00 204.88 424.38 477.88 570.12 207.13 669.25 35.81 from 12:30 t~ 17:08 Sample ofoil in mud at 14:63 was 13.6 APl 0 68degf 28.7500 29.0000 29.2500 29.5000 29.7500 9O,27 85.52 87.42 0.00 404.53 237.58 181.37 128.71 111.03 95.87 87.92 63.90 56.88 0.00 0.00 Rig up N2 and press test Start pimping downhole w/N2 Baci~uni ~2 DST~ 29-Mar-02 -Mar-92 18:00:00 18:15:00 18:30:00 18~15:00 19.1:X):00 19:15:00 19:30:00 19:45:00 20:00:00 20:15:00 20:30:00 20:45:00 21:00:00 21:15:00 21:20:00 21:45:00 22:15:00 (hm) 31.5000 31.2500 31.5000 31.7500 32_.__n000 32.25OO 32.5000 32.7500 33.0000 ~$.~'~4)0 33.5000 33.7500 34.5014 34.7500 35.0000 35.2500 35.5(XX) 35.7500 Whp 1124.00 1832.75 2249.00 __2604_ .00 Wht 34.91 74.32 66.40 60.74 C~ Rate Rate Rate (m~) (mof/~a) (bbVda) (bbVda) 0.00 0.00 0.00 0.00 GOR Remad(~ Page No. 4.1.6 at 17:42 cisplacing to pits 2931.25 3092.50 3081.50 3385.50 ._'3~_ _'~_; .50 3806.50 3968.25 4123.00 4272.75 4414.75 4578.76 4617.00 56.60 53.21 50.70 49.07 47.34 46.O2 45.07 44.31 43.65 42.97 42.23 41.42 40.98 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00, 0.00 0.00 0.00 172.00 Returns to pits were 167.5 bbl at 21:29 Cycle OMNI to Blank Pos 38.95 39.18 39.02 71.38 62.13 1172.1 0.00 0.00 0.00 37.86 Ruid level 9140' Bleed tubing to 3799 psi at 23:28 1-Apr-62 01:00:00 01:15:00 01:30:00 01:45:00 02:0O:00 02:15:00 02:30:00 02:45:00 0~:00:00 03:15:00 03:30:00 04:15:00 Dtirne (hrs) 37.0000 37.2500 37.5000 37.7500 38.0000 38.2500 38.5000 38.7500 89.00O0 39.2500, 39.50O0 89.7500 40.7500 41.0000 41.2500 41.500O 41.7500 Whp 3775.75 3337.75 3358.50 3418.50 Wht Gas Oilmlr Tank (rn~da) (bbVd~) (bbVd~) 1475.13 1472.88 1498.13 1499.75 GOR Remad~s Page No. 4.1.7 Open well to flare on 6/64 at 23:57 and ~onlJnue to · bleed off N2 3407.0O 3406.50 3448.75 3102.25 2904.25 2895.00 2903.00 2912.50 2898.75 2,~1=s 2281.00 2020.75 1925.75 1846.00 1824.25 50.93 47.50 45.15 66.52 64.27 50.04 57.08 55,07 55.39 63.70 62.25 61.09 57.59 44.20 43.60 1500.13 1502.12 1499.50 1507.12 1487.63 1502.63 1486.25 1505.12 1489.0O 1487.25 1495.25 1498.38 1478.63 Shut in to take fluid levels at 1/2 hour int~rvab while bleed off N2 AUempt to maintain 2o0o whp 1809.75 1823.50 1823.25 1803.0O 1814.50 53.73 51.78 51.55 52.49 50.95 1483.88 1486.00 1490.25 1499.25 1491 Badami f~2 DST#1 2g-Mar-O~ 'nme 1-Apr-g2 09:00:00 09:15:00 09:30:00 09:45:00 10:00:00 10:15:00 10:30:00 10:45:00 11:00:00 11:15:00 11 :,.,10:00 11:45:00 (hm) Whp 1857.25 1902.00 1941.75 1950.00 Wht Gas Oilmlr Tank Csg Rate Rate Rate (p~k;~ (mol/da) ~bbVda) (bbVd~) 1503.75 1499.00 1498.50 1488.00 GOR Page No. 4.1.8 Rema~,s 2001.00 1965.25 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.23 2234.00 1856.50 1732.50 1753.00 1784.50 45.08 49.01 43.50 38.37 43.19 43.17 42.96 42.77 42.53 42.56 64.86 64.71 54.13 1483.00 1475.75 1468.88 1466.00 1492.88 1489.75 1486.88 1484.38 1481.53 1479.50 1517.37 1498.38 1487.75 1484.87 1483.38 Shut in, fluid level 5559' Close master valve and bleed Open well to 8/64 at 09:64 Shut in well and RU SWS 46.7500 47.0000 4725O0 47.5000 47.7500 0.00 0.00 0.00 0.00 0.00 43.73 45.31 45.10 44.82 44.54 1480.50 1518.00 1517.13 1516.13 1515.25 Badami ~2 DST#1 29.Mar.92 'nme l-Apr-92 12:00:00 12:15:00 12:30:00 12:45:00 (hfs) Whp 0.00 0.00 0.00 0.00 Wht Welb~ad Condilions and ~ 13:00:00 49.0000 0.00 45.12 13:15:00 49~:KX) 0.00 45.18 13:30:00 49.5000 0.00 45.61 13:45:00 49.7500 0.00 45.40 . 14:00:00 50.0(XX) 0.00 45.44 14:15:00 ,50~000 0.00 45.35 14:30:00 50.,5000 0.00 45.28 14:45:00 50.7500 2887.75 65.35 15:00:00 51.0000 235825 49.19 15:15:00 512500 2378.00 48.72 15:30:00 51.5(XX) 2386.25 47.70 15:45:00 51.7500 2398.75 46.45 16:00:00 52.0000 2404.50 45.68 16:15:00 52.2500 2423.50 45.76 16:80:00 52.5000 2486.75 46.16 16:45:00 17:00:00 17:15:00 17:30:00 17:45:00 Gas Oilmlr Tank Csg Rate Rata Rate (p~) , (n~ (U~vc~), (bbVd~) 1515.25 1511.63 1514.00 1518.38 GOR Page No. 4.1.9 Rerna~,s 1514.00 1529.63 1528.50 1528.00 1525.38 1528.50 1528.63 1529.63 1631.13 1681.38 1688.38 1~.38 lS47.13 1630.~ 2455.50 2468.75 2462.75 2461.75 2480~50 45.81 46.91 45.11 46.55 42.29 1587.87 1616.38 0.00 0.00 0.00 SWS out of hole at 17:37 Could not get down wilh guns Badami ~f2 DST#1 29Aqar-92 T~lle 1-Apr-02 18:00:00 18:15:00 18:30.00 18:45.130 19:00:00 19:15:00 19:30:00 19:45:00 20:00:00 20:15:00 20:30:00 21:00:08 21:tS.'00 21:30:00 21:45.00 22:15:00 23:15:00 (hrs) Whp Wht Gas Oilmtr Tank Csg Rate Rate Rate (p~) (mo~) (bbVda) (bbVda) 2459.50 2458.75 1108.50 7.90 0.08 0.00 0.00 0.00 58.2333 58.5000 58.73,33 59.00(X) 59.23,.'.'~ 59.5(XX) 59.723~ 4.13 0.00 0.00 0.08 0.08 0.08 0.00 0.00 0.08 0.00 0.08 0.08 0.08 0.08 0.08 0.00 0.08 0.00 0.08 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 GOR Page No. 4.1.10 Remarks Rig up OTIS v~h GRC gauges Run in hole wilh rnerno~v _=aums Badami ~V2 DST#1 29-Mar-62 2-Apr-62 00:15:00 01:03:00 01:15:00 01:30:00 01:45:00 02:00:00 02:15:00 02:30:00 03;15:00 04:00:00 04:15:00 Wel~"~ad Condilions and lb, tee D~me Whp 0.00 5.80 0.00 0.00 Wht 38.40 38.14 37.75 34.87 Gas Oilmtr Tank Csg Rate Rate Rate (p~j) (mof/cl~) ~Vd~) (bbVd~) 0.03 1471.63 1526.13 1523.26 GOR (soW~b) Remarks Page No. 4.1.11 Open LPR-N atO0:13 Open well on 48/64 choke at O0~r/ 61.0000 61.25(X) 61.5000 61.7500 62.0000 62.250O 62.5000 62.7500 63.00(X) 62.7500 0.00 0.00 0.00 0.00 0.00 0.03 0.00 0.03 0.03 0.03 47.53 103.73 187.95 195.85 876.50 1520.00 1526.38 1515.75 1526.50 1518.00 1511.13 1,582,00 1525.00 1526.50 1516.25 1513.25 1510.03 1543.63 1550.50 1546.13 103.63 38.63 81.47 74.80 96.53 1527.50 1522.13 1517.37 15,39.50 1534.25 2220.44 Tag bottom w/gauges 0 10372' Pull out of hole at 02:50 Ob to surface at 03:18 Oil to heater at 04:01 Rig down OTIS at 04:03 Open bypass line on manifold at 04'~2 Badan~#2 DST~I 29-Mar. e2 'nm DlJrne (hm) 2-Apr-92 06:15:00 08:45:,oo 07:15:00 08:15:00 09:15:00 10:00.00 10:15:00 10:30:00 69.0000 69.2500 69.5000 69.7500 70.0000 70.2500 70.5000 Whp (P~) 85.O5 63.12 57.87 44.85 41.70 40.02 ,38.20 57.92 42.03 56.25 51.20 55.25 74.45 82.87 90.47 97.25 105.65 Wht 44.34 44.38 44.22 44.10 44.17 44.13 44.14 44.05 43.84 44.56 43.63 43.53 43,42 43.62 Well,ad C.,ondilio~ and Rates Gas Oilmtr Tank Csg Rate Flal~ Ra~ (p~) (moVda) (bbVde) (b~da) 1529.50 1525.08 1520.63 1533.00 1530.38 1527.13 1524.50 1522.00 1519.25 1517.50 1515.50 1514.00 1513.38 1513.00 1512.62 1583.25 1,533.88 1534.13 1533.88 61.72 81.07 34.84 87,10 110,56 119.12 171.65 169.27 173.84 209.38 318.73 323,81 363.65 409.43 426.38 337.38 310.25 500.10 200.04 380.08 GOR (~,~) Remafl~s Page No. 4.1.12 BS&W ~/~ BS&W Flow int~ sepa~r Gas gravity .745 BS&W .4% Gas glavity .824, BS&W 1.5% 10:45:00 11:00.130 11:15:00 11:30:00 11:45:00 70.7500 71.0000 71.2500 71.5000 71.75(X) 98.45 78,73 78.25 75.90 75.15 43.43 43.33 43.49 43.76 4425 1533.88 1533.25 1,533.13 1532.50 1531.38 170.54 145.90 131.40 127.33 12721 295.84 311 .g5 334.63 344.16 346.70 430.08 576 468 392 370 367 Gas glavity .783, BS&W .3% Badami~2 D~#1 29.Mar-92 'nm 12:00:03 12:15:00 12:30:00 12:45:00 D~im (hfs) Whp Wht Gas Oilmlr Tank Csg Rale Rate Rate (mig) (rncVda) (bbVda) (bbVda) 72.0000 76.18 44.52 1529.63 123.54 361.11 72.2500 75.22 44.71 1529.25 120.30 377.22 72.5000 70.57 45.12 1527.00 117.45 388.24 72.7500 71.90 45.18 1525.88 114.22 337.05 330.07 GOR 342 319 303 311 Rerna~,s Page No. 4.1.13 13:00:00 13:15:00 13:30:00 13:45:00 14:00:00 14:15:00 14:30:00 14:45:00 15.'00:00 15:15:00 15:30:00 15:45:00 16.00:00 16:15:00 16:30:00 73.0000 75.70 45.31 1526.63 111.86 355.18 330.07 78.2500 68.25 45.24 1527.18 122.97 331.44 73.5000 64.00 45.28 1527.75 120.95 336.53 73.7500 54.58 45.30 1528.78 115.52 339.92 74.0000 68.93 45.20 1530.25 1,1,4.33 328.90 8t0.05 74.2500 68.05 45.15 1531.50 125.30 308,56 74.5000 67.37 45.08 1532. 75 124.75 295.84 74.7500 68.15 45.07 1533.50 124.50 296.69 75.0000 68.17 45.24 1533.75 129.72 293.30 380.08 75.2500 68.35 44.91 1534.50 107.48 308,56 75.5000 68.23 44.58 1573.35 105.30 296.69 75.7500 67.45 44.48 1572.25 103.80 297.54 76.0000 64.97 44.54 1572.25 104.27 305.16 300.03 76.2500 6400 44.51 1571.38 104.11 394.17 76.5000 68.88 44.54 1570.37 105.32 392.48 315 Oil gravity 18.8 O 50 degf 371 348 Gas oravitv .768 422 42O 17:15:00 77.2500 68.55 44.50 1568.75 99.70 283.97 17:50:00 77.5000 68.20 44.42 1568.25 96.86 256.85 17:45:00 77.7500 70.55 44.20 1567.50 98.60 257.69 340.97 262 326 351 377 383 Badami~2 DST#1 2g~ar~2 Time Wellhead Caxliflons and Ratse Gas OJlmlr Tank Dtime Whp Wht Csg Rate Rate Rate (h=) t~ (c~ (p~) (r~r~) (bbVda) (bbVda) Rerna~s 2-Apr-92 18:00:00 18:15.'t:)0 18:30:00 18:45:00 19:00:00 19:15:00 19:30:00 19:45.t30 20:15:00 21:00:00 21:15:00 21:30:00 21:45:00 22:15:00 78.0000 71.35 44.12 1567.13 102.87 78.2500 64.58 44,14 1567.38 105.03 78.5(X)0 65~2 44.10 1588.00 103.09 78.7500 69.00 44.05 1566.25 102.95 79.0000 64.12 43.97 1565.75 102.78 79.2500 73.45 43.86 1564.50 97.73 79.5000 74.08 43.57 1563.00 94.99 79.7500 72.35 43.43 1561.25 96.57 80.0000 70~13 43.04 1559.63 105.65 80.5000 75.68 42.98 1557.38 94.76 80.7500 76.95 42.99 1557.35 97.77 81.0000 75.62 43.07 1557.62 97.33 81.25(X) 76.45 43.06 1557.62 , 96.72 81.5000 73.50 42.86 1557.38 96.66 81.7500 76.10 42.63 1557.13 95.82 82.0000 76.75 42.30 1557.50 95A1 82.2500 76.20 42.15 1557.50 94.43 82.5000 77.35 42.07 1557.87 96.32 255.15 386,,-54 362.81 371.28 371.28 320.42 259.91 299.23 307.71 233.95 194.97 244.13 257.87 337.38 403 272 284 277 277 3O5 328 323 343 421 486 475 472 395 361 353 233 279 286 Page No. 4.2.14 Gas gravity .775 Qas aravJtv .743 ~W .4% 0~ gravity 18.8 ~ 50 degf Take oil samples at separator Rnish samoiina oil (60 c~ 011 20 APl, Gas .744 Take gas samples at separator Set off downhole aampler 22:45:00 82.7514 76.20 42.02 1558.13 23:00:00 83.(XXX) 74.77 4200 1558.50 23:15:00 83.2500 78.52 41.96 1558.63 23:30:00 83.5000 75.77 4210 2192.62 23:45:00 63.7,600 64.82 41.63 8.61 95.35 95.73 300.06 233 Shut in LPR-N Allow gas to oonlinue to flow to blow down separator and lines Badami~2 DST#1 29-Uar-92 "nm ~Apr-g~ 00:00:00 00:15:00 DlJme (hm) Whp INht 41.~0 41.44 40.44 40.70 Gas Oilmb' Tank Csg Rate Rate Rate (p~;) (m~/da) (bbVda) (bbVda) 9,76 10.39 10.81 10.98 GOR (scf/s~b) Remmks Page No. 4,1.15 01:00:00 01:15:00 01:30:00 01:45:00 18.65 2.98 53.75 49.22 41.66 41.73 45.43 48.00 10.80 10.53 10.71 10.81 Reveme out to Tank 6 and 8 Badami ~ Third Flow (Thru Separator) GOR Graph starts at 08:00:00 2-Apr-92 // Oil Rate 0 68 Whp I I I I I I 72 74 76 78 80 82 Delta Time (hrs) 84 Badami~2 DST#1 29-Mar-g2 'nme 30-Mar-g2 12:00.~X) 12:30:00 16:00.'00 18:00.1)0 18:13:00 18:15:00 18:16.00 18:20:00 18:25:00 18.29:00 18:20:00 18:45:00 19:00:00 19:t5:00 19:20:00 19:45:00 20:15:00 21:00:50 21:15:00 21:16:00 21:18:00 21.25.00 21:28:00 (his) TankStrape Tank2 Tank3 Inc (in) (in) (in) lng Cum (bid) 0.0000 0.5(X)O 4.0(XX) 6.0000 Opening Slrape: Tank1=3", Tank2=O", Tank3=O', Tank4=O" TankS=O', Tank6=O", Tanl(7=O", TankS=3' Tank8 is 5' afler tesling and blowing down lines 6.2167 6.25OO 6~667 6.33~ 6.4167 6.4833 6.4833 6.7500 7.0000 7.2500 7.5000 7.7500 8.0000 5.2500 9.0000 Open LPR-N Open to 10/64 adj choks 0.75 0.75 125 025 0.25 0.42 Shut in ~t choke Blow down line~ to Tank~ during initi~ buildup 5.50 3.50 5.83 1.25 1.67 3.75 9.2500 9.2667 9.3000 gA167 9.4667 Open LPR-N Open on 10/64 ad] dx)ks to Tank2 Open manifold choke full, heater choks at 12/64 Change to 12/64 choke Rate (bbVds) Page No. 4.2.1 450.09 120.02 750.15 Badami #2 DST#1 29~18r-92 30-Mar-92 21:30:00. 21:36,t:)0 22:00:00 22:15:08 28:45:00 31-Mar-92 00:00:00 00:15:00 00:30:00 00:45:00 01:00:00 01:15:00 01 ::30:00 01:45.~0 Ruid Data (hfs) Tank2 Tank Straps TanlG (in) Ino Ino (bbl) 9,5000 9,6000 10,0000 10,2417 Change flow to Tank8 Ruid to tank 5.25 10,5008 10,7500 11,0000 11.2500 11,5000 11,7500 12,0000 122842 12.5000 12.7500 18,0000 13,2500 13,5000 13,7500 8.50 9.7s 12,00 18,50 10.50 11,00 11,50 8,00 5.25 1.25 0.50 22.5 0.5O $.00 8,75 Z08 0,83 8.7s 0.88 Cum (bbl) 17.g2 1.50 2.50 14.0000 14.2500 14.5000 14.7500 15.0000 13.25 14.75 1,75 1.50 4.17 81.67 33.75 89,17 41.67 44,59 48,75 51.25 Rate (bbVc~) Page No. 42.2 400.08 240.05 420.08 100.02 40.01 150.04 40o01 120.02 140,08 200,04 120.02 Badami~2 DST#1 29-Mar-92 07:15:00 Ruid Data OlJme (hr'a) Tank2 (in) TankStrapa Tank8 (in) ' Ino (~n) lng 15.2500 15.5000 15.7500 16.0000 16.2500 16.5000 16.7550 17.0000 17.2500 17.5000 17.7500 18.2500 18.5000 18.75(X) 19.0000 19.2500 19.50(X) 19.7500 16.50 17.50 22.00 23.50 25.25 15.50 17.00 21.25 24.00 0.75 1.03 1.50 4.50 4.25 1.50 2.75 1.75 1.25 1.67 2.50 7.50 7.03 2.5O 4.58 52.09 74.59 79.18 20.0000 20.2500 20.5000 20.7500 21.0000 27.00 25.00 27.00 1.03 1.75 3.33 82.09 83.76 86.68 (bbVda) Page No. 4.2.3 60.01 80.02 120.02 860.07 340.07 12o.o~ 140.03 50.02 140.03 150.03 Badami~2 DST#1 29~ar~2 (hm) Tanketmpe Tank2 Tank3 In~ (in) (in) (in) 31-Mar.92 09:15:00 09:30:00 09:45:00 09:47:00 10.130:00 10:00:00 10:15:00 10:38:00 10:45.00 11:03:00 11:15:00 11:30:00 11:45:00 12:03:00 12:15:00 12~5:00 12:45:00 17:00.1X) 17:08:00 17:30:00 17:42:00 18.00:03 21:03:00 21:15:00 21.2500 21.5000 21.7500 21.7838 Fluid Data Ino (bU) (bbVc~) Page No. 4.2.4 28.00 1.00 1.67 91.68 80.02 Pressure up annulus to aclivato bottomhole sampler 2.75 29.75 Shut in LPR-N, Well is open to Tank2 Reverse out to Tank4 on 10/64 choke 29.00 Mud to SuPine Puree lines olu.e:ed with mud Tank4 simp is 121" on reverse out Conlinue ~aning out ilowlines Rnish purqinq lines Star displacing downhole with nitrogen Opening tank simps alter deaning out lines Tank2=29", Tank3=30", Tank4=125.5" 96.26 220.04 1.387 97T93 Badarni ~ DST#1 29-Mar-92 'nm 81-Mar-92 21 ~9:00 21:30:00 21:45:00 TankStrapa Dlirne Tank2 Tank3 Inc (bra) (in) (in) (in) 33.4833 Shutdown N2,167.5 bbl returned to pits, Whp = 4587 pal 33.5(XX) Ruid Level is 9548 33.7500 Inc Cum Rate (~vc~) Page No. 4.2.5 Badami ~2 DST#1 29-Mar-92 Tlmo OtJrne Fluid Level Meaeu~ta Level Influx Influx (ft) (ft) (bU) 31-Mar-92 22:13:00 22:15:00 23:00:00 23:16:00 Cycle OMNI to Blank Posi~on Bleed tubing pressure to 3800 psi Shut in at 3799 psi Cycle OMNI to Well Test Poailion Open LPR-N Fluid Data Cum 7.2S Rate 115.94 Page No. 4.2.6 00:45:00 36.7500 Cyde OMNI 00:50:00 36.8333 8480.00 123.00 01:21:00 37.3500 Open LPR-N 02:00:00 38.0000 8230.00 220.00 02:15:00 38.2500 02:30:00 38.5000 8072.00 188.00 6.14 1.67 1.67 2.24 3.91 3.34 13,39 15.06 16.72 18.96 22.87 26.21 147.48 104.52 1 50.25 292.94 562.64 160.27 38.7500 39.00(X) 39,2500 39.50(X) 39.7500 7883.00 189.00 3.36 29.57 161.12 7632.00 251.00 4.48 34.02 213.97 Badarni ~ DST #1 29.Mar~ 'nm l-Apr-92 09:34:00 09:58:00 10:00:00 10:15:00 10:30:00 Ruid Data (R) (It) (bbi) (bbl) (bbVda) 40.0000 40.5000 40.7500 7318.00 314.00 5.58 6942.00 376.00 6.68 41.0000 41.2500 41.5000 41.7500 42.__n000 42.25O0 42.50O0 42.7500 43.0000 40.3833 43.7500 6344.00 314.00 5.58 6062.00 _'~__.LX) 5.01 584200 220.00 3.91 5559.00 283.00 5.08 51.32 68.90 61,90 65.81 242.10 267.68 240.40 167.55 Close Master Valve, Bleed downstream pressure, Close choke Repair leaking swab valve on tree and blow fluid out of lines Reopen Master Valve 5873.00 -314.00 -52A9 0.~ 0.~ 65~ 0.~ 220.00 3.91 69.17 187.55 Page No. 4.2.7 Badami g2 DST #1 2g-Mar-g2 O'dm Ruid Level Measurements Level Influx Influx 1-Apr-S2 Cum (bU) Rate (bbVda) 10:30:00 10:39:00 11:15:00 16:45:00 46.5000 47.6500 47.2500 52.7500 Shut in, Rig up SWS to make perfom~g mn Bleed pressure on downstream lites 3285.00 2418.00 42.94 112.11 164.90 17:00:00 17:02:00 17:15:00 17:30:00 17:45:00 18:00:00 18:22:00 18:23:00 18:25:00 18."26:00 18:30:00 18:40:00 21:25:00 58.7333 59.0000 59.2833 59.,.-.-.-.-.-.-.-.-.-~ 59.7333 3141.00 94.00 1.67 Bleed off annulus pressure Rig down SWS Pe~ratina aun set down in vicinitv of bundle carrier 3235.00 -g4.00 -1.67 Bleed off N2 pressure to 10/64 chol~ Open to 20/64 Open to 32/64 Open to 48/64 Incitation of gas at data header Rig up Olis to mn GRC memory gauges Run in hole wilh ,qauges 118.78 112.11 120.76 160.27 68.06 Badami ~2 DST#1 2g-Mar-g2 Fluid Level Measu~enb Dlime Level Inltux Influx (hr~) (It) (It) (bid) 2-Apr-92 00:13.00 (32:15:00 02:50:00 60.0000 2921.00 -173.00 -3.07 60.2167 Open LPR-N 60.45(X) Open to 48/64 d~oke, small flare 62.0000 2010.00 911.00 16.18 62.2500 62.~ Through LPR-N w/gauges, tag @10372, pulloutof hole Note: Rate of influx is based on O. 1776 bbl/it capacity forS' 19.5ff DP, ID = 4.276" Fluid Data (bid) 117.69 (bb~da) 194.15 Page No. 4.2.9 Badami ~2 DST#1 29-Mar-92 'nme Tu~ne Meter Dlirne Oil Meter Meter Con* Tanks Temp Cum Rate Rate (hfs) (cie~ (biff) (bi.cia) (bbVda) (in) 2-Apr-92 03:00:00 03:18:00 03:25:00 08:15:00 08:30:00 Ruid Data Ruid to surface Shut in at manifold Open on 48/64 chol~ to heal~r~ bypassed to Tank1 TankStraps Tank7 (in) Oil (in) Oil (biff) (biff) Page No. 4.2.10 Openingsl]aps: Tenk6=O', TanlO'=O' Otb at surface wilh gauges Oil to heater Shut in Master valve to rig down Otb Rock choke Switch llow to Tank'7, Tank1 riser possibly frozen off 27.75 27.75 46.26 94.40 0.00 123.30 2.47 237.12 139.40 6.23 360.g6 209.08 318.73 12.50 36.00 41.00 12.50 8.25 5.50 5.00 20.84 13.75 9.17 67,10 80.85 90.02 98,35 Oil 2~20.44 ,~X).IO ~I0.07 220.04 200.04 Badami DST#1 29-Mar.92 2-Apr-e2 09:15:00 09:45:00 10:00:00 10:15:00 10:30:00 10:45.'00 11:00:00 11:15."o0 11:30:00 11:45:00 12:00.1:X) 12:15:00 12:30:00 12:45:00 13:00.'00 13:15.'00 13:30:00 13:45:00 14:00:00 14:15:00 14:30:00 14:45:00 DlJrne (hm) 70.2500 70.5000 70.7500 71.0(XX) 71.2800 71.5(XX) 71.7500 72.0000 72.2500 72.5OO0 Fluid Data Oil Temp Tu~ne Meter Meter Cum Meter (bbVda) Rate f~Vd~) Tank6 TankStrap~ (in) Oil Ino (~n) Oil (bbl) 150.70 150.40 172.40 175.70 10.05 14.84 19.17 24.20 323.81 363.65 409.43 426.38 9.50 174.90 173.40 171.00 165.30 162.00 16200 162.10 162.80 162.50 164.30 28.18 31.84 35.38 39.01 42.96 47.02 51.11 35.37 59.82 64.40 387.38 310.25 295.64 311.35 384.83 344.16 346.70 361.11 377.22 388.24 35.75 51.75 10.75 8.25 164.50 166.50 167.10 166.10 168,50 163.30 163.40 157.10 153.g0 84.81 88.69 95.82 415.68 402.24 375.36 381.12 849.44 357.05 355.18 331.44 336.68 ~9,~ 328.90 308.66 43.50 50.00 8.28 7.75 15.64 17.92 13,75 13.75 12.92 Oil (bbl) Page No. 4.2.11 114.19 132.11 145.68 159.62 172.64 Oil (bbVda) 380.05 330.07 310.05 Badami ~2 DST#1 29-Mar-92 2-,a~or.92 15:00:00 15:15:00 15:30:00 15:45:00 16:00."00 16:15:00 16:30:00 16:4,5:00 17:00:00 17:15:00 17:30:00 17:45:00 18:00:00 18:15:00 18:30:00 18:45:00 19,1:X),'1)0 19:15:00 l~;ao;~o 19:45:00 20:15:00 75,O(XX) 7525OO 75,5000 75,7~_~03 78.5000 78,7500 79,0000 79,2500 79,7500 Fluki Data Oil Temp Tu~ne Meter Meter Cum , (bbl) Meter Rate (bbVd~) TankB (in) TankS'traps Tank7 (in) Oil Ino (in) (bbl) 152.60 153.10 152.90 153.90 102,78 106.42 109,92 113.43 332,16 349,44 336.00 336.96 69,50 15.84 154,20 152.60 151,50 151,50 150,30 152.90 149,50 151,10 150,40 153,70 117,03 121.68 126,31 131,06 134.81 138.16 141,19 14423 147,24 151.50 305.16 394,17 392,45 402.65 317,68 283,97 256.65 257,69 255,15 386,54 51,00 57,75 78,00 7,50 8.50 6,75 14.17 11,25 152,90 154,00 154.10 152,90 148.60 146,40 146.00 146,50 143.10 156,08 160.46 164,84 168,62 17~.o~ 175,57 179,20 181,96 164.26 410.33 420.43 420.43 382.68 ;~89,91 807.71 194.97 65.26 8,6.50 7.50 7.50 Oil Cum (bU) Page No, 4,1,12 168,37 200,87 215.04 226.30 238.80 251.30 Oil (bbVc~) MO.08 8(X).06 840.97 270.05 300.06 300.06 Badami e2 DST#1 29-Mar-92 Tu~ine Meter Dlime Oil Meter Meter Con* Tank6 Ternp Cum Rate Rate (bra) (clegt) (bbl) (bbl/da) (bbl/da) (in) 2-Apr-92 20:45.'(X) 80.7500 141.10 186.69 233.28 205.99 21:00:00 81.0000 142.70 189.12 233.28 205.99 21:15.00 81.2600 144.00 192.00 276.48 244.13 21:30:00 81.5(XX) 143.10 195.16 303.36 267.87 21:45.'~ 81.7500 141.30 198.26 307.20 271 26 22:00:00 820000 139.60 202.34 38208 337.38 22:15:00 82.2500 137.70 206.33 383.04 33822 22:30:00 82.5000 136.10 210.30 38 1.12 336.53 22:45:08 82.7514 135.30 214.27 381.12 336.53 23:00:00 83.0000 135.20 218.14 871.52 328.08 3-Apr-92 Ru~l Data TankStrape TanlE (in) 91.75 Oil Oil Oil Oil Ino Ino Cum Rate (in) (bbl) (bbl) (bbVda) Page No. 4.2.13 6.25 10.42 261.72 250.08 7200 99.25 6.75 11.25 272.97 270.08 7.50 12.50 265A7 300.08 5.00 8.34 293.81 807.75 01:19:00 01:30:00 85.8167 Blowdown lines & separator to Tank7 85.5000 Data Acquisilion 8hut Down, Thaw out ~;ers on Tanks 1~3,& 8 86.(XX)O Monitor wdl on buildup 167.4338 Opening strap on Tank6=74.5' for revere out 108.3333 110.1333 111.1500 111.1667 Open ~ manifold, Reverse out to Tank6 Mud to surface. Switch to Tanl~ Rnish Reverse out, Good mud to Sur~c~ Reversed out 60 bid to Tank8 112 12.75 21 ~.5 315.08 141.5 67 111.689 390.07 Badami ~ DST#1 29-Mar-92 'lime DlJme ., , (hm) Turbine Meter Oil Meter Meter Corr* Tank6 Temp Cum Rate Rate (c~) ~b~) (bbVda) (bbV~_,~ (in) 4-Apr-92 Note: The con'eca~ meter rate is computed by applying a wealhering factor ~ 0.8830 to the oil meter rote. The wealhedng fair wa~ computed from the ciffemn~e in cumula~ve produclbn between lhe tank snaps and eli meter during the 14 hr pe~:.:l from 0900 to 2'.300 on 2-Apr-92. TankS'traps Tanl(7 (in) Oil Inc gn) Oil (bbl) Oil Cum (~.~..') Page No. 4.2.14 (bbVda) Badami ~2 DST#1 29-Mar. e2 Time 2-Apr-62 08:15:00 06:45:00 09:00:00 09:15.00 09:30.00 09:45:00 10:00:00 10:15:00 10:30:00 10:45:00 11:00:00 11:15:00 11:30:00 11:45,"00 12:00:00 12:15:00 12:30.'130 12:45:00 13:00:00 13:15:00 13:30:00 13:45:00 14.'00:00 Whp Stalio Diff (~n) Temp Odfioe (in) eravity {.~r=l) 68.2500 68.5000 68.75O0 69.0000 56.25 5120 5525 60.80 1.50 17.56 19.47 20.87 162.39 6.88 28.31 23.68 67.77 93.10 107.62 118.85 0.500 1.000 0.750 0.750 0.748 0.748 0.748 0.748 69.25OO 69.5000 69.7500 70.O(XX) 7o.,-~3o 70.5(X)0 70.7500 71.0000 71.2500 71,5(X)0 71.75(X) 72.OOO0 72.7500 59.32 74.45 62,87 90.47 97.25 105.65 98.48 78.78 78.25 75.90 75.15 76.18 75.22 70.57 71.90 23.13 25.16 29.87 34.77 37.48 43.48 30.96 25,20 22.33 21.35 20.24 19.29 18.25 17.68 16.40 24.99 ,36.11 38.10 68.53 72.89 65.32 76.29 64.88 57.95 51.42 48.17 128.95 139.98 149.58 157.49 1el.45 163.45 163,66 162.75 159.57 158.19 152,20 148.30 144.96 142.00 139.54 0.750 0.750 0.750 0.750 0.7,50 0.750 0.750 0.750 0.750 0.750 0.750 0,750 0.750 0.750 0,750 0.748 0.748 0.748 0.824 0.824 0.824 0.624 0.824 0.624 0.783 0.783 0.783 0.783 0.793 0.783 73OO00 73.25O0 78.5(X)0 73.7500 7400O0 75.70 6525 64.00 64.58 66.93 16.27 18.02 17.16 16.65 16.03 49.60 58.65 5125 50.78 48.43 137.40 187.49 137.35 136.20 135.42 0,750 0,750 0.750 0.750 0,750 0.783 0.783 0.783 0.783 0.783 Rate (m,~da) 61.72 81.07 64.64 87.10 90.98 110.96 119.12 171.65 169.27 173.84 170.54 145.90 181.40 127.33 12721 123.54 120.30 117.45 114.22 111.86 122.97 120.95 115.52 114.33 Vol Page No. 4.3.1 0.67 1.51 2.24 8.14 4.08 5.17 6.39 8.02 9.62 11.62 18.43 15.00 16.41 17.75 19.08 21.64 22.87 24.08 25.25 26.52 27.77 28.98 30.18 Badami ~2 DS'r #1 29-Mar-~ l'lm~ 2-Apr-92 14:15:00 14:30:00 14:45:00 15:00:00 15:15:00 15:30:00 15:45:00 16:00:00 16:15;00 16:30:o0 16:45:00 17:00:00 17:15:00 17:30:00 17:45:00 18:(X):00 18:15:00 18:30:00 18:45:00 19:00:00 19:15:00 19:30:00 19:45:00 20.'00:~ DlJm 7425OO 74.5(XX) 74.75~ 76.0000 75.250O 75.5(X)0 75.7500 76.0000 76.250q 76.5000 76.7500 78.0000 782500 78.50(X) 78.7500 79.0000 792500 79.5000 79.7500 80.0300 Gas Data Whp Stalb Dilf (in) Gas Ternp (deft Orifice (in) erav~y (A~r=-l) 68.05 67,37 65.15 68.17 16.74 21.16 21.06 19.88 61.10 51.10 50.61 52.55 134.96 135.38 135.39 134.97 0.750 0.75O 0.750 0.750 19.86 19~8 18.93 1929 19.10 19.36 19.56 19.12 1721 17.62 17.95 19.77 19.84 89.23 39.02 37.77 36.99 36.56 38.39 37.89 38.03 33.31 34.81 33.73 35.98 37.00 134.65 134.48 134.38 134.19 132.57 131.56 130.62 130.32 128.84 129.60 130.54 131.34 0.750 0.750 0.750 0.750 o.7~ 0.750 0.750 0.750 0.750 0.750 0.750 0,750 0.750 0.750 0.750 64.12 73.45 74.08 72.35 70.18 19.59 1729 17.59 18.10 19.68 130.73 129.45 128.51 127.93 127.94 0.750 0.750 0.750 0.750 0.750 0.783 0.783 0.783 0.783 0.783 0.78,3 0.783 0.756 0.768 0.756 0.768 0.756 0.768 0.768 0.756 0.768 0.768 0,768 0.756 0.775 0.775 0.775 0.775 0.748 123.30 124.75 124.60 129.72 107.48 103,30 103.80 194.27 104.11 103.32 105.65 103.58 99.70 95.86 95.60 105.93 103.03 102.78 97.73 94.99 95.57 105.65 Vol Page No. 4.32 31A1 32.65 33.96 35.31 38.43 87.54 38.62 39.72 40.82 41.91 43.00 44.08 45.12 45.13 47.15 49.32 50.39 51.43 Time ~-~r.~ ~0:15:00 21:00:00 DIJBO Whp 7O22 75.68 76.95 75.62 Statb Diff (in) 17,43 17.11 17,52 17,86 32,56 31,60 32.98 33.37 Temp 128,19 127,27 128.28 128.50 Olifice (~n) emvity 0,750 0,750 0,750 0,750 0.743 0.748 0.743 0.744 (mind/da) 98.43 94.76 97.77 97.33 Cum (msd) Page No, 4,3,3 67,67 58.68 59,68 60,69 21:15:00 21:30:00 21:45,'(X) 22:00:00 22:15:00 22:3O:00 22:45:00 23:00,'(X) 81,2563 81,50(X) 81,7500 82.O0OO 82,250O 82,6O0O 82.7514 83,6300 76,45 73,50 76,10 76,75 76.20 77,85 76.2O 74,77. 18,02 17,88 18.31 18,04 18,02 18,18 18,39 16.63 32.71 31,77 32.85 30,75 31.38 30,54 31,55 3O28 128.46 125.94 128,22 124,36 123.45 123.24 123,11 123,02 0.750 0.750 0.750 0.750 0.750 0.750 0.750 0.750 0.744 0.744 0.744 0.744 0.744 0.744 0.744 0.744 96,72 96,68 95,62 95A1 94,43 95,82 95,35 95,73 61,70 62,71 63,71 64,70 65,68 66,69 67,69 68,68 ORIGINALi ;IICROFILMED CONOCO INC. 'BADAMI sLot #1 BADAM! NORTH SLOPE, ALASKA SURVEY LISTING Your ref : Our ref : svy114 Other ref : Date printed : 24-Mar-92 Date created : 12-Feb-92 Last revised : 24-Mar-92 FieLd is centred on 0.000,0.000,.0.00000,+ Structure is centred on 0.000,0.000,0.00000,+ CONFIDEN11AL Heasured Depth 0.00 415.00 429.12 459.77 490.57 521.38 552.11 582.99 613.77 644.60 675.35 706.25 737.07 767.90 798.80 829.65 860.38 891.23 922.12 983.74 1014.58 1045.40 1076.23 1107.08 1137.86 1168.71 1199.51 1231.24 1263.07 1294.94 1326.79 1358.79 1390.59 1422.59 1454.52 1686.49 1518.24 1549.92 1581.62 1613.57 1645.47 1677.37 1709.27 1741.18 1772.86 1804.69 1836.54 1868.19 1899.94 1931 1963.64 1995.54 2027.29 CONOCO INC. BAOAMI,Badami 2 BADANI,NORTN SLOPE, ALASKA Inctin. Azimuth True Vert. R E C T A N G U L A R DogLeg Degrees Degrees Depth C O O R D I N A T E S Deg/lOOFt 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 415.00 0.00 N 0.00 E 0.00 0.18 132.00 429.12 0.01S 0.02 E 1.27 0.20 94.90 459.77 0.05 S 0.10 E 0.40 0.20 90.00 490.57 0.06 S 0.21E 0.06 0.50 99.50 521.38 ':' "~"0208'.S. ~0;40 E" 0.99 . . . 0.70 87.50 552.11' '..~8.09 S' "0.72 E, ,~0:76 0.88 103.60 582.98 0.14 S 1.14 E 0.92 1.30 98.50 613.76 0.25 S 1.71E 1.40 1.30 95.60 644.58 0.33 S 2.41E 0.21 1.40 90.10 675.32 0.37 S 3.13 E 0.53 1.40 90.20 706.21 0.37 S 3.88 E 0.01 1.80 86.10 737.02 0.34 S 4.74 E 1.35 2.10 85.30 767.83 0.26 S 5.79 E 0.98 2.90 86.60 798.70 0.16 S 7.13 E 2.60 3.20 85.30 829.51 0.05 S 8.77E 1.00 3.40 87.10 860.19 0.07 N 10.54 E 0.73 3.60 87.70 890.98 0.15 N 12.42 E 0.66 3.40 93.40 921.81 0.14 N 14.30 E 1.30 3.40 97.00 983.32 0.19 S 17.94 E 0.35 3.60 · 96.60 1016.11 0.42 S 19.81E 0.65 3.30 96.20 1064.87 0.62 S 21.65 E 0.98 3.60 96.30 1075.64 0.79 S 23.50 E 1.04 3.70 93.40 1106.63 0.92 S 25.66 E 0.37 6.20 90.50 1137.16 0.99 S 27.58 E 1.75 4.70 86.20 1167.90 0.92 S 29.97 E 1.95 5.20 81.60 1198.58 0.63 S 32.61E 2.07 6.10 78.90 1230.16 0.10 S 35.68 E 2.96 6.00 79.10 1261.81 0.54 N 38.98 E 0.32 6.40 82.00 1293.49 1.10 N 42.37 E 1.59 7.10 82.90 1325.12 1.60 N 66.08 E 2.22 8.00 83.40 1356.84 2.10 N 50.26 E 2.82 8.80 8~.10 1388.30 2.60 N 54.88E 2.54 9.60 83.00 1419.89 3.18 N 59.96E 2.56 10.10 83.10 1451.35 3.8~ N .65.38 E 1.57 10.30 8~.00 1482.82 4.47 N 71.01E 0.80 10.40 83.00 1514.05 5.12 N 76.67 E 0.65 10.90 82.80 1545.18 5.8~ N 82.48 E 1.58 11.60 80.40 1576.27 6.75 N 88.60 E 2.66 12.30 79.60 1607.53 7.90 N 95.11E 2.25 13.10 79.20 1638.65 9.19 N 102.01E 2.52 13.00 80.00 1669.73 10.49 N 109.09 E 0.65 12.80 79.20 1700.82 11.78 N 116.10 E 0.84 13.20 78.90 1731.91 13.14 # 123.14 E 1.27 14.50 79.40 1762.67 14.57 N 130.59 E 4.12 16.50 81.40 1793.34 15.98 N 138.98E 6.50 17.80 83.80 1823.78 17.18 N 148.29E 4.65 18.00 82.60 1853.90 18.33 N 157.95 E 1.32 18.90 83.70 188~.01 19.53 N 167.93 E 3.0~ 19.90 8~.10 1914.10 20.65 N 1'78.46 E 3.16 20.90 85.50 1943.91 21.65 N 189.50 E 3.50 21.80 8~.80 1973.62 22.64 N 201.07 E 2.93 22.90 8~.90 2002.98 23.72 N 213.10 E 3.47 SURVEY LISTING Page 1 Your ref : Last revised : 24-Mar-92 ALL data is in feet unless otheruise stated Coordinates are from structure centre and TVOs are from rkb. Vertical section is from ~e[[head on azimuth 80.23 degrees. CaLcuLation uses the minimum curvature method. Vert Sect 0.00 0.00 0.01 0.10 0.20 0.38 0.69 1.10 1.65 2.32 3.02 3.76 4.62 5.66 7.00 8.64 10.40 12.26 14.12 17.64 19.45 21.23 23.02 24.93 27.01 29.38 32.03 35.15 38.50 41.94 45.68 49.88 54.52 59.63 65.08' 70.74 76.43 82.28 88.46 95.08 102.09 109.29 116.41 123.59 131.17 139.67 149.06 158.77 168.80 179.38 190.43 202.00 214.03 Measured Del=th 2059.12 2090.97 2122.75 2154.63 2186.51 2218.41 2250.29 2282.29 2313.94 2345.89 2377.65 2409.42 2441.28 2473.13 2505.01 2536.81 2568.74 2600.62 2632.44 2663.58 2695.04 2726.94 2758.77 2790.50 2822.40 2854.13 2885.85 2917.41 2949.20 3044.59 3140.06 3234.79 3329.15 3424.66 3520.25 3615.76 3679.11 3710.97 3742.65 3774.32 3804.90 3836.31 3868.21 3900.15 3932.26 3964.02 3995.80 4027.64 4091.13 4122.91 4186.86 4218.77 CONOCO INC. BADAMI,Badami ~ BAOAMI,NORTN SI.~PE~,RLASKA SURVEY LISTING Page 2 Your ref : Last revised: 24-Nar-92 lncLin. Azimuth True Vert. R E C T A N G U L A R DogLeg Vert Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 23.30 84.80 2032.26 24.8, N 225.53 E 1.26 226.48 24.10 84.?0 2061.42 26.01 N 238.28 E 2.51 239.24 24.80 83.50 2090.35 27.37 N 251.36 E 2.70 252.36 25.90 81.50 2119.16 29.15 N 264.90 E 4.37 266.00 26.90 82.30 2147.72 31.15 N 278.93 E 3.33 280.17 27.80 29.10 29.60 30.10 30.40 82.20 2176.05 33.12 N 293.45 E 2.82 81.60 2204.08 35.27 N 308.48 E 4.18 81.00 2231.97 37.64 N 323.99 E 1.81 80.10 2259.42 40.23 N 339.53 E 2.12 78.90 2287.02 43.16 N 355.35 E 2.11 294.82 310.00 325.68 341.43 357.52 373.66 389.96 406.60 423.64 440.97 458.42 476.19 494.35 512.78 530.82 548.93 567.22 585.47 603.70 622.12 640.56 659.03 677.36 695.77 750.73 805.61 859.73 913.97 969.08 1023.14 1075.67 1109.98 1127.23 1144.20 1161.06 30.70 31.00 32.00 32.70 33.20 80.20 2314.38 46.09 N 371.23 E 2.28 80.50 2341.65 48.82 N 387.29 E 1.06 80.20 2368.82 51.61 N 403.70 E 3.18 78.20 2395.72 54.80 N 420.44 E 4.01 79.10 2422.48 58.22 N 437.44 E 2.19 33.40 34.30 35.30 35.70 35.30 7T.90 2449.06 61.70 # 454.55 E 2.16 77.10 2475.57 65.55 N 471.91 E 3.14 76.50 2501.75 69.70 N 489.62 E 3.32 75.80 2527.66 74.13 N 507.56 E 1.79 77.20 2553.01 78.35 N 525.14 E 2.91 35.10 35.00 35.10 35.10 35.50 76.70 2578.72 82.44 N 542.81 E 1.12 77.20 2604.83 86.58 N 560.66 E 0.95 77.50 2630.89 90.58 N 578.49 E 0.62 7T.80 2656.85 94.49 N 596.32 E 0.54 78.20 2682.88 98.32 N 614.35 E 1.45 35.60 35.70 35.40 35.40 35.00 77.90 2708.70 102.14 N 632.40 E 0.63 77.90 2734.47 106.01 N 650.4? E 0.32 78.30 2760.15 109.80 N 668.43 E 1.20 78.20 2786.06 113.55 N 686.46 E 0.18 78.70 2864.01 124.56 N 740.33 E 0.52 35.20 34.50 35.70 34.80 34.10 79.20 2942.12 135.08 N 794.20 E 0.37 79.10 3019;86 145.27 N 847.37 E 0.74 78.70 3097.06 155.72 N 900.61E 1.29 79.00 3175.06 166.38 N 954.69 E 0.96 81.80 3253.89 175.40 N 1007.99 E 1.81 32.70 83.40 3333.62 182.19 N 1060.12 E 1.73 33.10 85.40 3386.81 185.54 N 1094.37 E 1.83 32.80 85.90 3413.55 186.86 N 1111.64 E 1.27 32.40 86.60 3440.24 187.98 N 1128.68 E 1.74 32.30 85.?0 3466.99 189.11 N 1145.58 E 1.55 32.20 86.30 3492.86 190.25 N 1161.86 E 1.10 32.40 85.30 3519.40 191.48 N 1178.60 E 1.82 33.20 84.20 3546.22 193.06 N 1195.81 E 3.13 34.20 82.80 3572.79 195.07 N 1213.41 E 3.96 34.10 83.10 3599.36 197.28 N 1231.30 E 0.61 1177.30 1194.00 1211.23 1228.92 1246.92 33.80 8~.00 3625.71 199.28 N 1248.93 E 1.8~ 33.50 83.70 3652.16 201.16 N 1266.44 E 1.08 32.10 83.40 3678.93 203.10 N 1283.57 E 4.43 31.90 83.10 3732.77 207.06 N 1316.98 E 0.40 31.40 83.50 3759.82 209.00 N 1333.55 E 1.71 1264.63 1282.20 1299.42 1333.02 1349.67 30,70 83,90 3787,21 210,81 N 1349,9~ E 2,28 30.50 84.00 3814.74 212.53 N 1366.12 E 0.64 29.80 82.50 3842.33 214.41 N 1382.04 E 3.22 1366.13 1382.38 1398.38 ALL data is in feet unless otherwise stated Coordinates are fro~ structure centre and TVOs are fro~ rkb. Verticat section is fro~ wetthead on azimuth 80.23 degrees. CatcuLation uses the minimum curvature method. Neasured Depth 4250.65 4282.46 4314.31 4346.00 4377.81 4409.67 4441.47 4472.82 4504.78 4536.76 4568.64 4600.31 4632.15 4664.00 4695.76 4727.58 4759.54 4791.44 4823.32 4855.32 4887.18 4918.67 4950.49 4982.45 5013.96 5045.76 5077.55 5109.40 5141.24 5173.12 5204.96 5236.65 5268.45 5300.37 5332.10 5363.98 5394.30 5426.11 545?.86 5489.76 5521.01 5552.99 558~.93 5616.83 5647.8~ 5679.74 5711.55 5728.55 5743.52 5764.50 5853.00 5879.71 5968.00 , CONOCO INC. BADAMI,Badam{ BADRMI,NORTH AS~:~,.ASKA SURVEY LISTING Page 3 Your ref : Last revised : 24-Mar-92 InctJn. Azimuth True Vert. R E C T A N G U L A R DogLeg Vert Degrees Degrees Depth C 0 0 R D I g A T E S Deg/lOOFt Sect 29.20 82.60 3870.08 216.44 N 1397.61 E 1.89 1414.06 28.80 81.50 3897.90 218.58 N 1412.88E 2.10 1429.4.8 28.30 80.00 3925.88 221.02 N 1427.90 E 2.74 1444.70 27.50 76.70 3953.89 224.01 g 1442.42 E 5.49 1459.51 26.70 76.10 3982.20 227.42 N 1456.51 E 2.66 1473.97 26.40 26.10 25.50 24.50 24.40 76.00 4010.70 230.85 N 1470.33 E 0.95 1488.18 76.10 4039.22 234.24 N 1483.98 E 0.95 1502.20 75.70 4067.45 237.56 N 1497.21 E 1.99 1515.81 74.90 4096.42 240.99 N 1510.28 E 3.30 1529.26 74.50 4125.53 244.48 N 1523.04 E 0.60 1542.44 24.30 74.50 4154.57 247.99 N 1535.71 E 0.31 1555.52 24.10 76.20 4183.46 251.28 N 1548.27 E 2.29 1568.45 24.00 75.20 4212.54 254.48 N 1560.8~ E 1.32 1581.39 23.40 76.40 4241.70 257.62 N 1573.25 E 2.42 159~.15 22.10 76.00 4270.99 260.55 N 1585.18 E 4.12 1606.40 21.50 21.10 20.80 20.00 19.20 76.00 4300.53 263.41 N 1596.64 E 1.88 75.30 4330.31 266.29 N 1607.89 E 1.48 75.00 4360.10 269.21 N 1618.92 E 1.00 75.90 4389.98 272.00 N 1629.67 E 2.70 76.30 4420.13 274.58 N 1640.09 E 2.53 1618.19 1629.76 1641.12 1652.19 1662.90 1673.22 1683.15 1692.94 1702.58 1711.68 18.70 18.10 17.80 17.40 16.30 76.60 4450.26 277.01 N 1650.15 E 1.60 77.80 4480.14 279.21 N 1659.84 E 2.25 77.20 4510.41 281.33 N 1669.42 E 1.11 75.20 4540.87 283.64 N 1678.80 E 2.27 75.80 4571.03 285.92 N 1687.64 E 3.53 15.50 76.20 4601.61 288.03 N 1696.09 E 2.54 15.30 76.50 4632.26 290.03 N 1704.30 E 0.68 14.90 79.30 4663.01 291.77N 1712.41 E 2.61 14.10 78.80 4693.8~ 293.28 N 1720.24 E 2.54 13.50 7T.40 4724.80 294.85 N 1727.68E 2.15 1720.37 1728.8O 1737.08 1745.05 1752.65 12.50 77.40 4755.82 296.41 N 1734.66 E 3.14 11.80 80.70 4786.80 297.68 N 1741.21 E 3.11 10.90 82.90 4817.98 298.58 N 1747.40 E 3.14 10.30 82.60 4849.36 299.32 N 1753.23 E 1.89 9.70 80.50 4880.60 300.12 N 1758.68 E 2.21 1759.81 1766.47 1772.73 1778.59 1784.10 8.90 81.70 4912.06 300.92 N 1763.77E 2.58 8.00 80.70 4942.06 301.60 N 1768.17 E 3.01 7.80 81.00 4973.56 302.30 N 1772.49 E 0.64 7.70 78.20 5005.02 303.07 N 1776.70 E 1.23 7.20 76.70 5036.65 303.97 N 1780.73 E 1.68 1789.25 1793.70 1798.08 1802.36 1806.49 6.20 78.00 5067.69 304.77N 178~.29 E 3.24 5.00 79.50 5099.52 305.38 N 1787.35 E 3.78 3.60 84.40 5131.37 305.73 N 1789.72 E 4.53 2.90 82.50 5163.22 305.94 N 1791.51 E 2.22 2.40 88.10 5194.19 306.06 N 1792.94 E 1.81 1810.13 1813.25 1815.64 1817.45 1818.87 1.40 95.70 5226.07 306.04 N 1794.00 E 3,22 0.20 98.70 5257.88 306.00 N 1794.44 E 3.77 0.30 226.20 5274.88 305.96 N 1794.43 E 2.65 0.40 266.70 5289.85 305.93 N 1794.35 E 1.74 0.80 267.40 5310.83 305.92 N 1794.13 E 1.91 1819.91 1820.34 1820.33 1820.24 1820.03 1.36 260.46 5399.31 305.72 N 1792.48 E 0.65 1.34 261.39 5426.02 305.62 N 1791.86 E 0.11 1.23 258.13 5514.28 305.27 N 1789.91 E 0.15 1818.36 1817.73 1815.75 Att data is in feet unless otherwise stated Coordinates are fro; structure centre and TVOs are fro; rkb. VertJcat section ~s from weLthead on az{muth 80.23 degrees. Catcutat~on uses the m~n{mum curvature method. CONFIDEI TI CONOCO INC. BADAH I, Badami 2 BADAHI ,NORTH SLOPE, ALASI(A Measured lncLin. Azimuth True Vert. Depth Degrees Degrees Depth 6057. O0 1.07 257.21 5603.26 6137.00 0.79 259.80 5683.25 6220.13 0.91 246.95 5766.38 6277.00 0.78 255.69 5823.24 6354. O0 O. 70 264.10 5900.23 SURVEY LiST%NG Page 4 Your ref : Last revised : 24-Nar-92 R E C T A # G U L A R Dog{eg Vert C 0 0 R D ! # A T E S Deg/lOOFt Sect 30~.89 304.63 30~.27 3O3.99 303.82 6450.00 0.67 259.43 5996.23 303.65 6527.00 0.61 249.38 6073.22 303.43 6577.00 0.60 263.21 6123.22 303.30 6674.00 0.71 261.16 6220.21 303.15 6769.00 0.34 269.29 6315.21 303.06 6818.00 0.29 260.13. 6364.21 303.03 6907.00 0.26 296.83 6453.21 303.08 6995.00 0.30 288.85 6541.20 303.25 7077.00 0.26 323.56 6623.20 303.47 7157.00 0.29 322.68 6703.20 303.78 ?227.00 0.29 322.68 6773.20 304.06 N 7318.00 0.39 257.98 6864.20 304.18 N 7402.50 0.20 317.16 6948.70 304.22 N 7496.37 0.17 305.20 7042.57 304.42 N 7593.32 0.15 332.64 7139.52 304.62 N 7691.21 0.22 307.12 7237.41 304.85 N 778~.29 0.20 331.73 7330.49 305.10 N 7879.93 0.24 329.02 7426.13 305.42 N 7970.7'2 0.14 323.48 7516.92 305.67 N 8068.83 0.21 312.12 7615.03 305.89 N 8166.51 0.42 354.53 7712.70 306.36 8260.29 0.30 348.97 7806.48 306.94 8324.45 0.25 335.48 7870.64 307.24 8~22.77 0.47 351.03 7968.96 307,83 8520.?2 0.39 354.45 8066.91 308.56 8613.96 0.36 6.34 8160.14 309.17 8706.66 0.24 353.26 8252.8~ 309.65 8803.00 0.16 264.61 8349.18 309.8~ 8901.03 0.28 234.33 8~47.21 309.68 8993.34 0.51 223.43 8539.52 309.25 9090.52 0.77 228.63 8636.70 308.51 N 9186.67 0.62 235.57 8732.8~ 307,79N 9280.50 0.60 234.84 8826.66 307.22 N 9376.33 0.60 233.21 8922.49 306.63 N 9472.11 0.41 234.25 9018.26 306.13 N 9565.77 0.54 215.66 9111.92 305.57 9662.86 0.50 187.55 9209.01 304.78 9752.35 0.40 153.65 9298.49 304.11 9851.57 0.25 81.17 9397.71 303.8~ 9943.28 0.20 129.06 9489.42 303.77 10038.65 0.21 166.63 9584.79 303.49 10138.17 0.20 170.12 9684.31 303.14 10234.19 0.29 172.97 9780.33 302.74 10323.68 0.35 176.11 9869.82 302.24 1~18.01 0.34 168.42 9964.15 301.68 1788.17 E 0.18 1813.97 1786.90 E 0.35 1812.67 1785.72 E 0.27 1811.~6 1784.93 E 0.32 1810.63 1783.96 E 0.17 1809.6~ 1782.82 E 0.06 1808.49 1782.00 E 0.16 1807.64 1781.49 E 0.29 1807.12 1780.39 E 0.12 1806.01 1779.52 E 0.40 1805.14 1779.26 E 0.14 1804.88 1778.86 E 0.20 1804.49 1778.46 E 0.06 1804.12 1778.15 E 0.21 1803.85 1777.92 E 0.04 1803.68 1777.70 E 0.00 1803.52 1777.26 E 0.41 1803.10 1776.88 E 0.40 1802.73 1776.65 E 0.05 1802.54 1776.48 E 0.08 1802.40 1776.27 E 0.11 1802.24 1776.05 E 0.10 1802.06 1775.85 E 0.04 1801.94 1775.70 E 0.11 1801.82 1775.50 E 0.08 1801.65 1775.33 E 0.31 1801.57 1775.25 E 0.13 1801.59 1775.16 E 0.13 1801.55 1775.01 E 0.24 1801.50 1774.91E 0.08 1801.53 1774.91 E 0.09 1801.64 1774.92 E 0.15 1801.73 1774.77E 0.30 1801.60 1774.44 E 0.17 1801.25 1773.97 E 0.26 1800.72 1773.18 E 0.27 1799.82 1772.27 E 0.18 1798.79 1771.45 E 0.02 1797.89 1770.64 E 0.02 1796.99 1769.96 E 0.20 1796.23 1769.43 E 0.21 1795.62 1769.10 E 0.26 1795.17 1769.19 E 0.31 1795.14 1769.56 E 0.41 1795.45 1769.88 E 0.20 1795.76 1770.05 E 0.14 1795.88 1770.12 E 0.02 1795.89 1770.18 E 0.09 1795.88 1770.23 E 0.07 1795.84 1770.30 E 0.05 1795.82 10512.63 0.30 176.46 10058.76 301.16 N 1770.38 E 0.06 1795.80 10611.90 0.25 180.66 10158.03 300.68 # 1770.39 E 0.05 1795.74 10673.70 0.23 218.98 10219.83 300.45 # 1770.31 E 0.26 1795.62 ALL data is in feet unless otherwise stated Coordinates are from structure centre and TVOs are from rkb. Vertical section is from weLLhead on azimuth 80.23 degrees. CaLcuLation uses the minimum curvaturemethod. OEN'IiAL Measured Depth 10770.73 10860.55 10958.60 11051.85 11141.25 11240.08 11340.76 11435.60 11495.50 11545.65 11617.80 11711.94 11782.01 11860.00 CONOCO BADAHI,Baclami 2 BADAH%,#ORTH SLOPE, ALASKA Inctin. Azimuth True Vert. Degrees Degrees Depth 0.74 227.58 10316.86 0.59 223.38 10406.67 0.62 ?.29.70 10504.72 0.66 221.30 10597.96 0.66 22/,.50 10687.36 0.62 222.68 10786.18 0.35 241.77 10886.86 0.41 235.40 10981.69 0.41 26/,.60 11041.59 0.28 288.23 11091.74 0.46 273.11 11163.89 0.59 274.51 11258.03 0.21 327.19 11328.10 0.21 327.19 11406.08 SURVEY L]STING Page 5 Your ref : Last revised : 24-Mar-92 R E C T A N G U L A R DogLeg Vert C 0 0 R D ! N A T E S Deg/lOOFt Sect 299.88 # 1769.72 E 0.53 1794.94 299.15 N 1768.98 E 0.18 1794.09 298.~ # 1768.?..3 E 0.07 1793.22 297.71 N 1767.49 E 0.11 1792.37 296.95 II 1766.79 E 0.04 1791.55 296.15 N 1766.02 E 0.04 1790.67 295.61 il 1765.38 E 0.31 1789.94 295.28 N 176~.85 E 0.08 1789.36 295.14 N 176~.46 E 0.34 1788.95 295.16 N 176~.17 E 0.38 1788.67 295.23 N 1763.71 E 0.28 1788.23 295.29 N 1762.85 E 0.14 1787.39 295.42 N 1762.42 E 0.70 1786.99 295.66 il 1762.26 E 0.00 1786.88 CONFIDENTIAL R'£CEIVED APR 8 7992 ~llas. lfa.Oil.& 8as Cons. Co ', ,' ' ~ci~orage remission ALL data is in feet unless otheruise stated Coordinates are from structure centre and TVDs are from rkb. Vertical section is from ~eLLhead on azimuth 80.23 degrees. CaLcuLation uses the minimum curvature method. CGNO'CO Structure · BADAMI Field · BADAMI Well · Badami 2 Location · NORTH SLOPE, ALASKI u'l 0 oo soo,,,- ,oo. oo East => I I I I ! I I I I I I I I I I ! ! I I I I I I I [ I I I I I I I I ! I~ RKB to Woter Une - 38 ft. ....... ............ :*'_;~ ....... CANNING TURBIDITE 13-3/8 ~oZ 9-5/8 csg ~ i i i i i · 1000 l~O0 2000 2~00 ~00.00 Vedlcal Section on 80.23 azimuth with reference 0.00 N, 0.00 E from structure centre Western Atlas International CORE LABORATORIES TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT TO: ALASKA OIL AND GAS COMM. 3001 PORCUPINE DR. ANCHORAGE, ALASKA A'i'TN: LARRY GRANT MATERIALS RECEIVED VIA: CORE LAB PERSONNEL ITEMS RECEIVED: STATE CHIPS Cogoco ,,,,,-BOX 1 OF 2 .~'". BOX 2 OF 2 I BADAMI #2 10730 - 10774 FEET 10775 - 10789 FEET RECEIYE APR Na~s~ OiL ~ Bas Gons. Gom~'~.~Lo.~. Shipped by: PERRY BROWN./ .-, . for COREl_AB Date: 23-APR-92 Received by: ' __.. _...: .._ ~_ for AOGC Date: C' Please note tha~~tems iiste~above are inventoried, shipped and recieved 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. 8005 Schoon Street, Anchorage, Alaska 99518-3045, (907) 349-3541, Pax (907) 344.2823 COMPL.,""ION DA'r[ ~/ ~/$ / ~,~-- CO. CONTACT AOGCC GEOLOGICAL MATERIALS INVENTORY UST [ check off or list data as it is rec=ived ) 4o7 I ~//.~/~,~ driilin9 histo~ ~ 'smve~, I ~ ~!, tests ~-"i~'core desriptio~' cored intervals core anal~/sis ~ dry, ditch intervals diQital data /~ '730'-/o 7f'o' ~o/---//,~',('o / ,.¢'..a ~'~, LOG TYPE RUN INTERVALS SCALE NO. 1) 2! ~ , 4! , , ,, 8} , ~ , ,~,~),, 12) , · ~3) .... 1 ~) , lq .... 17] , , oj , J 19) April 8, 1992 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 Mr. Mike Minder Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ¢11./¢¢ RE: Revise~ Fox-at X0-403 For B&~ami No.2 Dear Mr. Minder: Attached is the revised Form 10-403 for the Badami No. 2 exploratory well originally submitted in a correspondence dated March 30, 1992, from Steve Bolt. The revised form includes the 20" casing data as "surface" casing. This data was neglected in the original submittal. Please replace the original form with the revised form attached. I apologize for any inconvenience, this may cause. Please feel free to contact me' if you have. any questions. Best Regards, Jeff Allison Drilling ~ngineer cc: Badami #2 Well File . SGB, JLA, RSR " RECEIVED APR 1 0 1992 Alas~ Oil & Gas Cons. . , · . (~ STATE OF ALASKA ALA$,v~ OIL AND GAS CONSERVATION COMMi~,~iON APPLICATION FOR SUNDRY APPROVALSu IG L 1. Type of Request: Abandon X Suspend Nter casing Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well m Plugging __ Time extention __ Stimulate Pull tubing Variance Perforate Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200, Anchorage, AK g9503 5. Type of Well: Development Exploratory X Stratigraphic Service Location of well at surface 2700' FNL, 700' FWL, SEC 30, T10N, R20E, U.M., Alaska At top of productive interval 10,579' MD, 10,125' TVD, 2399' FNL, 2471' FWL, SEC 30, T10N, R20E, U.M., AK At effective dept At total depth 11,860' MD, 11,406' TVD, 2404' FNL, 2464' FWL, SEC. 30, T10N, R20E, U.M., AK 12. Present well condition summary Total depth: measured 11,860 (MD) true vertical 11,406 (TVD) 6. Datum elevation (DF or KB) 35' KB, 38' ASL 7. Unit or Property name Badami 8. Well number 2 9. Permit number 91-144 10. 11. feet APl number 5O-O29-2223O Reid/Pool Badami Prospect feet Plugs (measured) From feet 11,082' MD - 11,640' MD 10,628' TVD - 11,186' TVD Effective depth: measured 10,579 (MD) feet Prod. Top true vertical 10,125 (TVD) feet Junk (measured) none Casing Length Structural 16' 48" Conductor 97' 30" Surface 382' 20" Intermediate 5,770' 13-3/8" Production 10,504' 9-5/8" Uner Perforation Depth: Size Cemented Measured depth True vertical depth N/A 51' KB 51' Surface 132' KB 132' Surface 417' KB 417' Surface 5,805' KB 5,531' 9539' - Class 'G' 10,539'KB 10,085' measured Open Hole 10,539' KB - 11,082' KB 10,085' TVD - 10,628' TVD true vertical Tubing (size, grade, and measured depth) NONE Packers and SSSV (type and measured depth) NONE RECEIVED APR 10 1992 Alaska 0il & Gas Cons. C0mmissio~; Anchorage 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 04/04/92 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signs/d/.,~x- , /- Title Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness 15. Status of well classification as: Suspended __ Exploration X Plug integrity BOP Test Mechanical Integrity Test Location clearance Su'---bsequent form required 10--'~-o Approved by order of the Commission ORIGINAL SIGNED BY L,ONNIE C. S~/IITH Commissioner Gas Date 03/27/92 =..,~ ..... ;.."..'":. ~:;'il Approval ,,. . :.,. Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE F APRIL 03, 1992 SAMPLES SHIPPED OUT AS OF TODAY TO' LARRY GRANTY ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PH' 279-1433 FR' EX LOG, INC. 5430 FAIRBANKS ST. ANCHORAGE, ALASKA (907)563-3112 FAX:(907) 562-7602 SUITE 11 99518 THE FOLLOWING DRY CUTTINGS ARE BEING DELIVERED TODAY. CONOCO BADAMI ~t 2 WELL DRY CUTT T NG SAMPLES ITEM NO' DESCRIPTION SET B BOX 10 COVERING THE INTERVAL FROM 9980' - SET B BOX 11 COVERING THE INTERVAL FROM 10610'- SET B BOX 12 COVERING THE INTERVAL FROM 11270' - 10600' 11260' 11860' PLEASE CALL NE IF YOU HAVE ANY qUFRTT(3N.q .~ THIS SHIP~4FIdT_ ~INCERELY, ~ ~"-- ,. ,- ' "~ RAQUEL RODRIGUEZ /0 ~ ~I 0 -' I 0 [ ~ ~ / EXLOG, INC. , . __ _l / ADMINISTRATIVE ASSISTANT /07/0 / FROM CONOCO ANCHORAGE TO 927G7542 ,, ( PAGE. 00~./00G that ~ha? na~ be present to vt~noaa tho vork. lo Pi~k up a 905/8', 47 #/St casing scraper and TTH tO the 9-5/8' casln~ shoe at .~ O, .~.~g' MD. Circulate and condition mud. POOH. o Pick up a 9-5/8', 47 f/st ceuent retainer and T'XH to 10,489 MD. Se~ re~ainer at lO,480~ HD (S0e a~ve oh~) ~ d~ ~eeze class '~' c~ent (~28o sx) ~ 10,gl0' ~ (50' ~iov h~d~~n zone), sting out o~ retainer and o~ 100' o~ class *G' coent on 2ap of retainer. 3~ POOH 3 stands and circulate bottoms up. Pressure test plug to 4~ Rig up electric line perforating and RIH to 575~' MD. Perforate the 9-5/8" casing at 2 SPF from 575S~ to 5757'~. ~OOH and rig dc~n electric line. Pick up a 9-5/8#~ 47 ;/£t cement retainer and Tx2 =0 5705, (so, a~ove perforations), se~ retainer at s705' HD. Open g* 5/9# X 13-3/8~ ~if~J valve and spot a 5o0' annular class ,~, ~l~g frou 57S7t to 5257' leaving 50' of cement below retainer ~nthe ~-5/8" ~asIng. Sting out O~ re~a~ner an~ spo~ 100, class 'G" cemen~ on top of retainer to TOC at e POOH 3 stands and circulate botto~s up. Pressure test plug to 1ooo psi for 30 minu~es. POOH to 2000' MD. Displace mud with 10.2 PI~ ~reeze protect ~rine. POOH. 8~ Pick up a 9-5/8" casing cutter and TIH ~o 206' ND (165' BML). Cut 9-5/8H casing at 206~ MD. POOH. Lay down 9-5/8~ casing. g~ Pick up a 13-3/$u re=ainer and TIH to 206' MD (165' BML). Set the re~ainer' at 206 10. stin~ ou~ of ~he retainer and spot a 150' Pe~mafrose u~-~-nt plug frOm 56' to 206~ ~ (15t to 165~ ~). ~H. W~ and confi~ plug. 9. Remove casin~ s~r~,ng~ tn at least 15' BML. APR 2 1992 & Gas Cons. Commission Anchorage CONFiDENTiAL PROPOSED BADAMt #2 WELLBORE SCHEMATIC R~AINDi;I ~ 208' KB (~05' EL) ETOC @ 9,539' (~0' ~OW HYB~OCA~N ZONE} I~' C~ ON TOP ~/8~, 47~, N~O, ~ i0,5~' K~ - C~ TO 9539' ISOLATION PLUG Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 March 30, 1992 Mr. D. W. Johnston Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear D. W. Johnston, We are presently in the process of testing our Badami # 2 well, Permit No. 91-144. At the conclusion of the test we will be plug and abandoning the well. Please find attached our application and procedures to P & A Badami #2. We anticipate commencing abandonment operations on April 2, 1992. Best Regards, Steve Bolt Division Drilling Superintendent R.ECEIVED MAR ~ 1 1992 Alaska Oil & Gas Cons. Commission Anchorage ALA~ . OIL AND GAS CONSERVATION COMMI'-.~- ,,ON APPLICATION FOR SUNDRY APPROVALS 1. T~e of ~que~: ~andon X ~spe~d ~ Operation sh~down ~ ~nter suspended well 3, Alter casing Change approved program Name of Operator Repair well __ Plugging __ Time extention Pull tubing Varianco Perforate ~imulate Other 5. Type of Well: 6. Conoco Inc. Development Address Exploratory X 7. 3201 C Street, Suite 200, Anchorage, AK 99503 Stratigraphic. Sen/i~ Location of well at sudace 8. 2700' FNL, 700' FWL, SEC 30, T10N, R20E, U.M., Alaska At top of productive interval 9. Datum elevation (DF or KB) 35' KB, 38' ASL Unit or Property name Badami 10,579' MD, 10,125' TVD, 2399' FNL, 2471' FWL, SEC 30, T10N, R20E, U.M., AK At effective dept At total depth 11,860' MD, 11,406' TVD, 2404' FNL, 2464' FWL, SEC. 30, T10N, R20E, U.M., AK 12. Present well condition summary 11. Well number 2 Permit number 91-144 10. APl number 50-029-22230 Field/Pool Badami Prospect Total depth: measured 11,860 (MD) feet Plugs (measured) From true vertical 11,406 ('rVD) feet Effective depth: measured 10,579 (MD) feet Junk(measured) none Prod. Top true vertical 10,125 ('I'VD) feet Casing Length Structural 16' Conductor 97' Surface 5,770' Intermediate 10,504' Production Uner Perforation Depth: Size Cemented Measured depth 48" N/A 51' KB 30" Surface 132' KB 13-3/8" Surface 5,805' KB 9-5/8" 9539' - Class 'G' 10,539'KB measured Open Hole 10,539' KB - 11,082' KB 10,085' TVD - 10,628' TVD true vertical Tubing (size, grade, and measured depth) NONE Packers and SSSV (type and measured depth) NONE 11,082' MD - 11,640' MD 10,628' TVD - 11,186' TVD True vertical depth 51' 132' 5,531' 10,085' RECEIVED MAR 1 1992 Alaska 011 & Gas Cons. CommissiOn Anchorage 13. Att?_chments Dasoription summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operaGon 15. Status of well classification as: 04/04/92 16. If proposal was verbally approved Oil ~ Name of approver Date approved Sen/icc 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ . Title Drilling Engln,..,. FOR COMMISSION USE ONLY Conditions of approval: N,;,;~;y/Commission so representative may wlthess ' Plug integrity _~ BOP Test Location clearance Mechanical Integrity Test__ ~"ubsequent form required 10-"~ ~> Approved by order of the Commission Commissioner Gas Suspended__ Date 03/'27/92 IApproval No. ~0. ~ 7.~ Date ORIGINAl., S!GNED BY' LON~!!E ~. SMITH Exploration X Form 10-403 Rev06/15/88 SUBMIT IN TRIPLICATE TO: THRU: FROM: MEMORANuUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION .. Lonnie C S~Q/~ DATE: March 27:1992 Commissior~er''J~u FILE NO: .1 g32792, doc Blair Wondzell Sr Petr Eng TELEPHONE NO: SUBJECT: BOP Test, Nabors 26-E Conoco Badami #2 Permit 91-144 Exploratory SEC 30,T10N,R20E,UM Louis R Grimaldi Petr Inspector Thursday, March :~26..:~1992 I traveled to conoco's exploratory well Badami #2 to witness a BOP test on Nabor's Rig 26-E. This rig had been stacked previous to drilling this well and showed signs of neglect in its cosmetic appearance. Once the test was under way, it became apparent to me that the necessary B.O.P.E. equipment had been thoroughly gone through and I could find no noncompliances. I think that Mike Williams (Nabor's toolpusher) did an excellent job in reactivating this rig as he was more than prepared for this state-witnessed BOP test. The location was well laid out and all fuel and fluid containers were adequately bermed with herculite and timbers. The rig will be testing the well for approximately a week and will then plug back. They shall notify us so we may witness the plug tags. In summary, 'I witnessed a good BOP test on Nabor's Rig 26-E drilling Conoco's Badami ~2. All items were found to be in compliance. jMAR-27-' 92 07: 04 ] D: CONOCO BADAM ] TEL NO: 905'5647642 OPERAYION: Dnlg ~. - STAT~ or ALA$1C~ ALASKA OIL .aND GAS COHST:RYATION COHl41~$1OI4 BOP Test Repol-t~ ntg/),{',,~ HUD 5Y,~ TG~S ~ Visual Audio , THp tank Z//' . _1 r,..o.,..',1-.. ...... Pu~ ~CP clos Proms 200 p~tq ~ mtn ~ B~ co...o,,, ...., , ~ ,m _L I KELLY AND FL, OO%,~A..Fgq'y Upper 1(ol ._9QPE 5TACKz Test Preuurn Lower Kelly ~' Annular preventer .... ~4~)/~1:) ,,,, .... Bill ~¥pe Ch~e 1 t~ vulvas _ . ..~P D D Number valves ~R vllve / ~.;~ I~ ~00 Humber fl.ngol Test presaure ....~:5-~ C) ~ ~ Te~% pressure Test pressure ~OOO Teat pr~.ure /~ ..... / o~d ,, Repair or replacement Df fatled equtpmen'l; ~o be made wtt~hln ,'"--' days. No, try the Inspector~ and follow wtth wrlc~en/FAXed [276-75~,Z] verltl~t~lOfT tO C:(~mfsaion office. RECEIVED rt~'ZX~ 2 7 1992 ~mska Ull & Gas C, 9,ns,. Commission Anchorage --. Oistribueton: nr{g - At~.CC e - Superv~nor Wa~ red by: Wtl:nes&ed by, C.O0~ (rev 03/92) MARCH TO' 11, 1992 T~ LARRY GRAN ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PH' 279-1433 FR' EXLOG, INC. 5430 FAIRBANKS ST. ANCHORAGE, ALASKA (907)563-3112 FAX:(907) 562-7602 SUITE 11 99518 THE FOLLOWING DRY CUTTINGS ARE BEING DELIVERED TODAY. CONOCO BADAMI ~f 2 WELL DRY CUTTING SAHPLES ITEM NO' DESCRIPTION SET C BOX 5 COVERING THE INTERVAL FROM 5800' - 7270' SET C BOX 6 COVERING THE INTERVAL FROM 7300' - 8300' SET C BOX 7 COVERING THE INTERVAL FROM 8310' - 8830' SET C BOX 8 COVERING THE INTERVAL FROM 9400' - 9980' SET C , BOX 9 COVERING THE INTERVAL FROM 9990' - 10600' PLEASE CALL ME IF YOU HAVE ANY QUESTIONS REGARDING THIS SHIPMENT.'; ~r~7o ~ ~ ~o ~~..~ ~.. > ~.,~o~.,.e._. SINCERELY, ~~ --__ ~XLO~, ~NC. *SS~ST,NT ADHZN[STRAT[VE RECEIVED r< s ~ ~ ~ ~ MAR ~ 4199~ AI~ Oil & FEBRUARY 24, 19[ TO' LARRY GRANT~ ALASKA OIL ,ND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 ~Hf (907) 279-1433 FR: EXLOG, INC. 5430 FAIRBANKS ST. ANCHORAGE, ALASKA (907)563-3112 FAX:(907) 562-7602 SUITE 11 99518 THE FOLLOWING DRY CUTTINGS ARE BEING DELIVERED TODAY. CONOCO BADAMI # 2 WELL DRY CUTTTNG SAHPLES ITEM NO' SET C BOX 2 SET C BOX 3 SET C BOX 4 DESCRIPTION --m------------ ------------------------------------------ COVERING THE INTERVAL FROM 1120' - 3370' COVERING THE INTERVAL FROM 340'0' - 4750' COVERING THE INTERVAL FROM 4780' - 5785' PLEASE CALL ME SINCERELY, EXLOG, INC. ADMINISTRATIVE ASSISTANT RECEIVED BY' IF YOU HAVE ANY QUESTIONS REGARDING THIS SHIPMENT. :fl,' _--io o/ DATE- RECEIVED FEB 2 4 i992 Naska Oil & Gas Cons. Commission ALASKA OIL AND GAS CONSERVATION CO~IMISSION January 27, 1992 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Steve Rossberg Sr. Drilling Engineer Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Re: Well Name: Badami #2 Conoco Inc. Permit No: 91-144 Sur. Loc. 2700'FNL, 700'FWL, Sec. 30 T10N, R20E, UM Btmhole Loc. 2390'FNL, 2500'FWL, Sec. 30, T10N, R20E, UM Dear Mr. Rossberg: 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 ;%AC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drillingbelow 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 inspector on the North Slope Pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. r.~% r~,intcd on recycled r..~!:~,'r I") ~,' C: t~ Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (9O7) 564-76OO January 10, 1992 Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 '.-'..,R ENG ~ ~NG A'~;'T '"' ENG A~§T-- T SR GEOL I GEOL ASSTI GEOL ASSTI , STAT TECHI J ;STAT TECHI J IFILE RE: Addendum to the Badami No. 2 and Northwest Milne No. Drilling Permit Applications. Dear Mr. Smith: In response to our telephone conversation on 1/9/92 and to conform with regulation 20 AAC 25.047., Conoco Inc. proposes to place 400 bbls. tank capacity at both the Badami No. 2 and the Northwest Milne No. 1 locations. If you have any further questions regarding these wells, please direct them to me at 564-7637. Senior Drilling Engineer cc: SGB, JLA Badami No. 2 Well File File: 500.21.11 RSR RECEIVED JAN 1 0 1992 Alaska 0il & Gas Cons. commission Anohorag~ January 8, 1992 coMi,:~ ................ COMM COMM Conoco Inc. RES I=NG 3201 C Street, Suite 200 SR ENG Anchorage, AK 99503-3999 SR ENG (907) 564-7600 ENG ASST / - ~,',-,-i;' ~---. ENG ASST ~ GEOL ASST: .,.,.,,.,..'~,,,~','./;..~:~. ..... ':,, ~.: ,:.....r..~~,: 'it"c,.,..?.,..'.....,,~ GEOL ASST ,,,..-' c ........ ' ?:~;. . STAT TECH ] ~' ~ "?'...-, :'.i" STAT TEC'R ...... ~ b , FILE ...... j David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Addendum to the Badami No. 2 and Northwest Milne No. 1 Drilling Permit Applications'. Dear Mr. Johnston-. In response to a telephone conversation on 1/8/'92, with Mike Minder of the AOGCC, Conoco Inc. submits the following addendum to the Badami No. 2 and Northwest Milne No. 1 Drilling Permits: 1) 2) Attached is the anticipated pressure.profile for the Badami No. 2 well. (also included in the original permit), indicating a pore pressure of 11.8 ppg and a proposed mud weight of 12.5 ppg at. total depth. As stated in the drilling permit, the anticipated 'leak-off test at the surface casing shoe is 14.5 ppg (5,300' TVD). These design parameters were.derived from offset well data, including the Badami No. 1. Based on these factors, it is considered prudent to continue drilling to a total depth of 12,000' TVD without setting..casing above the.anticipated pressure transition zone located at 9,300' TVD.:. .. While drilling the Badami No. 2 and Northwest Milne No. 1, Conoco will adhere to strict well control practices (See the attached pressure control' procedure). Flow and pit level indicators will be set in a 5 bbl. position and will be functioning properly at all times. Therefore, any influx taken from the well should be less than 5 to 10 bbls. Standard well control procedure will be used to control and circulate out any influxes. The rigs that will be used to drill these wells will have sufficient pit capacity to handle a 50 bbl. influx. In the event of a planned test, sufficient tankage will be brought to location to temporarily store produced fluid until it can be injected or transported to a process facility. RECEIVE.D JAN - 9 199 Alas~ 0il .& Gas Cons. commis$%~[t ~Ghomge (. If you have any further questions regarding these wells, please direct them to me at 564-7637. Very Tru~ Y?urs, Senior Drilling Engineer cc: SGB, JLA Badami No. 2 Well File File: 500.21.11 RSR RE'I EIVED JAN - 9 t992 Alaska Oil & Gas Cons. Gommission Anchorage A]3AMI PRESSURk PRE]F-TI L SL: 2.700' FNL, 700' FWL SEC, 30, TiON, R20E BHL: P390' FNL, 2.500' FWL SEC, 30, TION, R2.0E PTVD: 12000' RKB/MSL: 35' WATER ]}EPTH - 3' PT]}: 12_,430' FORM. ~ ~ ~ L B / G h L CAS LITH. ~- POINTS (TVD) ~ '~ 9 10 11 1P 13 14 15 16 SAGAVANIRK-ToK ~ ' 3L0~; ~ AT 141' SHALE, SAND, GRAVEL AN]] 1000/ ~ 20'430, AT COAL BASE OF PERMAFROST 1535'-1935' 2000' I I I I 3000' , i SAND, SHALE, I SILTSTBNE I 4000' , i I I I 5000' , I 5488' EOCENE -J ~.13-3/8° AT 5,300' TV]) SAN]], SHALE, 14,5 PPG SILTSTONE ~000' FG (EST.) 6748' STAINES TONGUE 7000' (PALEOCENE) SAN]] AND SILTSTONE 8000, ~.,e. ae' _____i_', - CANNING , SHALE AND TURB]DITE 9000' SANDS gPRR' TP/FAN ICANNING PR ;SSURE EXPI'CTED TURBIDITE "'~'~ - ~ _ AT +/- 9,700'1VD OBJECTIVE ] BA ]AHI# 1 PORE SHALE AND 10000' i PR ]SSURE VAS 11,9 PPG . TURB. SANDS , 10 ~4R' ~/FAN SHALE 11000' 14~3' HRZ ~ I ~ ~;~I':"33' KEMIK 120001 ......... F~'O-D"X'-TC--X-~-TD ~ I 12,5 Frog [STIM./Jl'F'Z) I '. ......................................... , LCU e ti738' '} TD 9 12000' SUSCRL1P 13000' BELOW LCU .......... .. .. ,, SHALE, THIN . SAN,.gS, COAL t i 14000' . ........................................................................................................ t ................... ]' ................................... JAN - 9 t992 ....................... 1 .................................................................................................................................................. an~horago issio M U D W T, ..................... P 1,7] R liT: ::' f:;: t'" S, - .............................. [:' I:~' A C, 6 f? A ]] ] ['"" N T PRESSURE CONTROL PROCEDURES The following are recommended to aid in prediction, detection, and control of abnormal pressure which may be encountered while drilling. A. General Safety Rules . Continuously monitor and plot all drilling parameters obtained from the mud logging unit to detect an increase or decrease in pore pressure. These parameters include, but are not limited to, mud weight in/out, mud temperature in/out, shale density, size/shape of cuttings, ROP, WOB, RPM, "D" exponent, lithology, background gas, trip gas and connection gas. The "D" exponent is to be kept current at all times to help detect any transition zones. Data gathering will commence below the 20" casing. . In areas of suspected abnormal pressure, cuttings recovery and analysis shall not be allowed to lag more than 30' behind total depth at the bit. 1 The Drilling Supervisor shall evaluate drilling parameters and hole conditions to determine appropriate mud properties and other appropriate procedures. ; . If the ROP increases steadily over a 30' suspected shale interval, following a marked or abrupt decrease in shale drilling rate, circulate bottoms up to allow analysis of the other parameters. If the increased ROP is occurring in shale, this shall be sufficient evidence to indicate possible overpressured formations and a logging run (lES, GR-Sonic and FDC) should be considered at that depth. . A written record of hole fill up shall be maintained during each trip out of the hole. These reports are to be submitted to the Drilling Supervisor with the routine mud log. . Below the 20" casing, the driller is to observe the well for flow at each connection, or at any time be deems necessary, until he is confident that the well is not flowing. . Do not drill more than 5' of a drilling break without checking for flow. If there is no flow, do not drill more than 10' of the drilling break without circulating bottoms up. (See Drill Break Procedure - Section B). RECEIVED JAN - 9 ~992 Alaska 0il & Gas Cons. CommiSSiOn Anchorage S. . . 10. 11. 12. 13. 14. 15. 16. FIo-show and pit level indicators are to be functioning properly at all times. This includes the alarm system which will be set in a 5-10 bbl position to allow prompt audio warning of an increase or reduction in flow. BOP's, choke and kill lines and choke manifold are to be tested weekly. These tests are to be recorded on the IADC report. The steward on duty will have a list of all the room assignments. The cook on duty will be alerted to be prepared to extinguish all galley fires and shut down the ventilating system. The full drilling crew will be on the floor or pipe racks with the exception of the derrickman, whose station is in the pump room. Each crewman will have his well control duties assigned prior to spudding the well. Smoking outside the quarters is strictly prohibited. The driller shall be prepared to shut down all unnecessary electric motors in the well area. An ample supply of barite should be maintained on location. The chain of command, in the event of a catastrophe, shall be prominently posted and well understood by all rig personnel and subcontractors on the rig. The drilling contractor shall assume the responsibility of enforcing this. 17. The active pit volume should be limited so that volume changes (increase or decrease) can be easily detected. 18. Mud volumes should not be transferred to or from the active system while drilling is actually in progress. If transfers or additions are necessary, the rig floor, mud logging unit, and company representative should be notified. Drill Break Procedure: Gas and Oil Sands When drilling a gas or oil sand in a known or suspected producing horizon, the following drilling break procedure will be followed' . Drill maximum of 5' into a drilling break, pick up kelly, turn off pumps and check for flow. The well should be observed for 5 - 10 minutes before drilling is resumed. R EC E IV E D JAN - 9 {992 Alaska 0il & (las Cons. CommissiOn Anchorage (" ( . 1 1 Drill another 5' (maximum of 10' gas formation) and, if there is still a high rate of penetration, pick up kelly, turn off pumps and check for flow. At this point, circulate bottoms up. Do not continue drilling. The mud weight should be adjusted if the background gas does not return to normal. Continue to circulate until mud weight out is the same as the mud weight in and the background gas has returned to normal. Continue through the break by drilling 5' and checking for flow, drilling an additional 5', again checking for flow, then circulating bottoms up. Once the rate of penetration has returned to normal, continue to drill as before the break. Each time a new sand and drilling break are encountered, follow the procedure as outlined. It is important to have sufficient mud weight to control the bottom hole pressure when drilling permeable sands. The days versus depth and mud weight versus depth plots should be removed from the well plan and posted in the company representative's office on the rig site. These plots need to be updated daily and discussed with the Drilling Superintendent, Drilling Engineer and mud loggers. These plots will also be posted in the Drilling Superintendent's office and updated each day. Review the offset mud logs from wells in the general area that are provided by the mud loggers. Most mud loggers have localized experience and can be a good source of valuable information. C. Kick Warninq Signals 1. Gain in pit volume. 2. Drilling rate change (drilling break). 3. Increase in return mud flow rate. 4. Hole takes less mud than calculated on trip. 5. Decrease in circulating pressure or increase in pump strokes. . . . Trip, connection, or background gas changes. Gas-cut mud (depending on severity). Water-cut mud or chloride increase. RECEIVED JAN - 9 t992 Alaska 0il & Gas Cons. uumraissto¢, Anchorage Do E. Note: These signs are not necessarily listed in order of importance. General Precautions While Drilling The following precautions should be adopted in addition to the "General Safety Rules". 1. Flow check before each connection. 2. The mud weight in and out will be checked and recorded every 15 minutes while drilling.' 3. A pitman will be assigned to the shaker and active pits at all times while drilling. 4. Each trip the mud volume required to fill the hole shall be recorded at least once every 5 stands. The volume of mud that was used to fill the hole on the trip shall be recorded on the Driller's log. 5. All welding and/or cutting should be closely supervised so as to minimize a fire hazard. Diverting Procedure 1. If any of the kick warning signs occur, pick up and clear the kelly. 2. Shut down mud pumps and check for flow. 3. ~:. open leeward diverter valve and close the diverter. (If the bi~is-~ff-'PIS°ttom, run back to bottom, well flow permitting.) 4. Notify Drilling Supervisor and Toolpusher immediately. 5. Begin pumping mud at maximum rate. start preparing barite plug. If all the mud is used prior to pumping the barite, switch the water. 6. If the barite slurry fails to stop the fl__~ow, continue to pump water at the maximum rate. 7. If gas broaches outside the conductor to the surface around the rig jeopardizing the safety of the personnel, the drill site should be evacuated. RECEIVED JAN - 9 t992 Alaska 0il & Gas Cons. C0mmiss%0n Anchorage ( F. Drilling 12-1/4" Hole The following procedures will be used if a kick is taken after 13-3/8" casing is set. Shutting In Procedure Note: A Hard shut-in method will be used. If it is established that the well is flowing, proceed as follows: Drilling 1. Stop rotary 2. Pick up kelly 3. Position tool joints clear of rams 4. Stop pump 5. Check for flow 6. Close the annular preventer. 7. Open both of the choke valves to a closed choke. 8. Read and record the stabilized drill pipe and casing pressures and estimate the pit volume gain. If pressures are in excess of 2,000 psi, the pipe rams should be used. 9. Complete the well control worksheet and circulate the kick out using the constant bottom hole pressure method. Tripping If the hole is not taking the correct volume of mud on a trip, the well should be immediately checked for flow. 1. If the well is not flowing, run the drill string back to bottom and circulate bottoms up. 2. If the well is flowing, install an open TIW valve and then the inside RE( EI'VED . Close annular blow out preventer. JAN - 9 1992 Alaska Oil & Gas Cons. CommissiOn ;Anchorage G. H. . . . . . Open both of the choke valves to a closed choke. Notify Company Representative and Toolpusher. Strip into hole to bottom - regulate mud returns through choke. Note that entire pipe displacement should be allowed since pipe is not filling while the inside BOP is installed. Once on bottom, record stabilized shut-in drill pipe pressure, casing pressure, and pit again. Proceed with kill procedure. Note: To take drill pipe shut-in pressure with the inside BOP in place, pump into the drill pipe at one or two pump strokes at a time until an increase in casing pressure is noted. The shut- in drill pipe pressure is then the reading on the drill pipe minus the increase in casing pressure observed. Stripping Procedure If the well .kicks when the drill string is not at total depth, the pipe will be stripped back to bottom before the well is killed. If the surface pressure is 2,000 psi or less, use the annular preventer for stripping. Strip ram to ram for surface pressures in excess of 2,000 psi. During stripping operations, the equivalent mud volumes of drill pipe stripped will be bled off. The initial closing line pressure will be 1,500 psi. However, to obtain maximum life from the packing element, the closing line pressure should be regulated to the minimum value to maintain a seal. After stripping operations have been conducted for a short time, the regulator setting can be adjusted for the. optimum closing pressure. The pipe should be run slowly. Some leakage past the tool joint can be allowed when the tool joint goes through the preventer. As the stripping operation continues, closing pressure can be regulated to a value that allows some leakage around the pipe. This volume must be included in the total bleed off volume for the appropriate size drill pipe being stripped in the hole. Well Control Responsibilities 1. Flow Check Driller: He will be entirely responsible for conducting a flow check, shutting the well in, and calling the Drilling Supervisor and Toolpusher. RECEIVED Alaska.Oil & Gas Cons. Anchora.qe Floorman: One man will keep a constant watch on the shale shaker area and inform the Driller of any of the signs necessitating a flow check. Sufficient floormen will be on the drill floor at all times while drilling to shut in the well. Mud Logging Personnel: They will be responsible for keeping a constant watch for any signs necessitating a flow check and keeping the Driller informed. Drilling Supervisor and Toolpusher: Notify the Drilling Superintendent giving details of the "kick" as soon as practicable. They will check all of the Driller's information and supervise the shutting in of the well, if it is necessary. 1 Circulating Out the Kick Toolpusher: Sound the general alarm (Gas Alert) Drilling Supervisor: He will assume total control of the operation to circulate out the kick. With the Driller at the rig controls and the Toolpusher on the choke manifold, he will proceed as follows: . Record drill pipe pressure. If there is a float in the drill string without an orifice, pump slowly down drill pipe until float opens. Record pressure. . Calculate mud weight required to kill well. (Use Well Killing Worksheet.) . Circulate out the "kick" using a constant pump rate (approximately 3 BPM) and the. constant bottom hole pressure method. The Drilling Supervisor will coordinate overall activity. Keep the Drilling Superintendent informed. The responsibilities of others will be: Derrickman: RECEIVED JAN - 9 ~)92 Alaska 0il & Gas Cons, C0mmissi0~ Anchorage f Start degasser and keep it operating. Ensure, with Mud Engineer, that mud mixing equipment is functioning properly. Mud Engineer: Supervise addition of weight material. Mud Loggers: Monitor pump strokes, pit level and hydrogen sulphide reading. Report to Drilling Supervisor. Shale Shaker Floorman: Measure the mud weight in and out and record it continually. Other Floormen: Stay on the drill floor. Roustabouts: Work with Mud Engineer. At the request of the Drilling Supervisor/Toolpusher: a. Unnecessary personnel will be removed from the location. b. Stewards will awaken all personnel, close all doors to quarters, and secure the galley fires and ventilation. C. All doors which are not actually in use will be closed and kept closed. d. Organize the off duty crew into fire fighting teams. Well Control Equipment . An upper and lower safety valve will be used in the drill string at all times. . A solid drill pipe float may be used in upper hole sections. In deeper hole sections, aported float will be used. . A safety valve (TIW valve) and an inside blowout preventer will be available in a convenient location on the rig floor. The valves and the necessary crossovers will be required to fit each size or type of tool joint in the hole. RECEIVED JAN - 9 t992 Alaska 0il & Gas Cons, Comm%ssT0~ Anchorage U. . ,. . Choke Manifold Status: a. The choke line should be open through the manifold up to the automatic choke which should be in the closed position. The line leaving the automatic choke should be open to either the gas buster or to the towline so that any flow will be visible. b. All other valves on the choke manifold should be in the closed position. Co The choke manifold should be flushed and left full of drill water when not in use. Blowout Preventers: a. The BOP stack choke and kill valves will be closed. bo Pipe rams should be actuated on a daily basis - complete closure is not required. c. Blind rams should be actuated on each trip out of the hole. d. Control stations should be actuated on each trip out of the hole on an alternating basis, only one actuation per day is required. e. Annular preventer should be actuated once a week in conjunction with pressure testing. Choke manifold valves, safety valves, etc. should be actuated once each week in conjunction with pressure testing. BOP Diverter System' a. Function test upon installation, pump through lines. b. Function test each week. Blow Out Prevention Drills The severity of any well kick can be minimized if well flow is detected early and handled properly. In order to do this, drilling crews must be exposed to "pre-kick" training in the form of pit drills and blowout preventer drills. RECEIVED JAN - 9 1991~ Alaska Oil & Gas Cons. CommiSsion Anchorage . Pit Drill This drill is intended to reduce the time required for the driller to detect well flow. IT WILL BE CONDUCTED DAILY PER TOUR DURING DRILLING OPERATIONS. Frequency of this drill should be reduced to twice a week after reaction time has been reduced to one minute. Drill should be noted on IADC report. The following procedure will be used: ae Without prior notice, gradually increase the apparent pit level by manually raising the mud pit level float. Timing starts at the beginning of this step. b. The driller is expected to notice pit gain and perform the following: (Timing stops at the end of step 2). . Pick up kelly above rotary table and tool joint clear of annular preventer. 2. Shut down mud pump. 3. Check well for flow in trip tank. . Report to Tooipusher the pit gain and subsequent flow check. . BOP Drill The frequency of this drill will be at least once weekly per crew but should be more frequent until practice has reduced reaction time to 5 minutes. (The BHA should be up in the casing for the test.) Drill should be noted on IADC report. The following procedure will be used: Pick up kelly and break circulation at shoe. Inform the driller that he has had a pit increase and commence timing of drill. a. Check of Well Flow 1. Stop Rotary R ' EIVED JAN - 9 t992 Alaska 0ii & Gas Cons. Commission ;Anchorage . Pull kelly up until bottom of tool joint below kelly safety valve is clear of the rotary and tool joints are clear of Rams. . Stop pumps. Check for well flow. alarm. "Well is flowing". Driller sound b. Shut Well In 1. Close the annular preventer. 2. Open both of the choke valves to a closed choke. e At this time you would read and record the stabilized drill pipe and casing pressures, estimate the pit volume gain, complete the well control worksheet, and circulate the kick out using the constant bottom hole pressure method. Note: 'Neither the annular preventer or the pipe rams should be closed on a tool joint. RECEIVED JAN - 9 t992 Alaska Oil & Gas Cons. Commission Anchora,gB~ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR .. ... 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 3, 1992 Rodney Smith Reg Supvr Field Oprns HMS Alaska OCS Region 949 E 36th Ay Rm 110 Anchorage, AK 99508-4302 Re: ARCO's Gull Island #3; Conoco's Badami #2 a,ld Northwest Hilne #1 -- exploratory wells Dear Mr Smith: This is in response to your letter dated December 30, 1991 in which you made inquiry regarding proposed bottom-hole locations for the subject wells. The attached published public notices for spacing exceptions for each of these wells contain the proposed bottom-hole locations. Upon completion of each well, the Commission will publish the actual surface and bottom-hole locations. Should you feel compelled to review data from any of these wells prior to the expiration of confidentiality, you must direct such a request to the well's operator. Please contact Robert Crandall of this office if you have any further questions regarding this matter. Sincerely, Russell A Douglass Commissioner RPC/jo attchments STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF CONOCO ) INC. for an order granting an ) exception to spacing requirements ) of Title 20 AAC 25.055 to provide ) for the drilling of the Badami ) No 2 exploratory well. ) Conservation Order No. 286 Conoco Inc. Badami No. 2 January 3, 1992 IT APPEARING THAT: 1, Conoco Inc. submitted an application dated December 11, 1991 requesting an exception to 20 AAC 25.055(a)(1) to allow drilling the Badami No. 2 exploratory well el. set than 500 feet to a drilling unit boundary. , Notice of hearing was published in the Anchorage Daily News and the Anchorage Times on December 17, 1991 pursuant to 20 ACC 25.540 and in the Alaska Administrative Journal December 23, 1991. 3. No protests to the application were received. FINDINGS: . The Conoco Badami No. 2 well as proposed will be a straight hole drilled from a surface location 2390 feet from the north line (FNL), 2500 feet from the west line (FWL.) of Section 30, T10N, R20E, Umiat Meridian. . Offset operator/owner Petrofina Delaware, Incorporated has been duly notified. . An exception to 20 AAC 25.055(a) (1) is necessary to allow drilling of the well. Conservation Ord~ No. 286 January 3, 1991 Page 2 CONCLUSION: Granting a spacing exception to allow drilling of the Conoco Badami No. 2 well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE IT IS ORDERED: Conoco Inc.'s application for an exception to 20 AAC 25.055 for the purpose of drilling the Badami No. 2 well is approved as proposed. DONE at Anchorage, Alaska and dated January 3, 1992. Al~~hnasierrmva~io n C o mmis sion Lokui~ fi. Smith, Alaska Oil and Gas Conservation Commission Alaska Oil and Gas Conservation Commission ( Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commi.~sion Re: The application of Conoco Inc. for exception to 20 AAC 25.055 to allow drilling the Northwest Milne No. 1 exploratory oil well. Conoco Inc. by letter dated December 11, 1991 has requested an exception to the provisions of 20 AAC 25.055. The exception would allow drilling the Northwest Milne No. 1 exploratory well from a surface location closer than 500 feet from the boundary of la drilling unit. The proposed location is 2299' from the north line (FNL) and 1042' from the east line (FEL) of section 23, T14N, RgE, Umiat Meridian. A person who may be harmed if the requested order is issued, may file a written protest prior to 4:00 pm January 2, 1992 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed, and raises a Substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am January 17, 1992 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279- 1433, after January 2, 1992. ' If no proper protest is filed, the Commission will consider the issuance of the order without a hearing. Russell A. Dougl~§s Commissioner Alaska Oil and Gas Conservation Commission Published December 17, 1991 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (9O7) 564-760O December 30, 1991 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Revised Surface Casing Design for the Conoco Badami No. 2 Well Dear Mr. Johnston: Conoco Inc. submits the following surface casing design revision to the Badami No. 2 request for permit to Drill: 0 to 4,300' (TVD) 4,300' to 5,300' (TVD)/5,730 (MD) Size: 13-3/8" Size: 13-3/.8" Weight: 61 ppf. Weight: 72 ppf Grade: K-55 Grade: L-80 Thrd: BT&C Thrd: BT&c This revision is submitted 'to.comply with the Commission's design criterion for collapse, as conveyed by telephone conversation with Mike Minder on 12/30/91, and' meets Conoco's understanding of the .required design parameters, of a safety factor of one, with fully.' gas evacuated casing and formation pore pressure. If you have further questions regarding this'well, please direct them to me at 564-7637. Very Truly Yours, Senior Drilling Engineer cc: SGB, JLA Badami No. 2 Well File File: 500.21.11 RSR RECEIVED DEC 1'1991 Alaska 011 & Gas Cons. Commissle~ Anchorage Conoco Inc. ,. Request for Facsimile Transmission RECEIVED OEC 2 o 1991 Alaska Umt & Gas Cons. Commission .... -..:-.--- :-..---=mi _...~ ....I~r'~ Room No. Neme l' ,of~ ..,, ,,-- I 1. Your ~iginel$ must have'good e,e~trast (dark detail on light 2. Legible, 3. ½-inch margi~ on alt sides of sheet. 4. Number tli ~ BO0/iOO'3DUd E~&g&E-~ O& 3DU~OHDNU ODONOD NO~ ~P:P! I6, OE ,CAS,lNG DESIGN ,( Grade: K-55 Burst: 2,11o psi Tan,~'ie: 1,480,~# RECEIVED DEC 2 u ~99! N~sl~ 0ii & Gas Cons. Commission Anchorage Note: 30' x 1/2' ~uml casing will be set at 141' RKB which is more than adequate to drill to 430' and set A. Burst Assume that shallow gas is encoc~ered and the well is being diverted when the diverter line plugs: Pb I (Pore Pressure x Depth x .052) - ( Gas Gradient x Depth) (8.6 ppg x 5,30(r x .052) - (. 115 x 5,300~ B. Pb = 1,761 psi The burst safety, factor is therefore: SF -- .2 1~.~10 / 1,761 = 1.20 . Assume fl3at the casing is completely evacuated with cement on the backside: Cmt. Wt. x Depth x .052 15.6 ppg x 430' x .052 P~= 34,9 i~i The coH~q:~se safety factor is therefore: G00/EO0'39~d ~W~&S&~-G 01 39~aOHDN~ ODONOD NOaJ GP:~T iG, OE D3¢ SI: = 52O/349= 1.~ The tensile str~ is more than adequate to run the required 430'. RECEIVED Size: 13-3/8" Weight: 61 Grade: K-55 Thread: BTC Burst: 3,090 psi Collapse: 1,540 psi DEC 2 o 1991 U~t & Gas Cons. Commission Anchorage The frecture gradient et 5,300' is estimated to be 14.5 ppg. Assume that while drilling below the 13-3/8' shoe with 9.2 ppg mud a kick is taken allowi~ 3,710' of the t3-3/8' .casing to be filed with a .115 psi/it kick gradient. The burst pressure would be as follows: (Frae. Grad. x Depth x .052) - (MW x Mud Column x .052) - (Kick rad. x Depth) (14.5 ppg x 5,300' x .052) - (9.2 x 1,590 x .052) - (.115 x 3,710') Pb = 2,809 psi The burst safety factor is therefore: SF = 3,090 / 2,809 = 140 B. Collapse Assume that lost returns are experienced while drilling below the 13- 3/8" casing which evacuates the surface casing to a depth of 3,444' TVD. The collapse pressure is calculated as follows: Pore Pressure x Depth x .052 G00/C00'~D~d E~g&S&~-G 01 ]D~OHDN~ ODONOD HO~ O~:Pi IG, 0~ DDt' C. Po = 8.6 ppg x 3,'!,~,~,' x .052 Po = 1,540 psi The oollapse safety factor is therefore: SF = 1,540 / 1,540 = 1.00 Tension RECEIVED OEC ?. o 1991 Gas Cons. Commission Anchorage Tensior~ = Casing Wt. x Setting Depth x ((65.4 - Mud Wt.) / 65.4) Tension = 61 #/ft x 5,730' x ((65.4 - 9.2) / 65.4) Tension = 300,360# The tension safety favor iS therefore: SF = 962,000 / 300,360 = 3.20 .9-5!8' .Prod...~U~. Casinq_ _Se~...~ 12,.43.0' R .KB/I..2.,O00° TVD. (PoSsible) Size: 9-5/8' weight: 47 #/ft Grade: N4~ Thread: BT&C Burst: 6,870 psi Colla~: 4,750 psi Tensile: 1,086,~ ~e that a tubing leak develops just below the tubing hanger which exerts shutqn tubing pressure on top of the packer fluid above the prod~mfion packer. The burst pressure is calculated as follows: Pb =' ((Porn Pres. x Depth x .052) - (Gas Grad. x Depth)) + (Packer Fluid Grad. x Packer Depth x .052) - ( Backup Grad. x Packer Depth x .052) g00/~00'~D~d E~&G~-G 0£ ]9UaOHDNU ODONOD NOa~ 0S:~! lB, 0~ Bi C. Pb = ((11.9 ppg x IO,O(X~ x .052) - (.115 x 10,000~) + (12.5 ppg x 9,265 x .052) - (9.0 PI~ x 9,265' x .052) Pb = 6,724 psi The burst safety factor is therefore: R E C E IV E D SF = 6,870 / 6,724 = 1.02 DEC 2 O 1991 ~ Al~sk~ Oil & Gas Cons. Commission Anchorage ~ that the well is on gas lift and the packer fluid has been displaced out of the annulus to the top of the packer and the gas lift pressure has been bled off of the casing. The collapse pressure is Po = (Pore Pres. x Depth x .052) - (Gas Lift Gas Grad. x Depth) SF -- 4,750 / 4,15t - 1.14 The tensile load is celcuiated as follows: Tension = Casing wt. x Setting Depth x ((65.4 - Mud Wt.) / 65.4) Tension = 47 ~/ft x 12,430' x ((65.4- 12.5) / 65.4) Tension = 472,549~ The tension safety factor is therefore: SF = 1,086,EXX) / 472,549 = 2.30 'G00/S00'~DUd ~GLg&~-G Ol BDU~OHDN~ O30NOD NO~ IS:P! lG, OE Conoco Inc. Suite 200 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 3201 C Street ;ENG ASST I Anchorage, AK 99503 ' ENG ASS~ [ .. '~_,~ + --~ GEOL ASS$~ .... "TAT TECHI i RE: Request for Wavier of 20 AAC 25.065, C, 1, 2, Requirements for Hydrogen Sulfide for the Badami No. 2 and Sequoia No. 1 Wells. Dear Mr. Johnston: Conoco Inc. requests wavier of the hydrogen sulfide requirements as outlined under State regulation 20 AAC 25.065, C, 1, 2, for the Badami No. 2 and Sequoia No. 1 wells to be drilled during the winter of 1992. Attachment 1 is a plat showing the proposed Badami No.2 well location in relationship to Badami No. 1 and the five other wells drilled in the Mikkelsen Bay area. All of these wells, except for the West Mikkelsen No. 2, penetrated the Lower Kekiktuk interval, which is the proposed T.D. formation for Badami No. 2. A review of well records indicated that only the West Mikkelsen No. 1 encountered H2S, while testing the Lisburne Formation. Table I (Attached) provides a detailed geologic correlation for these wells and shows that only the Mikkelsen No.1 and West Mikkelsen No. 1 actually penetrated the Lisburne formation, which is sour in the Prudhoe Bay Field. As previously stated, only the West Mikkelsen No. 1 encountered H2S. The bottom-hole location for the Badami No. 2 well is located approximately 3 miles from the erosional edge where the Lisburne Formation is completely truncated by the Lower Cretaceous Unconformity. Conoco's .subcrop map shows that the Badami No. 2 well will T.D. in the Lower Kekiktuk and the Lisburne formation will be totally eroded at that location; therefore, the chance of encountering sour gas is considered to be minimal. (See the attached IOC for a detailed geological description). Attachment 2 is a plat depicting the proposed Sequoia No. location in relationship to exploratory wells previously drilled in this area. A review of well records indicated these wells did not encounter hydrogen sulfide gas, nor did they penetrate known hydrogen sulfide productive zones. Table 2 (Attached) provides a detailed geologic correlation for these wells. RECEIVED DEC 1 6 1991 Alaska Oil & Gas Cons. Comm'tss%o~ ~.nchoraae Conoco, Inc. December 11, 1991 Page 2 In addition, Table 2 provides a geologic prognosis for Sequoia No. 1, indicating the well should not penetrate horizons deeper than those previously drilled by the offsetting wells. Therefore, the risk of encountering sour gas is considered to be minimal. MWD formation evaluation tools will be run in the bottom-hole assemblies while drilling these wells. In combination with mud logs, these tools will enable the on-site geologists to monitor stratigraphy as the wells are being drilled; thereby, minimizing the risk of unknowingly drilling into hydrogen sulfide bearing intervals, such as the Lisburne formation. As a precautionary measure on both Badami No. 2 and Sequoia No. 1, the mud logging company will install hydrogen sulfide detection monitoring equipment at the shale shaker, bell nipple and pump room. Additionally, Conoco will maintain six Scott Air Packs on location and will have all equipment as specified under 20 ACC 25.065, C, 2, on standby in Deadhorse. In the unlikely event that hydrogen sulfide is encountered in either of these wells, this equipment will be immediately mobilized to location. If you have further questions regarding this request for wavier, please direct them to Steve Rossberg at 564-7637. Very Truly Yours, David L. Bowler Division Manager cc: SGB, AEH, JLA, RSR, JRH, SJL, Badami No. 2 & Sequoia Well Files File: 500.21.11 RSR RECEIVED DEO 1 6 1991 Alaska 0il & Gas Cons. Commission Anchorage .~TOOLIK #2 ARCO 8700' ,~,~ TOOUK #1 ~ 10,B14' 1::) CONOCO i i i ., / / ARCO PIPEUNE ~ . Ii ii i ~.1~ i I I II I 10,460;' 1, 111 I..3MILES I im ... iiiii IIII . ,. IIII OEOHAZARD STUDY SEQUOIA PROSPECT NORTH SLOPE ,AK. ...--~., ,, l, ,,, III Ilmllll I RECEIVEI) DEC 1 6 1991 Alaska Oil & Gas Cons. l~omm'~ss~o" Anchorage T TABLE OFFSET,-WELL DATA- SEQUOIA PROSPECT OCNOCO SEQUOIA 1 LITHOLOGIC UNIT (PROGNOSIS) Base of permafrost 1 550 Paleocene Staines(SOS equiv) 4035 Cretaceous Canning Hue Shale GRZ/Pebble Shale Upper Kupsruk LCU/Lower Kuparuk Jurassic Kingak TD 5135 8178 8368 8545 8635 8900 9050 'rOOLIK 2 1440 3203 4012 7360 75.69 7848 7858 8072 8700 PIPELINE-ST 1250 ? 6212 9870 10084 vy limited deep logging suite 1O460 AR(X) TOOLIK 1 not logged 4532(?) 6360 8990 9140 9312 ? 9688 10814 DEC 13 '$1 I~:~5 FROM OFFSHORE-RLRSKR-aRER (" iii i il iii Interoffice Communication Jim Hand Jennifer K. Donuan Friday, D~c~mbm' 13, 1~1 Requ~t f~ Waiver (H2S)- Con~ Badami ~1 PaGE. 0B2 e second ~ph. of the lena- needs m be ch~ and possibly added, to. I will uxicrlinc parp..that. I have ch_~g~. The West Mi~ #1 well report mentioned that the), had to shu~ in wmi outing one or the DS'I's in the Lisburn~ b~ausc of '~ish 1-12S". Also, no Lwr Kek was cncoun~ in the West Mikk#2, only bascracnt was below the LCU. Aliachment I ~tP_,lat ~owi~.. thc pmposedBadami No. 2 well locmion in rclalionship to Badami No, 1 m nye omer wells drilled in the Mikkelsen Bay area. All of tbes~ wells, exCePt ~ ~c W~ lV[ikke. 1sen No. ~ penetraued the Lower Kcldkmk interval, which is the No.2. p,.ml~l, T~.. formation for Badami A review of well xcconts indicated ~ west Milckel~n #1 encoun __e~edH~,_q_._while testina the l-!sburne F__om~sfi_'nq._ Table 2 (AUached) pmiddes a detailed geologic corrcla~n- for ~ wells and ~ws that only thc Mikkeben No. 1 and West Mikkelsen No. 1 actually ~cuatcd thc Lisbume Formation, which is sour in the Pru~ Bay Field. As ~usly~die,se wells did not encounter hydrogen sulfide gas. The boumu hole location for the Conoco Badami ~2 well is lccat~d ahuost :3 miles from the sionni~edgc of where the Lisbm'ne Formation is completely mmcate~ by the Lower s Unconf, ~ity (LCd. Thc well-established northwest-southeast rods and the position of thc .Imncalions ofleach of thc f~malions is confiml~ I:~' t~ off~t w~ll data. As mcnfion~ above, dtc Mobil Mik~lsen # 1 and thc Arco WestMiki~sen' # 1 wells cncounmed the Lisburne Formation just below thc LCU. Moving to the northeast and perpendicular to the trend of the subc~ps, thc next thnm: wells in the area am the Shell West Mikkclsen 4~6 and and the Conoco Badami #1. These wells encountered.the Upper Kekilm~ below thc LCU, beyond the erosional odgo o[ the Lisburne and Kayak Shale. The Badami ~2 location is on trend with. the.Humble East Mikkelsen #1 well which encountmed the Lower Kekiktuk below the LCU and no Li~bume was present. Our subcrop map shows that the Badami #2 well will TI) in th~ Lower I~~ ~s wen, and the LisSurne Formation will be Ix~ally eroded at that loC' ation; ther~ore, the chance of encounming sour gas is considered to be minimal RECEIVED DEC 1 6 199~ Alaska Oil & 6as Cons. (~ommission Anchorage 12/13/91 11:39 AM page 1 *~ TOTRL PRGE.00~ ** · , , II I I '"" I II III I / ~ ........ : ........... i'1 , ,,_1 _ / ~ W. MIKKEL . ..... .......... . ..... . ~ ~'~ . i ......... ~ ~ , ~~~ - -. / , ~ ' MIKKE LSEN 1 - "B" LOCATION ~ i - ~ ,.~ .............. , BADAMi ~2 ~ LOCATION OF VELOCITY ANALYSIS U~ F -!-I- 1~[ ...........~-- NORTH SLOPE, ALASKA · ..., CONOCO ACREAGE A~lSka 0il &as Cons. C~mmission ALASKA la. Type of work Drill Re-Entry 2. Name of Operator Conoco Inc. STATE OF ALASKA AND GAS CONSERVATION COl~' ~ISSION PERMIT TO DRILL 20 AAC 25.005 Redrill -_-I lb. Type of well. Exploratory ~ Stratigraphic Test .~ Development Oil '~ DeepenEI Service _-_ 3. Address 99503 3201 C SI:., Suite 200, Anchorage, Alaska 4. Location of well at surface · 2700' F~.., 700' lq~, SEC 30, TION, R20E At top of productive interval 2390' fitS, 2500' lq~-L, SEC 30, TIOlq, I~0E At total depth 2390' :EEL, 2500' :FI, IL, SEC 30, TION, R20E 12. Distance to nearest 13. Distance to nearest well property line 700 feet 10,560 feet 16. To be completed for deviated wells Developement Gas ~ Single Zone ~ Multiple Zone [] 10. Field and Pool 5. Datum Elevation (DF or KB) [B 38' AY~. feet 6. Property Designation AnL-367006 7. Unit or property Name Badami 8. Well number 2 Approximate spud date 2'ebruary 1, 1992 14. Number of acres in propert' 5035 acres Bad-mi Prospect Kickoff depth 500 feet 18. Casing program size Specifications Hole Casing Coupling 30" I~lelded 26" 20" BT&C Maximum hole angle 33 0 11. Type Bond (see 20 AAC 25.025) Number 8086-15-54 Amount $200,000 15. Proposed depth (MD and TVD) 12,430' l~D/12,000'TVD feet 17. Anticipated pressure (see 20 AAC 25.035 6386 ~sio Quantity of cement (include stage data) r~ frost"C'~ st"C" st"E" )S~R Per~ frost'G" BT&C Maximum surface 2580 psig At total del)th (TVD) Setting Depth Top Bottom TVD 141' 12~;" 9 5/8" BT&C 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet 12,000'- Effective depth: measured feet Junk (measured) ,,,.,,,., true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth RECEIVED DEC - 6 1991 Oil & I~as Cons. u0mmis$i0n .Anohoraga True Vertical depth 20. Attachments Filing fee 1[] Property plat ~ BOP Sketch [Z Diverter Sketch ~ Drilling program Drilling fluid program I~ Time vs depth plot :~3 Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby c~,il~at the fo~,,~n(,/is' true and correct to the best of my knowledge Signed~/' c.~,.~ ~ ~ Title Sr. Drilling Engineer Commission Use Only Permit Na'mber APl number ] Approval date _ ?- aaa o Conditions of approval Samples requ~red.~J*'Yes [] No Mud log required ~'Yes [] No Hydrogen sulfide measures [] Yes ~"No Directional survey required ,,~¥es [] No Required work~su 9 f~OP,~:,,,C2M; [] 3M; ~ 5M; [] 10M; [] 15M Other: ~-",,, ~ ..... by order of Form 10-401 Rev. 12-1-85 '~' \' - Datel2/3/91 See cover letter for other requirements Submit in triplicate TOWNSHIP 10 NORTH RANGE 19 EAST i RANGE 20 EAST I s=¢ 19 r ~ BADAMI ~2 SEC 30 . i SEC : :' , . RECEIV NOTES: ~. ~IS O~ LO~ON IS ~0~ PRO~DED ~ ~ONO00. ~. E~A~ONS ~VE Y~ TO BE Al~sk~ Oil & E~ABUSHED. Anchomg~ L~ .~1. PROmAC~ ~C~ ~ TI~, R2~ UMIAT M~IDIAN, ~KA F. ROBERT BE~ A ASSOC. ,, ,, ~P' ~ANT ~ ~C ~ ~R L~ ~.,.*~ ' CONOCO I Sg2116~.74 N I NA 7~1'31.2~" NA 27~'~L j ~.28 E 14710'19.0S~" 7~ BADAMI ~2 PROPOSED WELL LOCA~ON ~2/~/91 ~DU ., 1-=2~' 1~ R~. NO. DA~: RE~$ DRA~ ~E~; gong B~I2 1 ~ 1 , A.S.P. PLANT GEOOETIC CELLAR LOCATION IN COORDINATES ZONE 3 CI:X~DINATES POSITION BOX ELEV. SEC'lION 5921164..74 N NA 70'11'31.2,58" NA 2700'FNL 354540.98 E 14710'1g.054." 700'FI&L WELL PLAN - CONOCO BADAMI F2 HOOD WI: .66667 FllqA ~ 33333 IX)CATION: ti: .~3333 (up m 1st $750.000 DE{C) CIz .66667 SL 9_700' FNL, 700' FWL ~c 30. T10N-R20E Fl'VD = 1200(7 CI: .66667(~(t=l~7f~3.000DHC) C~ 33333 *BELL 2390'FIqL, 2500'FWLSe~:30. TION-R/0E FrD=12,468' I D~PTIq PORMATION I/TH HOI~ CASING MWD saoav~K ~ I ~"~ a~' (1~8-1~8) , ' E~ ~ -~50' (5918) 7~ ~I~ ~I~) ~ ~ -11~ (11713) I ~ ~ -I17~ (12168) ~ s~c~oes~mw ~ DEC- 6 199[ Ano{ [orago 'BOTTOM IIOLE LOCATION MOVED TO Si> 505. L~IE 7-AK-91 RE'v'ISED 11/6191 JENNIFER IX)N.~A_N ")-LTGH PJ::..SOLLFFION DIPMETER THROUG}q CAN,~ING FM. *"*DP..Pt~'DLNG ON THE LOC, G~G CO.: 66 CORiLS V, TIt-I SCHLUMt~ERGER. 50 CORES WI-DJ.' ATLAS, t. IAI.L!}3URTON ': ** ~ 'i~)SSIBLE BOREHOLE IMAGI.t','G 'l'~Di.../,(.;ROSS PAY D','I]Y. RVAI. ONT, Y FORMATION EVALUATION A. Logging Hole Size Interval 17-1/2" TD to 20" shoe 12-1/4" TD to 13-3/8" shoe Note: MWD tools with gamma ray and resistivity will be run from the to TD. ..Logs GR, SP, DIL, FDC, CNL GR, Long Spaced Sonic GR, SP, Phasor Induction, Micro Resistivity, LDT (Pe Curve), CNL GR, Long Spaced Sonic (Array if pay) GR, High Resolution Stratigraphic Dipmeter GR, Borehole Imaging Tool (Optional over 1000' interval) GR, Formation Tester GR, SWC Check Shot Survey (VSP if pay) 13-3/8" casing shoe RECEIVED Alaska Oil & Gas Cons. C0mmJssJ0n Anchora~o (' 48" HOLE (30" CASING) The 48" hole will be drilled with a big hole drilling rig prior to mobilizing the drilling rig. This big hole rig will drill a 48" hole to 100' below the mud line and run 30" casing. The casing will be plain end and will be welded while running. The top of the 30" should be approximately 3' above the top of the ice pad. The 30" will be cemented by pumping cement in the 48"x 30" annulus from the surface as per the cementing program. Cement should also be allowed to fill one foot in the bottom of the cellar. Once the drilling rig has been mobilized, a bell nipple will be constructed out of excess 30" casing to be left at location. RECEIVED DEC - 6 1991 Alaska Oil & ~as Cons. L;ommissio,n AncbQ .raDs. 26" HOLE (20" CASING) i . . . . SI . . . Fabricate bell nipple from excess 30" casing and weld onto 30" casing stub. Drill a 26" hole to +/- 430' RKB utilizing BHA #1. Circulate hole clean and spot hi-vis pill in open hole. Check the samples at TD to make sure that the bottom of the hole is not in a sand. POOH. Rig up and run 20" casing. Ensure that the 20" BTC by 4" Weco circulating swedge is on the rig floor with the valve open prior to running the casing. Run stab-in float shoe (will be shipped to rig already welded onto a joint of 20" casing). Check circulation .through the float shoe prior to running in the hole. Depth +/- 430' Grade K-55 Weight 94 Ib/ft Thread Buttress Collapse 520 psi Burst 2,110 psi Tensile 1,480,000 lbs. Run centralizers as follows: One 10' above the float shoe, one just below the float collar, one every 4 joints to surface (across the collars). A rigid centralizer should be run just below the surface to insure that the 20" casing is properly centralized after Cementing. Remember, however, that when the well is abandoned, the casing must be recovered to 15' below the mud line. Therefore, place the upper most centralizer accordingly. Fill casing every joint while running. Land the 20" casing just off of bottom. Run 5" inner string with sealing adapter and centralizer inside of the 20" casing and stab into float shoe. Establish circulation slowly. Circulate one open hole volume of mud. Do not exceed annular velocity that was used to drill the interval. Rig up to cement. Pressure test lines and pump to 3,000 psi. Cement as per cementing program. When cement is seen at surface, quit pumping and leave the drill pipe volume of cement on top of the float collar. RECEIVED DEC - 6 1991 Alaska. 0il & Gas Cons. {J0rnmissien Anch0rag~. 10. 11. 12. POOH laying down inner string of 5" to prevent cement plugging of MWD, jets, etc. after drilling continues. Run 1" string down 30"x 20" annulus and wash out cement to +/- 30' below the mud line. After washing out the cement, displace annulus with 10.8 ppg CaCI2 with a freeze point of-570 F. This will help during the abandonment process by allowing the 20" to be cut and pulled independently of the 30". Cut the 30" and 20" casing at the desired heights keeping in mind the subsequent casing strings and heads. Weld on the 21-1/4", 2,000# slip-on casing head to the top of the 20" casing. Test head to 70 % of the 20" collapse (364 psi). RECEIVED DEC - 6 199] ,Oi~ & 6as Cons. Commission '' ~h.qr..age~ · . 17-1/2" HOLE (13-3/8" CASING) . . . . 1 . . . . Nipple up and function test 20" diverter system. Install wear bushing. Drill a 17-1/2" hole to 500' utilizing BHA #2. Prior to drilling below the 20" shoe, circulate through the diverter system. Kick off the well at 500' in a N80.23°E direction building 2°/100' to 32.830 at 2,142' RKB / 2,053' TVD. Maintain hole angle and direction to a depth of 3,541' RKB / 3,229' TVD and then drop angle at 1.5°/100' to vertical at 5,730' RKB / 5,300' TVD. Pump hi-vis gel sweeps as needed to insure proper hole cleaning. Take MWD surveys at least every 100' starting at 500' (or shallower) until TD of the surface hole at +/- 5,300' TVD. Circulate hole clean. Check samples at TD to make sure that the bottom of the hole is not in a sand. If the bottom of the hole is in or near a sand, the hole should be deepened so that the shoe will be a minimum of 50' below any sand. Short trip and condition mud. Strap out of hole. Run open hole logs as specified in the logging program. A geologist will supervise the logging operations. Make a conditioning trip. POOH. 'Retrieve wear bushing. Rig up and run 13-3/8" casing. Ensure that the 13-3/8" BTC by 4" Weco circulating swedge is on the rig floor with the valve open prior to running the casing. Run float equipment one joint apart making sure to thread lock each end of the float equipment. Check circulation through both the float collar and shoe prior to running in the hole. Depth +/- 5,730' RKB / 5,300' TVD Grade K-55 ,~ Z.-8o Weight 61 Ib/ft Thread Buttress Collapse 1,540 psi Burst 3,090 psi Tensile 962,000 lbs RECEIVED Run centralizers as follows: One 10' above the float shoe, one just below the float collar, one every joint for the next 6 joints (across the collars), one 50' above the 20" casing shoe, one at +/- 300', and one at +/- 180'. A 10. 11. 12. 13. 14. 15. 15. 16. rigid centralizer should be run just below the surface to insure that the 13- 3/8" casing is properly centralized after cementing. Again, this centralizer must be positioned to allow for abandonment 15' below the mud line. Fill casing at least every 5 joints while running. Land the 13-3/8" casing just off of bottom. Establish circulation slowly, reciprocating pipe while circulating. Circulate and lower mud rheologies to help insure better cement placement. Rig up to cement. Pressure test lines and pump to 3,000 psi. Release bottom wiper plug and cement as per cementing program. Release top plug and displace cement with mud. Bump plug with 1,000 psi over final circulating pressure. Reciprocate pipe while cementing if possible. After bumping plug, bleed off pressure and insure that floats are holding. If floats are not holding, maintain pressure on casing for 4 to 6 hours or until the pressure can be bled off. Run 1" string down 20"x 13-3/8" annulus and wash out cement to +/- 30' below the mud line. Displace annulus with 10.8 ppg CaCI2 with a freeze point of -57o F after washing out cement. This will help when abandoning the well by allowing the 13-3/8" casing to be cut and pulled separately. Nipple down the diverter and set 13-3/8" slips in 20" casing head as per Wellhead Section. Cut 13-3/8" casing and install 13-5/8", 5000 psi slip-on casing head as per Wellhead Section. Test head to 70% of the 13-3/8" collapse (1,078 psi). Nipple up and test BOP's and related equipment. RECEIVED DEC - 6 1991 Alaska 0fl & ~as cons. [~ommissi0[t 12-1/4" HOLE . . . . . Install wear bushing. Pick up BHA No. 3. Run in hole and clean out 13-3/8" casing to the top of the float collar. Pressure test the casing to 1,500 psi. Pressure up on the casing at a rate of 1/4 barrel per minute and plot pressure versus volume on a graph. Pressure must be held. for 30 minutes. By government standards, the pressure test is acceptable if the pressure drop is 10% or less in 30 minutes. However, if any leakoff is detected, contact the Drilling Superintendent in Anchorage before proceeding. The pressure test must be recorded on a chart recorder and the chart given to the Conoco Drilling Foreman. The casing test must also be recorded on the IADC report. Drill cement, float equipment, and 10' of new formation. Circulate a minimum of bottoms up and until the mud weight is consistent from surface to TD. Perform leakoff test as follows: k. Close BOP around drill pipe and pump down drill pipe at 1/4 barrel per minute. Be Plot pressure versus volume pumped each 1/4 barrel on the same plot as the casing test. C. At the point where the pressure departs from the straight line, stop pumping. Hold the pressure for 10 minutes plotting the pressure each minute. Bleed off the pressure and record the volume of fluid returned. If no leakoff in pressure is observed after reaching 1.0 ppg EMW over the minimum acceptable I~koff, contact the Drilling Superintendent to see if an actual leakoff pressure is necessary. At the end of the test if no leakoff was observed, be sure and state that it was a "jug test" on the reports. Note: All casing and leakoff tests should be performed with a cement pump. The minimum acceptable leakoff is 13.5 ppg. MALO = MW at TD + Kick Tol. + Trip Margin MALO - 12.8 + 0.5 + 0.2 RECEIVED ~,0.jJ.& 6as Cons. . . . 10. 11. 12. MALO = 13.5 ppg Note: The calculated leakoff is 14.5 ppg. Drill ahead to TD at +/- 12,000' TVD taking MWD surveys at a minimum of every 100'. Hi-vis sweeps should be pumped as needed to help insure proper hole cleaning. As seen in the Badami #1 well and the other offsets, abnormal pressure can be expected in the Canning Fan Complex. In the Badami #1, the pore pressure was measured during the DST and found to be 11.9 ppg. The top of the Canning in this well is estimated to be at 9,718' RKB / 9,288' TVD. When the offset wells drilled into this abnormal pressure, a marked increase in gas was noticed. Once the gas was encountered, the mud had to be weighted up 2 to 3 ppg in just a short interval as seen on the mud weight plots in the Offset Wells section. Therefore, the Pressure Control Procedures should be followed closely prior to drilling into this interval. Key interest should be placed on gas, cuttings size and shape, and chloride content. Be prepared to take conventional cores in the target intervals. After reaching TD, circulate bottoms up and short trip to the casing shoe. If no fill or problems are encountered on the short trip, strap out of hole for logging. Log well as per logging program. After evaluating the logs, a decision will be made to abandon the well or run 9-5/8" casing and test the well. If casing is not run, the following procedures will not apply and the well should be abandoned as per AOGCC regulations. If the decision is made to run 9-5/8" casing, a conditioning trip will be made and the wear bushing will be retrieved. A set of 9-5/8" rams will also be installed above the blind rams and the bonnet seals tested to 3,000 psi. Rig up and run 9-5/8" casing. Ensure that the 9-5/8" BTC by 4" Weco circulating swedge is on the rig floor with the valve open prior to running casing. Run float equipment two joints apart making sure to thread lock each end of the float equipment as well as the connection in between. Automatic fill float equipment should be run on this casing string. Check circulation through both the float collar and shoe prior to running in the hole. Depth +/- 12,430' Grade N-80 Weight 47 Ib/ft Thread Buttress RECEIVED DEC - 6 1991 .Oil & Gas Cons. L;0mmissi0n · , , 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. Collapse 4,750 psi Burst 6,870 psi Tensile 1,086,000 Run centralizers as follows: One 10' above the float shoe and one on the next collar. One 10' below the float collar and one across each collar until 500' above the top of the highest producing zone. Depending on how high up from bottom the highest productive zone is located, a stage cementing collar may have to be run. Fill casing at least every 5 joints while running. Land the 9-5/8" casing just off of bottom. Establish circulation slowly, reciprocating pipe while circulating. Circulate and lower mud rheologies to help insure better cement placement. Rig up to cement. Pressure test lines and pump to 5,000 psi. Release bottom wiper plug and cement as per cementing program. Release top plug and displace cement with mud. Bump plug with 1,500 psi over final circulating pressure. Reciprocate casing while cementing if possible. After bumping plug, bleed off pressure and insure that the floats are holding. If floats are not holding, maintain pressure on casing for 4 to 6 hours or until pressure can be bled off. Nipple down BOP's and install 9-5/8" casing slips as per Wellhead Section. Cut 9-5/8" casing and install 13-5/8" 5M x 11" 5M tubing spool as per Wellhead Section. Test tubing spool to 70% of the 9-5/8" collapse pressure (3,325 psi). Nipple up BOP's. Change out casing rams and test BOP's. Clean out and test well as per Testing Procedure which will be constructed after evaluating the logs. Abandon the well as per AOGCC regulations. RECEIVED DEC - 6 ~0jl & 6as Cons. t;0mmission SL: a700' FNL, 700' FWL SEC. 30, TiON, R20E BHL: ~P390' FNL, ~P500' FWL SEC. 30, TION, RaOE PTVD: laO00' RKB/MSL'. 35' WATER DEPTH - 3' PTD: 1 430' FORM, ID A Y S CASING LITH. o_ v (TVD) ~n,, PFIINTS v 10 20 30 40 50 60 SAGAVANIRK- \30' AT t41' TOK ~ ])RILL A 26° HOLEEO° AT 141' SHAL~ SAND, AT 30' 20' AT GRAVEL AND 1000" 430' COAL ]~ASE OF PERNAFROST : 1535'-1935' 2000' 3000' ,.A 17-1/2' HOI E SAN]), SHALE, iSILTSTDNE 4000' 5000' s488, EOCENE' . iSAND, SHALE, 13-3/8' AT 5730' RKt~ 5300' TVD 'SILTSTONE 6000' '~ 13-3/8' AT 5,730' RRB 14.5 PPG 6748' STAINES FG (EST.) 'fiiNOUE 7000' (PALEOCENE) SAND AND !SILTSTBNE 8000' 9000' ~ DRILL A 12- 1/4° HOLE 10000' SHALE 11000' % I 11483' HRZ r~ SAND : LCU @ 11738' ~ 9-5/8' AT TD @ 12000' -- I ~'~ 12,430' RK.B SUBCROP 13000' , LOG BELOW LCU I -- r SANDS, COAL , .' ~] ~[~ ~4ooo' . ....... j. .. _ J ..... ~ .................................. ! ................................ CEMENTING PROGRAM 30" CASING The 30" casing will be cemented to surface by placing a chicksan line into the annulus. The slurry volume will be calculated on 100% excess. Slurry properties are as follows: Cement Type: Slurry Density: Slurry Yield: Water Required: Thickening Time: Compressive Strength: @ 20°F BHST Permafrost "C" Cement 15.6 ppg. 0.94 cu ft/sx 3.75 gal/sx 2:30 Hr:min @ 40°F BHCT 24 hrs. = 1,000 psi 7 Days = 1,550 psi A lab test will be run prior to the cement job. 20" CASING The 20" casing will be also be cemented with Permafrost "C" cement as shown above. A +/- 30 bbl. fresh water spacer should be pumped ahead of the cement slurry. A stab-in float shoe will be run and cement will be mixed and pumped until cement returns are seen at surface. The cement remaining inside the drill pipe should be left on top of the float shoe. 13-3/8" CASING The 13-3/8" casing will be cemented utilizing a permafrost lead slurry and a premium cement tail slurry. The cement volume will be calculated on open hole volume plus 20%. The tail slurry should cover the bottom 500' of open hole. A +/- 40 bbl. water spacer should be pumped ahead of the lead cement slurry. The slurry properties are as follows: Lead Cement Type: Slurry Density: Slurry Yield: Water Required: Thickening Time: Compressive Strength: @ 105°F BHST Permafrost "E" Cement 12.1 ppg 2.05 cu ft/sx 11.0 gal/sx 6:00+ Hr:Min @ 75°F BHCT 24 hrs. = 25 psi 7 Days = 100 psi RECEIVED .Oil & Gas Cons. C0mmissie.n Tail Cement Type: Slurry Density: Slurry Yield: Water Required: Thickening Time: Compressive Strength: @ 115°F BHST Premium Cement 15.8 ppg 1.15 cu ft/sx 5.0 gal/sx 3:30 Hr:Min @ 75°F BHCT 12 hrs. = 800 psi 24 hrs. = 2,200 psi A lab test will be run prior to the cement job. An extra 100 sxs. of the tail slurry should be on location to perform a top job if necessary. A total of 5 #/sx of gilsonite should be added to the lead slurry to help prevent lost circulation. 9-5/8" CASING The 9-5/8" cement volumes and types will be determined at the time the decision is made to run pipe. The cement volumes will be based on the open hole caliper log plus 20% excess. R'£CEIVED Oil a Was Cons. U0rnmissi01t Anchorage BOP TEST PROCEDURES The following test procedures shall be conducted at the time of nipple up, configuration change and on a weekly basis. All BOP tests shall be recorded on the IADC report. 13-3/8" CASING . Upon nipple up, all rams (including the blind rams), kelly valves, emergency valves, choke and kill lines and valves, and the choke manifold must be tested to a Iow pressure of 250 psi and a high pressure of 5,000 psi. The annular preventer shall be tested to a Iow pressure of 250 psi and a high pressure of 3,000 psi. . After nipple up, all pipe rams, kelly valves, emergency valves, choke and kill lines and valves, and the choke manifold must be tested to a Iow pressure of 250 psi and a high pressure of 5,000 psi on an interval not to exceed 7 days. The blind rams will also be tested to a Iow pressure of 250 psi and a high pressure of 5,000 psi by backing off of the test plug on an interval not to exceed 7 days. The annular preventer shall be tested to a Iow pressure of 250 psi and a high pressure of 3,000 psi on an interval not to exceed 7 days. 1 All pipe rams and the annular preventer are to be function tested daily. . Blind rams shall be function tested on each trip out of the hole not to exceed once per day. Note: If 9-5/8" casing is run, the above listed test procedures will be followed. RECEIVED D[C - 6 J99! Alaska Oil & (~as Cons. Commission Anchorage SURVEY REQUIREMENTS An MWD survey will be taken no deeper than 500'. Thereafter, MWD surveys will be taken at least every 100', or more frequently for directional control, until the surface hole has been drilled to +/- 5,730' RKB / 5,300' TVD. While drilling the 12-1/4" hole section, MWD surveys will be taken at least every 100' or more frequently if deemed necessary to control hole angle. At TD, a composite of all MWD surveys shall be submitted as the final well survey. All surveys will be corrected to the Section Grid System using a total correction of 28.294o East. / ECEIVED DEC - 6 199! Alaska 0il & Gas Cons. CommissiOn Anchorage slot. ~2 ~I~ SLOPE~J.~K~ PROPOSXL LISTING Your ref: S TYPE Our ref: propll Other ref: Date printed: 29-0ct-91 Date created: 29-0ct-91 Last revised: 29-0ct-91 Field is centred on 0.000,0.000,0.00000,+ Structure is centred on o.000,0.000,0.00oo0,~ ~I~...~..OJJ .& Gas Cor~s. Commission CONOCO INC. Badami 2,slot ~2 Badami,NORTH SLOPE,ALASKA Measured Inclin. Azimuth PROPOSAL LISTING Page 1 Your ret: S TYPE Last revised: 29-0ct-91 TrueVezt. RECTANGULA Depth COORDINATE 0.00 0.00 80.23 0.00 0.00 N 0.00 E 0.00 0.00 500.{)0 0.0{3 80.23 500.00 0.00 }{ 0.00 E 0.00 0.00 600.{)0 2.00 80.23 599.98 0.30 N 1.72 E 2.{30 1.74 700.00 4.00 80.23 699.84 1.18 N 6.88 E 2.00 6.98 8{)0.00 6.00 80.23 799.45 2.66 N 15.46 E 2.00 15.69 900.00 8.00 80.23 898.70 4.73 1{ 27.48 E 2.00 27.88 1000.00 10.00 80.23 997.46 7.39 N 42.89 E 2.00 43.52 1100.00 12.00 80.23 1095.62 10.62 }4 61.69 E 2.00 62.60 1200.{)0 14.00 80.23 1193.{)6 14.44 N 83.86 E 2.00 85.10 1300.{)0 16.00 80.23 1289.64 18.84 N 109.37 E 2.00 110.98 1400.00 18.00 80.23 1385.27 23.80 N 138.18 E 2.00 140.21 1500.00 20.00 80.23 1479.82 29.32 N 170.26 E 2.{)0 172.77 1600.00 22.{)0 80.23 1573.17 35.40 N ~.~ E 2.00 208.60 1700.00 24.00 80.23 1665.21 42.04 N 244.08 E 2.00 247.67 1800.00 26.00 80.23 1755.84 49.21 N 285.73 E 2.00 289.93 19{)0.00 28.00 80.23 1844.94 56.91 N 330.46 IE 2.{)0 335.33 2000.00 30.00 80.23 1932.39 65.14 N 378.24 E 2.00 383.81 2100.00 32.00 80.23 2018.11 73.88 N 428.99 E 2.00 435.31 2141.69 32.83 80.23 2053.30 77.68 N 451.02 E 2.00 457.66 2500.{)0 32.83 80.23 2354.37 110.65 N 642.48 E 0.00 651.94 3000.00 32.83 80.23 2774.49 156.66 N 909.65 E 0.00 923.04 3500.00 32.83 80.23 3194.61 202.67 N 1176.82 E 0.00 1194.14 3540.84 32.83 80.23 3228.93 2{)6.43 J 1198.64 E 0.00 1216.28 3629.76 31.50 80.23 3304.20 214.47 N 1245.29 E 1.50 1263.63 3729.76 30.00 80.23 3390.14 223.14 }{ 1295.68 E 1.50 1314.75 3829.76 28.50 80.23 3477.39 231.44 N 1343.83 E 1.50 1363.61 3929.76 27.00 80.23 3565.88 239.34 !{ 1389.72 E 1.50 1410.17 4029.76 25.50 80.23 3655.57 246.85 N 1433.30 E 1.50 1454.40 4129.76 24.00 80.23 3746.38 253.95 N 1474.56 E 1.50 1496.27 4229.76 22.50 80.23 3838.26 260.65 N 1513.46 E 1.50 1535.74 4329.76 21.00 80.23 3931.14 266.94 N 1549.98 E 1.50 1572.80 4429.76 19.50 80.23 4024.95 272.81 N 1584.08 E 1.50 1607.41 4529.76 18.00 80.23 4119.64 278.27 N 1615.76 E 1.50 1639.55 4629.76 16.50 80.23 4215.14 283.30 N 1644.98 E 1.50 1669.20 4729.76 15.00 80.23 4311.38 287.91N 1671.73 B 1.50 1696.34 4829.76 13.50 80.23 4408.30 292.09 N 1695.99 E 1.50 1720.96 4929.76 12.00 80.23 4505.84 295.83 N 1717.74 E 1.50 1743.03 5029.76 10.50 80.23 4603.91, 299.14 N 1736.97 E 1.50 1762.54 5129.76 9.00 80.23 4702.46 302.02 N 1753.66 E 1.50 1779.47 5229.76 7.50 80.23 4801.43 304.45 N 1767.80 E 1.50 1793.82 5329.76 6.00 80.23 4900.73 306.45'N 1779.38 E 1.50 5429.76 4.50 80.23 5000.31 308.00 N 1788.40 E 1.50 5529.76 3.00 80.23 5100.09 309.11N 1794.84 E 1.50 5629.76 1.50 80.23 5200.01 309.78 N 1798.71E 1,50 5729.76 0.00 80.23 5300.00 310.00 N 1800.00 E 1.50 6000.00 0.00 80.23 5570.24 310.00 N 1800.00 E 0.00 6500.00 0.00 80.23 6070.24 3i0.00 H 1800.00 7000.00 0.00 80.23 6570.24 310.00 N 1800.00 E 0.00 7500.00 0.00 80.23 7070.24 310.00 ~ 1,800.00 E 0.00 8000,00 0.00 80.23 7570.24 310.00 N 1800,00 E 0.00 8500.00 0.00 80.23 8070.24 310.00 H 1800.00 E 0.00 9000.00 0.00 80.23 8570.24 310.00 N 1800.00 E 0.00 9500.00 0.00 80.23 9070.24 310.00 N 1800.00 H 0.00 All data is in feet unless otherwise stated Coordinates are from structure centre and TVI)s are from rkb. Vertical section is from wellhead on azimuth 80.23 degrees. Caloulation uses the minimu~ curvature method. 1805.57 1814.72 1821.26 1825.19 1826.50 Canning Turbidite 1826.50 1826.50 1826.50 1826.50 1826.50 1826.50 1826.50 1826.50 RECEIVED DEC - 6 1991 Alaska Oil & Gas Cons. COlZllllJssJJJlt Anchorage Imda~i 2,slot t2 Badami,~RTH Heasured Inclin. Azimd~ True Vert. Depth Degrees m~rees Depth 10000.00 0.00 80.23 9570.24 IOSO0.O0 0.00 80.23 10070.24 11000.00 0.00 80.23 10570.24 11500.00 0.00 80.23 11070.24 12000.00 0.00 80.23 11570.24 12429.76 0.00 80.23 12000.00 PROPOSAL LISTING Page 2 Your ref: S TYPE Last revised: 29-C~3t-91 REC?ANGULAR~I~ Vert COORDI1{~TES Ft Sect 310.001{ I800.OOE 0.00 1826.50 3lO.OON 1800.OOE 0.00 1826.50 310.001{ 1800.00E 0.00 1826.50 310.00 I{ 1800.00 E 0.00 1826.50 310.00 I 1800.00 E 0.00 1826.50 310.00 N 1800.00 Z 0.00 1826.50 All data is in feet unless otherwise stated Coordinates are from structure centre and T%U3s are from rkb. Vertical section is from wellhead on azimuth 80.23 degrees. Calculation uses the minimum curvature method. RECEIVED Alaska Oil & 6as Cons. Anchorage ~NOCO INC. PROPOSAL LISTING Page 3 Badami 2,slot ~2 Your ref: S TYPE Badami,NOR~H S~PE,~ ~t rev~: 29~-9I ~~ in well~ ~ ~ R~~ CoorS. ~nt 57~.76 53~.~ 310.~ N 18~.~ E ~9 ~bi~te ~i~ ~itio~ in s~ing 'l' ~p ~ ~op ~ Re~ar C~. ~t ~ ~t ~ R~~ CoorS. ~i~ 0.~ 0.~ O.~N O.~E 135.~ 135,~ O.~N O.~E S~face 0.~ 0.~ O.~N O.~E 4~.~ 430.~ 0.~ O.~E ~" ~g 0.~ 0.~ 0.0~ O.~E 572}.76 53~.~ 310.~N 18~,~E 13 3/8 ~ ~tat~ Wi~ ~s ~11~ Y~t ~ P~ition ~,V.D. ~1 ~~ar ~r~. ~te rev~ ~i~ ~iditi not s~ifi~ ~3~.~ 310.~N 18~.~E 29~-91 All data is in feet unless otherwise stated Coordinates are from structure centre and TVDs are from rkb. Vertical section is from wellhead on azimuth 80.23 degrees. Calculation uses the mi. ni~u~ curvature method. RECEIVED Alaska O~l & ~as COns. C6NOCO ! Strucfure · Radorni 2 Field · Badarni Locofion · NORTH SLOPE,ALASKAJ t~oo 2500 I- a st -- 200 300 400 i ~ i i ~ I SURFACE LOCATION''} 2700' FNL - 700' PaLt SEC.50,T10N,R20E I ~"'" BUILD RA~ 2 DEO/100' GENT ~G~ 32,83 DEC ~OP O~ RATE 1.5 OEO/100' I I VE. RTICAL SECTION 1826.50' ALONG 80.23 DI[G AZIMUTH WELL PROFILE DATA TARGET LOCATION 2,:190' ra~. - 2500' $1rC.S0,T 10N,R20E I I I / / / / --(~/ / / / / / / ~ .--., 3' TO FLARE ITEM 'Il 12 DE~RCRIPTION ,4 H;..IO Q~O N~I ~41'E VALVE - McF..VO¥ 2H~ ,, - ,, ~&.IOOCZ) it.el AD.tU~TAIbL£ CHo~.E- NILLIE. -~14~.IOQ::O APl I~,EMOTE OPE[ 414~.loog:oJt/=l LE~/::) FILLE. D TAIZG~ET ~LIIJD 5He,.IO,w'w APl ' · · - - 414a, 1~4Y~, ~t414~A. Ht,, .< ~,V~ /0000 APl ~T/JDOF. D 4Y~a, ~ ~I4&~'414~'4Ka, /0000 APl ~TUDD~O 41,~ D~g::~ APl FLeD DRILL FLOOR 4' TO MUD/GAS SEPARATOR 4' RECYCLE FLOWLIqE CLEANER .... ~?~?__~ ~ 1[ CHOKE MANIFOLD ARRANGEMENT ....................... I~"~";~; ~"'"'"' I~""" / ..... WELL SITE SHALLOW HAZARDS EVALUATION "B" LOCATION - BADAMI #2 Surface Location: 2700' FNL, 700' FWL of Sec. 30, T10N-R20E Bottom Hole Location: 2390' FNL, 2500' FWL of Sec. 30, T10N-R20E North Slope Borough, Alaska This analysis attaches to the Application for Permit to Drill the Conoco Badami #2 well. CDP seismic data (migration) was examined by Jennifer Donnan, Staff Geologist, and Tony Bazile, Analyst. Included with this report are a location plat (Attachment A), a window from one seismic section (Attachment B), a velocity analysis from CDP seismic data (Attachment C), and plots of sonic logs, mud gas and mud weight versus depth from offsetting well data (Attachments D and E). CDP SEISMIC ANALYSIS Of the three CDP seismic lines which were reviewed, one line, GP83-22, shows an anomaly at approximately -1000' (.016 sec, Attachment B). The anomaly is recognized by a strong amplitude, but there is no associated phase change, flat spot or velocity pulldown. The anomaly may be indicating shallow gas. It may also indicate a lithology change, or be an artifact of the processing. VELOCITY ANALYSIS Displayed on Attachment C are five plots of interval transit time versus depth as derived from stacking velocities taken from five different shot points from three different CDP seismic lines. The velocity analyses indicate that a possible slower velocity zone is present throughout the area from approximately -2100' to -7000'. This zone is bracketed by a high velocity permafrost layer above and a faster velocity Paleocene sand section below. No problems with overpressure are noted through this interval in the offset well data. OFFSET WELL DATA The proposed location of the Badami #2 well in relation to the offsetting well data is illustrated on the location map (Attachment A). Offset well data indicate that the base of permafrost may occur between -1400' to -1900'. All mud logs studied showed no shallow intervals of overly gaseous sediments. The slow velocity zone that was present on the interval transit time plots from -2100' to -7000' relates to a regularly-pressured sand-shale interval. This breakover point from slower to faster sediments most likely relates to the age of the section and possibly to a lithology change from dominantly shale to a sand-rich interval at approximately -7000'. Offset data indicate that overpressure may be encountered at -9700' (Attachments D and E). Interval transit time plots do not indicate that overpressured sediments will be encountered any shallower than what is predicted from offset well data. RECEIVED DeC 6 .Oil & ~,as Cons. commission ~ I 6 I 6 ,. ..... ,'_~ .............. / : W. MIKKEL : ~ W. MIKKI~LSE" 1 ' / ~ ~ ~ ,, ~ BADAMI1 o .~ ~ k E. MIKK ~LSEN 1 "B" LOC~TIO~ - ~~, ...... _ ...... -- BADAMI"-~Z x LOCA~ON OF VELOC~ ANALYS~S ~ NORTH SLOPE, ALASKA I I I I A ~A CHMENT '~" I I I HUM. E. M IKKELSEN #1 MUD WT. TO DEPTH R~TIO DEPTH O- -- m -2,000 ................... -4,000 -6.000 - -8,000 - -10,000 - -12,000 - -14,000 - -16,000 9 10 11 12 13 14 MUD WT. (LBS. PER GAL.) --"'- Series 1 A/a$/~a.Oil & Gas Cons. Commission ( MOBIL MIKKELSEN #1 MUD WT. TO DEPTH RATIO DEPTH -2,000 .............. -4,000 - -6,000 - -8,000 - -10,000 - -12,000 - -14,000 - · · · · · · · · · · · . · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · --1 6,000 .............. · · · i 8 9 · · · · · · · · · · · .~ . · · · · · · · I 'I I 10 11 12 13 MUD WT. (LBS. PER GAl...) --IS-- Series 1 R£CEIVED Alas!ce.Oil & Gas Cons..Commissien '~c~o~ ' .. ARCO W. MIKK. ~2 IS. MUD WT. TO DEPTH RATIO OI -2,000 - -4,000 - -6.000 - -8,000 - -10.000 - -12,000 - -14,000 DEPTH 8 8.5 9 9.5 10 10.5 11 11.5 MUD WT. (LBS. PER GAL) Series I 12 RECEIVED DEC - 6 ~,991 Alaska Oil & Gas Cons. Commission Anchorage ARCO W. M IKKELSEN #1 MUD WT. TO DEPTH RATIO DEPTH · · · · · · · · · · · · -2,000 ' ' -4,000 ...................... > .................. . ............... 6,000 ' ~,000 ~10,000 ................ ~. ..... , ...... ' ' · ..... -12.000 .............. , .................. , .............. 14.000 :---------------------------' -1. 8.000 -~ ~.ooo ' i ' 8 9 10 11 12 MUD WT. (LBS. PER OAt..) 0 Serles 1 R'£'C£1VED '~nchorage SHELL MIKKELSEN ~4 MUD WT. TO DEPTH RATIO -2,000 -4,000 -6,000 -8,000 - -10,000 - -12,000 - -14,000 DEPTH 8 9 10 11 12 MUD I/¥T. (LBS. PER GAl.) --3K-- Serles 1 ATTACHMENT "E" CONOCO BADAMI #1 MUD WT. TO DEPTH RATIO -1500' -3000' -4500' -6000' -7500' -9000' -10,500' -12,000' -13,500' 9.0 9.5 10.0 10.5 11.0 11.5 12.0 12.5 MUD WT. (LBS. PER GAL.) RECEIVED DEC - 8 1991 Alaska Oil & ~as (;o~,,s. Commission ~nchom~8. LINE: GP-83-22 MIG. RAM ATTACHMENT "B" BADAMI #2 (B LOCATION). ONE MILE 0 SURFACE LOCATION 900' S.E. OF LINE ~o ~"zo ~ ..... ~o ~ ....... ~'~-~ ~"~o'~ ~o~' I. . I I I !' Il: II I I I I I. I I I I I I I II I I I "'":'": ' ' i"! -'-: L,'.-"": !'".' ":::, i. . ...' - i. ! '"-": '"'i :'",' ,. ' ° ° ' ' · ..:,.'- :.-b ,~Jt* . ~.. ....... .'?'."~', ...... '"' ,~:',,, ........ ,='~: ........ ,¥.:!i::::i~::::;;,;,, ~- - :-~ ................. ;~ .... :--' ~ -- :::_: ................. :,:,,,,,!,..'?,~"".' %~ .. : .... : ..... ,~ ;.. . : .om.,.,..,...: ..... -...,, . ,-,6 .,~ : -'.~m~Nlm~~ .... : ........ :,,'' .... ~:. ,." - :'" . ' ~ ',llPp,O ' """¥ ~.., '~. · ' ';": ~"'" ......... ~- ' ': ......... :' .... ~': ................ ~ ' ', . ~- -'"' .......... -" .... ': .................. ~ .......... :: . 4, ' ''~- .......... · ''~- ..... :', ' ~ ';" ~"'~ '"-"' '" '"~ :., ...,,;. ~ ; ,.. : _11,, ...- .. ,! : : : : . , .,i i , --,llf!' -'* · ,,i ': ! , iG ii Ii · ~6 i . ;'' '-- ~ ,' ~ : .. o - : : : , : '- .... ~'"' .-* : : "" :' i., o ' - , -';",": ': ~1!- . ~ ..... :'. :~ '"~. : . , .-:,, ,..: "~ . : . : : ..... : ,,, .. ,.- ; ,: : = ...... .~. ,,, ,~j ,. .,: . . . .,..::. ',.,, .' ;. . .,: : .... .,; ':.: .: : : ;. : : ; .,, .= .-:.,~ :, .. -: ,,, . . : ; : : : : ~ .... .: . .: : .. ~ : ,.. : ..... ,.,~...,,,, ,,.,.. ;'. ...... ,,,,...: . . .: · ' ~.,,,, .... -' - . - * .... · ............... * ..... t .... · .... ~..,:~ ,,,~ .... :.. ... : .... . : · : ': ..' : ",' ....... : ..... : ; - :. : ............ · . . · .-. ...... o . ,,,.~ . ,,, . - .... i! · ,. ..,.,.,.. ,, ,~ ,, ,!. · :,-, ... :_-.., . :.. ,..,,,: . .; - . :.. .~ . : .: ...... ~, ........ · . ';":;-;-:;'.--~,-,;),,. "':' '"' ..,' :'" '..,,,,1. """-~' .... -. : :'., ........*.,,,: .... r "~ '. ---, ;... '"" ..... : ......... .~-. . I,Illllllllll i i ~ IIIIIlQIII ii : ...... : : : t'"!'"t;,,,,,,,,~',,/ .. : ................ ~ ,,,, , '"'""? .............. .: '"? , ....: -: ' .:- : .... - ~ ... ' .: ....... ~- ; ' " ·: '. .," ":' : ,,,, .... , : . .:.' : . -.,...,,,:..... . :,~.,..~.~__ . .... .- ................ ~ · .,,,..-. ........- ....... _ ..... : .. : ....... .._ . .: · :,,,,,,, ..- .,,,... ... . . . ? .IIIIQiiii))ill' . . IlIll II III Iii,.,..-" ifil IJl.. "" .... ' .... ' .... ' '" ' '- I * - ~ .... ~ .... .~ . .,,,,~, ' ' ' ' ? ' .......... ' ...... ,,,, ,)1 ............ )1 ii! - · J"'",;'.,),),,;~':'"; ' .,; ~, "-: .... '-. .......... :' ..... :- .......... ~- ........ ; :i ......... ::~,,,;.. ' .... : ...... .~: ...... ~ , ,,.,;;, ' .:" -' .'": ...., ." - ", 'u ,'." : ~ , ,; .... , .... ., -JJ .:_ i 'l.iTr,- , ."' *,_ : ' ' : : .: ....· .~ ~'~"I~S~))))jj))j)~I,i,))j '"'"~"'~ '"' '"" : ....... ~ '~ IB~l,,.. .: ,~. , ~'C_ I t~ ~ ": ~ '~': ...... ~,~,,,, '-'. '~'"~"~,,,,,,,,.,,~.__...,.. ~ ........ .=.. : ..... :... : ............. o ..........: : -: :- '.. : -: · :- .~ , ' ~ '". i -' ii~,i,,," ~ ...... ~::...,~.,~-,,,.,,,,,,,),)~ _ i . .-.:~: .,: -' ..... ,,,,, : : ... "'"-~. .................. ~!,, ....... ,,,,,,,~ ......... ...... "' ~ ~ ' ' = i : : ...... '~...,,,,,, ,,, iii i i iJj ~ - iJjjj))jjjj))jjjjjjjll~- JJJ#~J)J~ - ' ........ iiiiii- . *. · .~.,, 0.5 1.0 LINE: GP-83-22 ATTACHMENT "B" MIG. RAM BADAMI #2 (B LOCATION). ONE MILE ~ SURFACE LOCATION 900' S.E. OF LINE ~o ~o"'~.o ....fro° ..... ZPoO-~o z~o .... r~o~O '~0 "~' ~0 [ ~ ~ , .~ ....... 2~0 2~ 2~ 2~ 2~ 2~ ~.-,-~..... l.. ! ~ ~1 ! I ! I I, I I I I I I I III I I I -= ,, ,.:.' .... ..... ..' .: ..... ..................... - . ;.'" '.,:'~.;. ~. ~, ",..'":'.'"~:- · .. ..,' :".:'":". ~:::: :::~i; ::'~ ......... ':~ "~' ","~'-- . ....~ , ~ ~ ~ . , ............... . ........ ............. - .... ,, ; . ~,.-- - .-- · ........ - ~ ~h~. ~ -'~'J~~ ~ ~ ;-' ....." : ,. . '~,,,,,,~,l, ll ".-~, - ~ - a, .- ~ .. ~ le;&"~' .' ~ ~ .~ "~)~ . - ~. · ~' - '. ' :' · ',, '-' ; '.'.,,~ ' ' .... = ........... '"'""'"'",, ",, = - ' - "~" .,' ,,,,; .. -: ....= --~~i.'; .... ' ~ " """ ' "?~ ' ;~', .... ."~ '"~;~:' ~,.':~/',~ .,;,~ ~. ", ~ i; .~' '" '." ' ~ ' ~i~l' *" ' ' ' ~" .... ' ' ' I ' · ----" '' "' '""''~' ~ ' '~ .u. . . . . . ~ ?','.~ -~:.T~.~,;,,,:,, ~,~ . . ~... .-. ?. .~ ......-., ...... .~ - . ..,,~.,,,,, ............ ~ ..... . .... ~. · .... ,,,,,,~ ................. ~ ............. ~ ....... - ~,,~ .,.., ,.. ,;,,..,.. ,,,:,,;.,, .. ,,,..~ ,..,,,,. ........ } .. , ....... ~,.,;~,,, ,,,,~ ~ ~ ;'-.--.--- 6 .. v ........ :-,,,, ; ' ; ............ : a ............... v .......: ........ , ...... ,,,,, ~ . .. ' . -... ':.' .... ,.,.~ ,,,~,, .-. -~ ,.- : .... ~:.., ......... :. ~ . . 'lllllll. : * '" . . : . * - . . si :· .1111. ~ .. . i .... djlj I . Il -- i, IoilII II U ~ . . ' iii I ii l) j I* ' -- I Ii "i " I ' ' ~:..':. · .: ,.;.,~,.., -~.... ~ ,., ~ , - .... . ....... ~ ................. .... : .... ~.. , ~ ~ : : . ~,,,,,, . ~ ...... ,,.' {. ,~ ,-., -: .... .... .,,, . ""'"' ~ .: A ~ , ....: . ;-. . :,.. ?,, : .......... ; ...... .: : .,.. .... :.. ....... ? .... . .... , ...... __,,,- ~ ~ ........ ...~,,.. · ~ -:,,~ · ~ ~- - ~ ...... : .... : .......... ~ - ~ ~ ..... :.. ........ ,,,,: . -. .: ,,. : ....;:. :.~,,:~'" . :.~..~ ; '=, . ..~ ' ,: * - . ..~ ~ : - - : I "~ 2 ~ - ~' · ' ~. I illll I . '' · II -- ' , . ,-., .Il . . .l~ ~7~ :,,~=',,.". '..:.. ' "' i ;, ; i - ~ - ~ : T , '" : , . '.: .. ;~ .... ~ ,;. ".' ~ ..,.. T."-'.""',~ . ,' {', ..... ,,'" ; : '~ ' · ' : - "-' '~ : ' ; : - : ; '"'"'"" : ; : : : ""'"'""~ ............ '"'"Y'"" "~:~'Qil ~ ' ' ~ ~ ' ' ~' ~' -~ J ~ '-:"~ ' ~ ' · ' . · '..'-'L ~ , : * - : . : : : -,-, ,l,....,, ~ . [ : :. : . - . i , ~,: ,, . .,~, , , t - , .~ ,.. ,, ... llill)ll,i I ~' ' H~IIiI'''"I' : j IJ'llJiilllO'llllJllll'' : "; : : . : ". ..- : '" - ; .,,Jl1' ~ ~ ,. I.;l ~ , .i .,. : ,11 ~ .- .... ...:~,::',,~ ......... :~:. : ,,~ .........,,,,: .... ~' : . ; .......... ~ ...... ; ;. : ..... ; ....... ~ . . ~,,., ; -; - , ; .. ; ' ,,=..,. .... ..2 . .~ .. : · ' ;'m)~)),~ : : ~",,,,,,0, .,,,,,, ~ ....... : . : ............ . . . · · , ,: , ~. ,, ~ ,, . . .... · ...... ~ ... i?~ .... ~_.. : ~ : ' '- ~ ~ ' ;' ""'"'"'-;,,h.. · _ - ' :" ...... ',-,,-G ...., ...... ; ........ · ~ ......... : ............: ....... ; ; ' ~ ~ ' . ': '" .... :.. .,l~ .: , . ,. ' , · I1~ ,. : ... ) : ~J)lli ' _ : "~'", J i : - -.~1 i i:,lll .11 . . i ~)lJJlI i i: ~1 I~Jll, . 4, i ' ~, ii- , ii ; ;' ' 2 iii. , : :: ..... . -i~l · .. ..... ~.. i : ~ --- . . - ...... _ - llllllQh. . IIJIIJllllll.~lllI )~ - * . : : ~ I . : -" · 'tlllll'~' '.. ': ' ' : '"'~ *~'"~ ......... q)l)l -:--. --Ih.t.,-rtl ' ' ' I'l*J*ll;;~;iL-~;;:~;;;llllllllll~ll~ *1 piih.: i I I1~, ;' · II ..~.~ liJlt,, * ) ~1 & I ~ *~lll ~,,,.;; ~-. ~= ....... ,, . = "" ,.c - = ~ ' ' : : .-= " · ': ?~,,).,.,~,). , '"?"~ '"'"'"' : ......... Y" ".,,- ,.'. c. · , ,, ~. '~ , ; ;~. ": - -- I~I i ; '..i.I. . : .: : . ~ ..... - lilllllJ III)ID)))i)ii .. , Ill .... Illi II' ' - I II1"" ~ A ................ :., ..... ,..,,-. ...... ............ ................ .......... .,,,,,;.,: ;,..,,,.,,,,__..- .... I'llllllJ~ I Illll "~ DJ ' : Illlh I' 'J. ; ~ I' III1' ~ Illill IlJlllll liB) : i ; : ' : ~ : JI I ' ' ; iilB,;~...,,~ : I.- : · ' ~- ~ I'"'ll IIIIlOIlilllllll'lll' : : '"; ....... IIIhoilil I": : : ; ] ~ h, h,~ 'llliil~ill)il;I Ttj ~. .. !~,,J~,, ..... ~::.. '":,, ..... .; . i , -'~ '. .... ' - : '"~ ...... , : ~ .. ' '"'"; .... ,, ~ '--m). ~, ,. ,.. ; ' I~ . = '" '~ , C ' : '. ~ ~ " )lllll)li ·, , ~ .... ',,~ ~"~Hilll~._.. ~ .... ~ - .. ' lit ' - t.h .., . ..... . .~ ,.,,.....~ ,. . . . , · : , ,.., :. . .... ~' : .... Z'. .... ' ~ :',' " ~~,,~ ' ~ ~ ' ~' :-_ - - = '~ .................. ~,,'"' = ............... ~' ..... = ' ·" -; ,;~,,,,,,,, · :,~ ' ~ ' .... ;' ~ ' ''':' "- ~ ~,.~'~h~~..~ .' ...... .,~,,,.,,,~,,~.. ~ ~ '~ - '''~ ..... ::.....;...~,;, . : -..- ..~ ........ · · ~ ................ ~,~, ............... ~ ~ . ,' ~ · . ~ ': .... ;. . -, .... '~ ' ,' '" ~ ",,~', . ," .; ' ' '' ' "' ........... - ...... ~ ....... '" ""~:" ~ ~ ' .... /'"'""' .... ' ..... ' ' '-: "' ~ . ~' : : ..,~_~_~h,.~, : SL'. 8700' FNL, 700' FWL SEC. 30, TiON, R80E BHL, 8390' FNL, 8500' FWL SEC. 30, TION, RSOE PTVD'. iPO00' RKB/NSL: 35' WATER BEPTH - 3' PT]}: 1P..,430' FDRN. ~ ~- ~ L B / G A L CASING LITH. o_ > POINTS (TVD) ~ v 9 10 11 1P 13 14 15 16 , 13~ AT 141' SAGAVANIRK- TOK SHALE, SAND, ~, 20' AT iGRAVEL AND 1000" ~ 430' 'COAL BASE DF PERMAFROST lS3S'-193s' 2000' I ' ! 3000' , SAND, SHALE, I SILTSTONE m 4000' ! I , :5000, ' I 5488' EOCENE j ~13-3/8' 5,300' TV9 ,SAND,s~LTSToNESHALE, [ 14.5 PPG 6000' FG (EST.> 6748' STAINE~ TONGUE 7000' (PALEOCENE) SAND AND SILTSTONE 8000' 9000, .... PR :SSURE EXP ~CTED 10000': , PRI:SSURE VAS H.9 PPG I,. I SHALE 1100 O' ' I H483' HRZ SHALE i , I i s-s/s- AT 11633' KEMIK 12000 ~ I 12.5 PPG ESTIM/TED i ~!~000' TV~ LCU ~ 11738' t T D ~ 12000' SUSCROP 13000 , ~ j BELOW LCU , - -~ ~ ~ m V ~ ~ ! SHALE, THIN '. SANDS, COAL 14000, ~IIDEC - 6 19~1_. ', j I Alaska 0il & ~s ~ons. ~ ~,,.nission j I I ch°rage MUD WT. PI]RE PRES. FRAC. GRADIENT " ,, . (-.f. DRILLING FLUID PROGRAM The following drilling fluids program should be used as a guideline for the type of mud to be used to drill each interval as well as the basic mud products which will be required. The actual mud weights and rheologies should be adjusted as dictated by hole conditions. Interval: 0 - 5,300' TVD Hole Size: 26" and 17-1/2" Mud Type: Gel/Extended Bentonite Recommended Mud Properties Mud Weight: Funnel Viscosity: 8.6 - 9.2 ppg Initial 250 - 300 sec/qt Final 70 - 80 sec/qt Remarks Treat out the excess calcium in the make-up water with soda ash to a level of less than 100 ppm. Use high yield bentonite and extender to make a gel slurry having an initial viscosity in the 250-300 sec/qt range to provide adequate hole cleaning through the initial gravel sections. Use caustic soda to adjust the pH to the 9.0 - 10.0 range for maximum yield of the bentonite. concentrations are recommended for this interval: Bentonite: 20 - 25 ppb Extender: .1 ppb Soda Ash: .15 - .25 ppb Caustic Soda: .25 ppb The following product RECEIVED Alaska 0~1 & (~as Cons, C0m~liss~it Anchorag~ Maintain the viscosity at the initial level through the heavy gravel zones and possibly to the base of the permafrost formations depending on actual hole cleaning requirements. As siltier and sandier clay bearing formations are encountered, viscosities may be allowed to gradually reduce based on observation of the cuttings at the shale shakers. It is recommended to not allow the viscosity to fall below 70 sec/qt through the course of drilling this interval as the higher rheology does provide some protection from the spalling tendency of the unconsolidated gravels in the shallower formations. Maximum utilization of the rig's solids control equipment is recommended throughout this hole interval to keep the sand content below 1% by volume and to keep the fluid density as Iow as possible by discarding drilled solids which will accumulate in the mud due to the high penetration rates. Normal pressures are expected throughout this interval and no shallow gas is anticipated. When drilling through the sands in the lower section of the 17-1/2" hole, the APl filtrate should be maintained between the 8 and 12 cc/30 min. range with PAC polymers. This should help prevent excess wall cake build-up. Prior to running 13-3/8" casing, a hi-vis sweep should be pumped and a short trip made. A hi-vis pill should then be spotted in the open hole prior to pulling out of the hole to run casing. Before cementing, the hole should be circulated clean and the mud rheologies lowered to insure better cement placement. Interval: 5,300' - 12,000' TVD Hole Size: 12-1/4" Mud Type: PHPA Polymer Recommended Mud Properties Density: 9.0- 12.5 ppg Viscosity: 35 - 50 sec/qt Plastic Vis:10- 25 Yield Point:8-15 AP! FL: 10 - 4 % Solids: 4 -6 % LGS pH: 8.5 - 9.5 Remarks RECEIVtID DEC - 6 199,1 Alaska. 0ii & Gas Cons. Comlll~.~l, ft~i An, oho,rage. Thoroughly clean the mixing pits including all solids control equipment and associated lines. Fill the pits with an appropriate amount of fresh water to provide a comfortable initial circulating volume based upon hole volume and pit system. Treat the make-up water with soda ash to remove excess calcium and mud up the Iow solids polymer system to the following formulation: Bentonite: 7.5 ppb PHPA Polymer: .50 ppb PAC-L: .25 ppb KOH: .25 ppb The important properties for the initial drilling in this interval are a pH in the 8.5 - 9.0 range, a yield point in the 8 - 10 cp range, and an APl filtrate in the 8 - 10 cc/30 min range. The initial viscosity should be +/- 35 sec/qt or as dictated by hole conditions. To avoid excessive cement contamination of the new mud while drilling out of the 13-3/8" casing and obtaining a leakoff test, the suction pit should be kept full of the spud mud and this mud should be used for ddll out purposes. This can be accomplished by isolating all of the other pits and taking returns directly into the suction pit. Once the drill out is completed and a successful leakoff test has been obtained, this spud mud can be dumped and the new polymer mud system can then be used. The viscosity of the mud can be maintained through the use of bentonite and/or PAC polymers. These additions should be based on actual hole cleaning requirements. Generally, viscosities in the 35 - 45 sec/qt range with yield point values in the 8 - 12 cp range should be adequate for drilling this interval. As the mud system stabilizes, the PHPA polymer concentration should be gradually increased on an as needed basis to .50 - 1.0 ppb for wellbore stabilization. Solids control should be maximized throughout this interval so that Iow gravity solids can be kept below 6 %. The ability to maintain a Iow solids drilling fluid throughout this interval will have a significant impact on the success of the polymer drilling fluid. Treatment with PAC polymers should be used throughout this section of the hole to control the APl filtrate in the 8 - 10 cc range initially and gradually lowered to the 4 - 6 cc range by the time the Canning Turbidite formations are reached at +/- 9,288' TVD. These reduced filtrate values can be achieved with .5 - .75 ppb of PAC polymer and 1.0 - 3.0 ppb of polyanionic lignin. Excessive rheologies can be controlled with additions of a polymer deflocculant and Desco-CF. The bentonite concentration should be maintained at a minimum of 4 - 8 ppb throughout this interval. Prehydration of the bentonite will be necessary to achieve proper yield of the clay. Maintaining these concentrations of bentonite in the mud will help insure good wallcake integrity as well as aid in filtrate control efforts. The pH level in the system should be maintained between 9.0 - 9.5 with additions of potassium hydroxide. The potassium ion will also provide additional formation and cuttings inhibition. At no time should the pH be allowed to reach a level of 10.5 or greater as degradation of the polymers and dispersion of formation solids will occur. The mud weight should be increased as dictated by hole conditions. Barite will be used to achieve the desired density and when added, thinner additions will also be necessary for rheological control. From offset well data it is expected that the mud RECEIVED DEC - 6 1991 Alaska Oil & Gas Cons..Com~iss[e,[t Anchorage , weight will have to be increased to +/- 12.5 ppg after drilling into the Canning Turbidite Fan Complex. This mud weight should then be sufficient to TD the hole. Should shale instability or differential sticking become a problem, a 2 - 4 ppb treatment with a sulfonated asphalt is recommended. Hi-vis sweeps should be pumped as deemed necessary to insure proper hole cleaning. RECEIVED DSO - 6 ~991 AJaska Oil & Gas Cons. Ancho~age~ CHECK LIST FOR NEW ~/ELL .PERMITS I TEN A~PROVE (2) LOC [2 thru (3) Admin c.,g [14 thru 22] Company 1. Is permit fee attached ............................................... Lease & Well YES NO REMARKS 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... ~_ 4. Is well located proper distance from other wells ..................... /~ 5. Is sufficient undedlcated acreage ava[.Table in this pool ............. 6. Is well to be deviated & is well bore plat included ................... ~ 7. Is operator the only affected party .................................. 8. Can pemit be approved before 15-day wait ............................ Does Operator have a bond in force ................................... /~_ Is a conservation order needed ....................................... ~ Is administrative approval needed .................................... Is lease n~nber appropriate ........................................... Does well have a unique nmme $ ntmber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected ... to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ . 10. 11. 12. 13. 15. 16. 17. Will cement tie in surface g Intermediate or production strings ...... 18, Wlll cement cover all known productive horizons ..................... ~ Will .all casing give adequate safety In collapse, tension, and burst. Is well to be kicked off from an existing well bore ................... ~1 Is cid weJ 1bore abandonment procedure included on 10-40~ ............. Is adequate wellbore separation proposed ............................. (5) BOPE . ~(~,/~. ~-/M~/ 23, Is a diverter system required ........................................ /~ [23 thru 28] 24. Is drilling fluid program schematic & list of equipment adequate ..... ~ 25, Are necessary diagrams & descriptions of diverter & BOPE attached .... , ~.~ 26. Does BOPE have sufficient pressure .rating --,test to~j;;~__psig ..... ~ 27. Does choke manifold comply w/API RP-53 (May 84) ...................... ~ · 28. Is presence of H2S gas probable ...................................... FOR EXPLORATORY g STRATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc~ are survey results of seabed conditions presented... 32. [ 29 thr:u j'l ]' Additional requirements ............................................. .qeo 1 ogy' DWd~ ,,~, RPC~ MTM~ LCS//...~J'' dH ,.~Z. '"' ' .,. , . INITIAL GE01 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Well Histo.ry 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 ^PPENDIXi No special 'effort has been made to chronologically organize this category of information. COPY #3 11 il il 11 ii l, ii ii ~1 ri ~1 I1 II ii Ii Il II 11 ti 11 Ii ii 14 F:' F.:E'T' A F'N M "' I r I"' I:. "':":" '":' C 0 H M Iii!: 1'4'i" S ........ Il*Ill %...I o,]0. II Il 'I Il II II I II II II Il Il II II II I1 II Ii II II II II COMF:'ANY NAME: : CONOCO W I-'F i.... L. N A M E : B A D A M I ¢.1.' 2 F" I ELD NAME : W I L. DC':A'T' C 0 I..i Ixl"l' Y : I',10 R'T' H S L 0 P E S'T'A'T'E' : A I.._ A S I.-'.':(:'~ C 0 LJ Ixl T R Y : U S A R I G . . ixl A :El [.J I.,~,=~ 26 E C 0 !"! F' A N Y R F:=.: F::' : W A'T' S 0 ixl / F' 0 L.. Y A RE=CO. RD ]"YF::'E 130 'TAF:'E HEADER R E C 0 R D l....lii..".l'q~'.'!i'T' H ::::: :L 3:2 !iS R V C: N I"1 Y F.':/' M 0 / D g "1" A F:' E N A M I/~.1 R C I:::'IR E'T' A F:'N FI M F:"T' 9 2 / C ':" ' . ... . .),::J / 2 () (') () :i ,:"~ :L C 0 I"l M Ii:: N 'T' S: RE C OR D 'T' Y P E :1213 F I Lli::: HI.=_'A Dii.'.':R ............................................ I:;i:E C 0 R D L ENG'T'H = 62 F:" I L N A M. 1'4 U M i'1A X Ri .... H I=' T ,, () ~':) 1 1 (")2 4 · 'r', v, ,i:::' ,-.':: S I Z E C 0 D E 4 :l B ,:, :1. :L "'1. 4 A 'L .... ~ i :('3 () () 13 DE SCR I F:"T :i: ON UF'/DOWN FL. AG := ..... :1. 0 U"I" F:' U"!' D Ii!!: F' T I'"1 F:" I.... A G =: 0 UNI'I"S OF' DI.:.i:F::"I"H :[Iq DATA F;?.IiECORDS ::= F"F R I!i.:. F:' C O D E. F" 0 R 0 U"I' F::' U'T' D E P"I"I"-I = D T E: R M I N A. "i" 0 F;?. RECEIVED dUN 2 6 1992 Alaska Oil & Gas Cons. Commission Anchora[le NAHE ;' ..... ',." ......... · =~F.:.~;L..I'qM OF:'.DEF;?NLiM. LJI;.4I ~ L...OG't .......... ... ..,,,iZ:F;'VE AF'IM F"IL. NL!M <IZE...., FL..vi"" ' .... F;?. D E I":;"F M P'T' O O (')('~ ()0 () 0 F""F 0 () () () O () I 0 4 ('~ (')() 1 D 8'773. O0 2':3. () 3 D E F' 'l" S R 0 P 8873, ()() :;.?.3, 59 lii) 9'73 ,, 00 21 ,, 30 90'73, 0 () 16, 9 9 ,:::,., .,.'l '7 3 ,, () 0 2 :;::: ,, 1 () 9 '.7'73 ,, C.:, C, :20 ,, '.::::, 9 ,=.,... ,..,"=' .s.., .....,"::' ,, 0 () 2..':l. ,, 94 94 '73 ,, '..")() .... F'¢ 99 ,, 25 '!:5, 5'73. () () 17.3 .1. 9673.0 () :;:'-' 5.0 () 9773 ,, () 0 i 4. '75 98 '73.00 42.."1. ,4 997'3. ()0 4i?). 41 .1. () ()'73 ,, .'")(") 28, 6 :;? 10173 ,, O0 .1. 8 ,, 58 1 (":, 2'73 ()0 17 ,, ' ....... ' .... , ./ .,~:. :L () 373 ,, 00 32 ,, 99 1 () 473. ()0 -..999.25 ':"v='"""' ()() '""-' 6() .1 ..... ~ / ',.'~' ,, ,.:.4, 106'73.00 .... 999 ,, 25 10'7 '73 ,, ()() 12 ,, 2 (7:, '7 2. 16 .'$ ,, ,q.:;..5: 13 9 ,, '7 4 :) .::l J":. L. t .......... , ,:.~ [::.WI .... !..'3'l"l!i:'r-,I 62 ,, 6 C:, 6. '71 1 .':1.3 ,, 26 7 0 ='.=i ~ ::', .1. 4{3 ';'::'6 .... ~.. 4 ,, "" '":l ..... .69.49 ":i., 9'7 1 "$ 5 ,, ()1 '73. () 1 4 ,, 62 146, ,, '7'7 '"""=' :7:.:' 0 q. ,, '7 4 ,1 .... ~, 146 '7 7 73 ,, '7 i;!: 4 ,,b"" =',J .1. ()8 ,, 1 () ""':~ 11:2 / ,._,, (")...... 7 4,6 '7 118 ,, b::::,"' .... 68 '-"-' ,, .... , .,:. 5 16 1 :;;!: ~.~i II {ii.I 64. 12 ':=i '7'7 1 ::30 ":'.~':::' · .-, - ,, 2: ~...~ ...... 3 9 9 ,, ':.'-': [5 6.2 5 :t ;..3 9. '7 .':1. 72 ,, '76 ,..~':=' ,, 1 C:, ".~. '",.':, c," ,, :2:2 '72 ,, 09 6 ,, 46 .1. :3'::3 ,, '7 ,=1· 6':'} o8 .5::5,,':=.'..` ,..~,::, 1 '" '= ':'::, i ' ..... '-l',..i ,: . '7 _1. ,, '!9'.':3 ','5.64 14',:..5.01 "?, ":'...., 99 5 ,,~::.~ ::::.,""' ":" 1 '::i-,"3 ,, 53 '71, 'ii:.; i 5 ,, 51 152 ,, 04 '""', ,..,'""' ,, '."":.~ '7 ,'.'5.1.46 1 t5 ':.'"'. ,, 04 7 4 ,, 0 :;:2: '7 ,, 5 () 155 ,, .~;,... 6" "I:'-~'" b ...... t:,,..., 8,,' .... ~ 52 ;:'.,,"~.. 1 .99 !:'ils:, .. ::=::q 1 ':::' .. !::¥7 '1%',::1. ,:.1.'7 " " (2) ,,...';; .1. ()9 '73 ,, ()c".~ i _1. ,, 4 '7 86 ,, 5'7 4 ,, 65 .I. :.., .,.' ,.:;,, (')..... (":' 'I ',";. ,, 2 '7 81 ,, 5':::~. .'1. ,, ,J"-':;ii'. .1. 1173 ,, 0C; ..... !!)99.25 7 .1. ,, ,'i-2 5.64 :1. '~ ":'"7".:' (..) C) 2'7 8 C.', '"~ =' 4,:::.'.- '-"" ..................... · ,' ,..:, ._,..':I. 2 1 :L 373 ........... c:,c) :3 '1 7 ~'::, ~ 1, '75 rf!: 17 :i. 14. ........ 73, 0 (") .... 999 '""',,"". o""'.1. ,, 4 ~"~-... ,_,"::::. 43 :1. :i. 5'2' 3 ,, ('-.~ 0 44 ,, T.':" 3 '79.7 () (:ii, ,, 70 :i. 1673,.. 0 C)_ "I-. 27 '72. ,'_,'-' 9 6~ :1. 5 11 '77 :.3,, 00 4 ~, '*.,' ~'"'" 70. '"'"'"c:, ,' 6 ,, 'ii') 2 R E C 0 RD I._1..'{ itl G"i" i-.-I = 6:;ii'. F l I...1\! A M. N U M M A X R L M F:'"i" ,, () (.) 1 1 ,.'"~ :24- R EC13 R D L.E N G'T'I..-I = 6:;? I::" I I_ N A M, I\IUM MA X Ri .... I"1F"I' ,, (") () 2 102."1- I::' R E:' V F' L Iq A M E R E CC] R D L..i.:Y N G']"I..-I = '['YF'IE SI ZE C[]DE: 4 I B 13 :L B :L ,4 4 A 15 1 B 0 O B 268 B Y'I"E S ..... ('"' I'"' '"' '~' "" .... D E,:~ ....l'-...,. I:" I I 0 I\1 UI:::' / D OWN I::"L_ A G = ..... 1 [] U'T P U"I' D E F"i"I'"I F' L.. A G = () U N I 'l" S 0 F D E P T'I"'I I N D A T A R E C.: 0 R D S :":: F"I" i;?. E I:::' C O D I'-:': I:'- [] Fi: El U'T F' LI'T D E P T I'"1 -":: D 'l"E RM I N A T ("IR rqAMi::... SI:;;:VC:I\IM ORDE:RI\ILIM LII\II"I' L..OG'I" CRV'i' C:RVC AF'IM i:::']:l....l\iL.Ii"l~o.I. Z E F'L. VI .... R DIFP'I" MI::'T -OCx}C)Cx}C)C~ F"l" C) () 0 0 Cx)2 '.'")4 ()OC) 1 D D A'T' E M F"T' () 000 () () () 0 () () () () () 02 () 4 0 () 01 D "l" i lq E M F' T 0 () 0 () (") 0 () 0 0 () 0 0 () 02 c) 4 () 0 () 1 D F" X 'l" M F"T' () (") ()000 () c':) () 0 () (") 002 04 00 () :1. D D D T M F' T 0 () 00 (") (':) () 0 (') 0 0 () 00 ]il 04 () A () _1. D "1" I.'E M F:' M F"l' c:) 0 () () () () () 0 C:, () 0 0 () ()2 (") 4 0 () 01 D 'T'EMF:' 69 ,,-'.1-3 .1. 18 '" -"'::' ,, I.'~',.~ ....! :l. 2.2. 16 143 ,, 26 12'7 ,, 44 .1. 50 ,, 2'!-':~ 136 ,, 22 :1. 60 ,, ,'.:33 1 '..:.:.;'iii., ,, 08 I'' l]l l''''l''IHH" IXli..Jl II C:(]MIvIEI\i"!'S ~ I"t F:' '1" '-':} 2 / '.:]) 5 / 2 0 0 0 ]. ::'.::, 1 C 0 H !".'I E: i',.i 'T' !!il ALASKA COMPUTZNG CgNTBR *------' 8CHbUMBERGFt~ ....... COMPANY NAME I CONr~CO I~,C, WEbb NAME I BADAI'.{. ~2 FIELD NAME I WILDCAT BOROUG~ I NORTF~ SLOPE STATE { ALAS~,~ APl NUMBER I 50-029-22230 REFERENCE NO I 92210 RECEIVED MAY 1 5 1992 Alaska Oil & Gas Cons. Commission Anchorage ~I$ ?ape Verification Listin~ Schl, umberqer Alaska Computinq Center 27-APR-t992 08:57 SERVICE NAME { EDIT DATE { 92/04/27 REE~ NAME { 92210 CONTINUATION # PREVIOUS REEb COMMENT : CONOCO INC,,WILDCAT,BADAMI #2, 50-029-22230 **** TAPE HEADER SERVZCE NAME { EDI? DATE { 92/04/27 ORIGIN : FbIC TAPE NAME { 92210 CONTINUATION # : 1 PREVIOUS TAPE COMMENT { CONOCO INC,,wILDC~?,BADAMI **** FIbE HEADER **** FIbE NAME : EDIT ,001 SERVICE : FbI. C VERSION : 001A07 DATE : 92/04/27 MAX REC STZE : 8192 F.IbE TYPE : bO LAST FI[,E : COMPANY NAME: CONOCO INC, WEbb: BADAM! FIEbD: WILDCAT BOROUGH: NORTH SLOPE STATES AbASKA AP1 NUMBER: 50-029-22230 [,OCATION: 2700' FNL & 700' FWL SECTION: 30 TOWNSHIP: 10N RANCFlt 20E PERMANENT DATUM: MSb EbEVATION: O' LOG MEASURED FROM RKB 37' ABOVE PERMANENT DATUM PAGEt Tape verification blstlnq 'Schlumberger Alaska Computin~ Center 27-APR-1992 ;,8~57 ~L£VATION~ KS~ 37' RUN NUMB£R~ ONE DATE LOGG£D) 20-F~B-1992 ?D DRIb~ERt 5823' TD EOGGERt 5828' C~SING tt 20" ~ DR~bbER DEPTH O~ O" TO ~20' TYPE PLUID IN HOb~) GENERIC #2 DENSIiTY~ 9,6 LB/GAL PH~ 7,5 VISCOSITYt 7j PLUID bOSSt 7,6 MUD RESISTIVITY) FILTRATE RESISTXVITY~ MUD C~KE RESISTIVITY) 1, ~ 63 DEGF ~ 63 DEGF ~ 63 DEGF M~XIMUM TEMP RECORDCD~ B8 DEGF IN DI. STRICT~ WITNESSt PRUDHOE BAY CHBN~V£Y/WEST HAND,CLARK,MERCER RUN NUMB,ER~ 2 DATE bOGGEDt 21-MAR-t99~ TD DRILLER~ 11560 TO EOGGER~ 11867 BIT SIZE l,~ 12,25" I 85 ~ 55 DEGF 52 DEGF PRUDHOE BAY G. SARBER MERCER,/CEARK DA JOB STARTE 26-~AR-92 6~S ?ape verification Listin~ '$chlumuerger AlasKa Computinq Center 27-APR-1992 r)8=57 bOP/ANAl KRUWELb FILE - EDXT.O01 COMPANY NAMEI conoco XNC, WELbl BADAMI #2 FIELDI WILDCAT MAXN PASS bOG DATA DATA SAMPLED EVERY -.5000 FEET DATA XNCbl. IDED - TOOL EXTENSION TOOL TYPE USED NAME DXTE ,DTE PHASOR DUAL INDUCTIO~.i - SF6 D{TE ,PHA COMPUTING CENTER PHASOR PROCESSED DATA bBS ,LS$ bONG SPACED SONIC bDT ,bDT bZTHO DENSITY bDT eCRC G ,SAN ENVIRONMENTALLY CORRECTED bDT CNT-A/D/H ,CNb COMPENSATED NEUTRON * CNT-A/D/H ,SAN ENVXRONM. ENTALLY CORRECTED CNb * NOT ,NGT NATURAL GAMMA SPEC, CURVES COMMON TO Abb NGT * MAIN bOG DATA * NGT ,KAL NATURAL OAMMA SPEC,(KAbMAN rib?ER) '* NGT ,ALP NATURAL GAMMA SPEC.{AbPHA * A~T ..ALT ARRAY X~UCTION TOOL (6" SA~PLED *.%***$, **************************** **************************** PAGE { TABS~ TYPE TUNI VAbU DEr]: . . .............-,..-......-....................-...... ........... ...........................,,,..,;..;,.;, N CONOCO INC, Company Name CrN WILDCAT Field Name WN BADAMI #2 Well Name APIN 5QT029-22230 APX Serial. Number rb 2700' FNb & 700' rw6 Field Location SECT 30 Section TO~N iON Township RANG 20E Range COUN NORTH SLOPE County STAT ALASKA State or Prov~nce NAT! USA Nation ,bis Tape Verification LlstXnq SchlUmberger Alaska Computinq Center 27-APR-1992 08157 PACEI 4 TUNX VAbU DEFI WXTN MERCER/HAND/POYbA Witness Name 548510 MSb Service Order Number Permanent.datUm ~e Elevation ot Permanent Datum bog Measured 370 Above Permanent Datum 37, Elevation of Kelly ~6. Derrick r&ogr Eleva:~o~ o~ 1 ~ Total Deot~ - bogger ~o~om tog Interval 11833 445, ' TOp I~oq Interval GENERIC · lI,5 9.7OOO0! 56, 4,b Y 58 ~.~9 rate...-S 56 ~ampl 17§, Cure' #2 TABbE TYPE I CURV C~DP ZDPH (:PER 3:DER CDVR IDVR '.l MP MPH CMER XMER CMVR XMVR ! ZDOF IMOF IIRD I~XD Depth INDUCTION DEEP PHASOR CONDUCTIVITY INDUCTION DEEP PHASOR RE$IST~VIT~ DEEP INDUCTION ENHANCED RESObUTION PHASOR C['!~',oUCTIVITY DEEP INDUCTION,ENHAnCED eE$ObUTTON PH~$OR Re, S.~STIVITY DEEP INDUCTION VERY,ENHANCEO RE~ObUTION'PHAS{i~ CONDUCTIVITY DEEP'INDUCTION V'ERYiENHANCED RE~ObUTION PHASD;~ RESISTIVITY XNDUCTXON. ~EDIUM PHASOR CONDUCTIVITY .... 'INDUCTION MEDIUM PHASOR RESISTIVITY MEDIUM INDUCTION ENHANCED RE$ObUTZON ~HASOR C,'I~DUCTI~Ty .MEDIUM XNDUCTIO~ ENHANCED RE$Ob~T)ON PHA$OR M.EDIU~ INDUCTION VERY-~NHA'NCED 8EBObU~ION PHAi~OR ~ONDt)CTIVITY MEDXUM INDUCTION VERY-ENHANCED RE&ObUTXON PHASOR RESISTIVITY ConductXv~t¥ Xb Deep St, a~datd Processed Deep Imduc:lon Standard Processed Resistivity ~op~uct~v~t¥ Ib ~ed~um Standatd Processed ' ~eo~um InouctXon Standard Processed ResxstXvlty IOOF DEEP INDUCTION OUA. bZTY FACTOR IMOF MED INDUCTION OUAbITY FACTOR_ ~eep' ~ndu¢~Xon Rea! Xn:ermedXate ~onduct~vXt¥ Dee~ Induction Ouad X~termedXate ConductXvXt¥ ,LIS ?ape Verification List! SchlUmberger Alaska Computtnnqg Center 2?-APR-1992 DEr! [IR~ Medium Induction Real Intermediate Conductivity I~X. ~edium In~tion Ouad Intermediate Conductivity SbU SFb Resis lty Unaveraqed SP Spontaneous'Potential ' GR Gamma Ra CAbS Sonic Caliper TENS Tension MTE~ .ud Tems_e~atu re pity HTEN Head Tension DT DTL DE~TA-T bONG SPACING DT~N DELTA-T ~ONG SPACING DTLF DTbF G~ Gam~a Ray I~S Tension N ~ud Temperature ~RE8 MUD Resistivity HTE~ Head Tension DPH! Density POrosity RHOB Bulk vensity DRHO Delta RHO per PhotoElectric Factor Q S 9ual[ty con~ro~ of iPng. sPaciog f~[rbDT ua,,ty concro, on snort spec,ng ~ong ~pacing Computed Count Rate bOng upper i-2 Nlndow Count Rate {bb+bU/2 ~lt~olog Windo~ Count Rate SS'! Short ~ac~nq ! Windo~ Count Rate SS2 Sbort'Spaqzn~ 2 ~indo~ Count Rate bSHV bonq'SpaczOq'Hiqh Voltage, SSHV Short Spacznq HtQh Voltage SlRH Short_Spa~ing 1 Density bSRH bong sPacln~'~ulk Density LURH ~oOq,Upper Bul~ Density C~! 'cat[per . SGR Spectroscopy Gamma Ray TENS 'Tension ' ~TEM Mud Temperature MR£$ MUD Resistivity HT£N Head Tension PHND DENSITY POROSITY CALCULATED FROM THE gNHA~C~:I') RHOt.~ PFDC Porosity ~rom the FOC Too~ NRHO ,Enhances Vertkcal Resolut,on Oensity RHOB PEF DRHO RTNR TNPH TNRA NPOR Bulk Densi PhotoElectric Factor Delta RHO Neutron Porosity Raw ?~ermal Neutron Ratio Thermal Neutron Porosl~ Thermal, Neutron atio li ra ed Neutron Porosity from an Application Proqra~ " 2?-APR-t992 09:57 Tape Verification bistinq .,Schlu.mberger Alaska Computlnq Center D~[I RCNT RCNT RCFT RCFT CNTC CN?C CFTC CFTC SGR Spectroscopy Gamma Ray TENS Tension, MRES MUD Resistivity MTE~ Mud Temperature HTEN Head Tension NPO~ Neutron Porosity from. an ApPlication Program TNPH Therma! Neutron Porosity NPH! Neutron Porosity URAN Uranlum THOR Thorium PO?~ Potassium SGR Spectroscopy Gamma Ray CGR Comppted Gamma Ray URAN Uranlum THOR Thorium POTA Potassium SGR Spectroscopy Gamma, Ray CGR Computed Gamma Ray CS Cab!e Speed ~ING window 1 (.1~ !5 ~2NC ~lndo~ 2 (,5 ~ ~ev) ~3NG window 3 (!,. - [ 6 ~ev) W4NO N[ndow 4 Ct,6 - 2 Mev) NS Tension HTE~ Head Tenet n t~v ty MRB8 ~UD Resi~ ~?BM HUd Temperature GR Gamma Ray SP Sponteneous Potential H?E~ Head Tension .TEN8 ?enston ** DATA' FOR.MAT SPF, CIF'ICATION RECORD ** SET TYPE - 64EB ~ TYPE REPR CODE VAbUE 1 66 0 2 66 0 3 73 ~40 4 66 . 6 LIS Tape Verification Ltsttnq ,$cl~l,umberger ~laslce ComputtnCj Center 27-APR-1992 0~:57 TYPE REPR CODE VAbUE 7 65 11 66 18 12 68 13 66 0 14 65 15 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** NAME SERV UN.IT SERVICE AP1 APl AP1 API FIbE NUMB NUMB SiZE REPR PROCESS ID ORDER # bOG TYPE CbA$S MOD NUMB SAMP El, EM CODE (HEX) DEPT FT 548510 O0 000 O0 0 I I I 4 68 0000000000 C!DP PHA IoPH PHA CDER PHA XDER PHA CDVR PHA IDVR PHA C~MP PHA IMP~ PHA CHER PH~ ~MER PHA C~VR .PHA IMVR PHA CXbD DTE IbD DTE X~GF DIE ! OF DTE 'I~RD DTE ! XP DTE IRM DTE IXM DTE SFLU DTE SP DTE D? MTEM MRES.DTE HT~ DTE DT LSS DTL LSS DTLN bSS DTLF LSS MHHO 548510 O0 000 O0 OHMM 548510 O0 000 O0 .MHO 548510 00 000 O0 OHMM 548510 O0 000 o0 MMHO 548510 O0 000 O0 OHMM 548510 o0 000 O0 MMHO 548510 O0 000 O0 OHMM 548510 00 000 O0 ~M.O 548510 OO 000 o0 OHMM 548510 OD 00o O0 MM.O 548510 DO 000 O0 OHMM 548510 0o 000 00 MMHO 548510 O0 000 00 OH.. 548510 O0 000 O0 MMHO 548510 O0 000 O0 OHMM 548510 oo 000 O0 548510 O0 000 O0 548510 00 000 OD MMHO 5485i0 00 000 00 MMHO 548510 O0 000 O0 MMH0 548510 00 000 00 ~MHO 548510 O0 000 O0 OH,M 5485!0 O~ 000 O0 MV 548510 O~ 000 O0 GAPI 548510 O0 000 oo IN 548510 O0000 O0 o~ ~4.,,o ODooo oo o... ,4.s,o ooooo oo , ,4e,,o ooooo oo O0 O0 US/F 548510 00 O000 US/F 548510 O0 O0 68 68 68 68 68 68 68 68 68 6~ 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 00000000 0 O0000000gO 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000o00 0000000o00 0000000000 0000000000 0000000000 00000 ooooo~88~ 0000888800 0000 O0 000 1 ooo2~ ~ oo oo~ ~888 000000 00 000000§~00 bls Taoe VertftcatLon b~sttnq Schlumberger Alaska Com~uti. n~ Center NAME aERY UNIT aER ID ORD OR bS$ GAP1548 TEN8 GS8 I.,B 548 MTEM baa DEGF 548 MRE:8 baa OHMM 540 HTEN bS8 bB 548 DPH! bDT PU 548 RHOB bO~ G/C3 548 DRHO bD~ G/C3 548 PEr ED~ 548 Ob8 bD~ 548 088 bDT 548 bS bDT CPS 548 bU bDT CPS 548 Lb bDT CPS 548 blTH bDT CPS 548 SSi bDT CPS 548 S62 LOT CPS 548 bSHV bDT V 548 81RH bDT G/C3 548 bSRff bDT G/C3 548 bURH bDT G/C3 548 C~bI bDT IN 548 SGR bDT GAP[ 548 TENS bDT bB 548 HTE~ bDT DgGF 548 MRE8 bDT OHMM 548 PHND SAN PU 548 PrDC 8AN PU 548 NRHO CRC G/C3 548 PEr.RHOBCRC CRC G/C3554848 DRHO CRC G/C3 548 NPHI tnb PU 548 RTNR CNb 548 TNPH CNb PU 548 TNRR CNb 54 8 NeOe cN~ eu s4e RCNT CML CPS 548 RCr~CN~ CPS s4~ CNTC CML CPS 548 CFTC C~b CPS 54a SOR . GAPZ 548 TENa ~NL Nb bB 548 MRE8 CNb OHMM 548 MTEM CNb DEGF 548 HTEN CNb bB 548 NPOR 8AN PU 548 TNPH SAN PU 27-APR-1992 08~57 VICE API APl APl AP1 FIbE NUMB ER ~ bOG TYPE 510 O0 000 O0 0 1 1 510 O0 000 O0 0 1 1 510 O0 000 O0 0 5tO O0 000 O0 0 510 O0 000 O0 0 1 1 510 O0 000 O0 0 1 1 510 O0 OOO O0 0 1 1 510 O0 000 O0 0 t 1 5~0 O0 000 O0 0 510 O0 000 O0 0 I ! 510 O0 000 O0 0 1 l 510 O0 000 O0 0 I l 510 O0 000 O0 0 1 I 510 O0 000 O0 0 1 t SlO O0 000 O0 0 1 1 510 O0 000 O0 0 1 t 5i0 O0 000 O0 0 I 1. 510 O0 000 O0 0 I 1 510 O0 000 O0 0 1 1 510 O0 000 O0 0 I 1 510 O0 000 O0 0 I , 510 O0 000 O0 0 1 1 510 O0 000 O0 0 1 1 510 O0 000 O0 0 ! 1 510 O0 000 O0 0 1 1 510 O0 000 O0 0 1 1 510 O0 000 O0 0 510 O0 000 O0 0 1 1 5,0 O0 0O0 O0 0 1 510 O0 000 O0 0 1 510 O0 000 O0 0 I i 0 O0 000 O0 0 I 1 510 00. 000 O0 0 $1o O0 o00 OO 0 5!0 O0 000 O0 0 510 O0 000 O0 0 510 O0 000 O0 0 ~,o ooooo ooo PAGiC! mmmmmmmmmmmm#mmmmmm~m~mmW~ UMB SIZE REPR PROCESS bg~ CODE [HEX) 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 68 0000000000 4 6fl 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 ~8 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 00000000 0 4 68 000000 0 oooo~~ ~ ~ o ~o 4 0000 0000000000 ~ ~ 0000000000 ooo o ooo8~88~8o 4 68 ,000 , ~, ooo~~°° o,o ~ ~ oooooooooo 4 68 ~0000000 4 68 0000 4 68 0000000~000 4 68 000 ~0 , ~, oooggggg.g , ~, oooooooooo 4 68 000000 0 4 68 000000~§0 ~ ~ ~8 1oo ~.ooo o~ ~ ~ ~, ooo~§o oo , ~ ooo~ooooo " b%8 lape. vert~ioation bist~n · $chl, 1 ska ComPuttn.~ en mverget a .~ C ret 27-APR-1992 08=57 PAGEt -mmm~-~m~mmmmmmmmmm---mm#mmmm~mmmmmmmmmm.-mm-mmmmmmmmmmmmmmmmmmmmmm-m~m"m-m.m-~"----m. NAME SERV UNIT SERVICE APl AP! AP! APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CbASS MOD NUMB SAMP EbE~ CODE CHEX) '''''''''''''''''''''''''''''''''''''''''''''''''''''''''';''" Ab PPM 548510 0 O0 0 1 1 ..... 4 '''''''''''''''''''''68 000000000 THOR KAb PPM 548510 O0 000 O0 0 1 ! I 4 68 0000000000 POTA KAL PU 5485]0 O0 000 O0 0 1 ! I 4 6a 0000000000 SGR KAb GAPI 548510 O0 000 O0 0 1 1 1 4 68 0000000000 CGR KRb GAPI 548510 O0 000 O0 0 I 1 1 4 68 0000000000 URAN AbP PPM 548510 O0 000 O0 0 1 1 1 4 68 0000000000 THOR AbP PPM 548510 O0 000 O0 0 1 1. 1 4 68 OOOO000000 POTR AbP PU 548510 O0 000 O0 0 1 1 ! 4 68 0000000000 SGR ALP GAP! 548510 O0 000 O0 0 1 1. 1 4 68 0000000000 CGR AbP GAP! 548510 O0 000 O0 0 I I I 4 68 0000000000 CS NGT r/HR 548510 O0 000 O0 0 1 t 1 4 68 0000000000 WiNG NGT CPS 548510 O0 000 O0 0 1 1 ! 4 68 0000000000 W NG NGT CPS 548510 O0 000 O0 0 I 1 1 4 68 0000000000 WiNG NG? CPS 548510 O0 000 O0 0 I 1 1 4 68 0000000000 W NO NGT CPS 548510 O0 000 O0 0 1 1 1 4 68 0000000000 WSNG NGT CPS 548510 O0 000 O0 0 1 I 1 4 68 0000000000 TENS NGT bB 548510 O0 000 O0 0 1 I 1 4 68 0000000000 HT£N NGT bB 548510 O0 000 O0 0 I I 1 4 68 0000000000 ,RES NGT OHMM 548510 O0 000 O0 0 1 1. 1 4 68 0000000000 MTEM NGT DEGF 548510 O0 000 O0 0 I 1 I 4 68 0000000000 GR AlT GAP! 548510 O0 000 O0 0 1 1 1 4 68 0000000000 BP AlT MV 548510 O0 000 O0 0 1 1 I 4 68 0000000000 H?EN AlT bB 548510 O0 000 O0 0 I ! 1 4 68 0000000000 TENS Alt bB 548510 O0 000 O0 0 1 1 1 4 68 0000000000 "~m.m)""mmmmmm~m~mm.mmmmm-mm-Nm.mmmm.mm~Mmmmmmmmmmm~Mmmmmm~mmmmmmmmmm~mmmmmmmmmmmmmmm" DATA D~PT Z~PH PHA VR PHA IIXD DTE SP DTE MTEM DTE DTL bSS TENS DPH! bDT OLS bDT Lb bDT ~SHV bDT LUSH bDT MTEM bDT PFDC SAN DRHO CRC NTC Nb ~RES Nb TNPH SAN -999 -999 -20 -999 -999 ~999 '999 -999 -999 -9 -999 -ggg 250 25O 101 588 0 0 000 ~$0 25O ~50 ~- 0 250 ~$0 ~50 CIDP,PHA CDVR,PHA CMER,PHA CIbD.DTE I .DTE GR.DTE MRESeDTE OTbN,bSS MTEM,bSS RHOB,[~DT ~SS.,LDT SSHV,hDT CALZ,LDT MRES,LDT NRHO CRC ~PHI CNb NPOR CNb CfTC CNb MTEM CNb NPHI SAN -999 -999 -§99 252 55 0 91 -99~ -99 -99g -999 -999 -999 . IDVR,PHA .~50 I~ER.PHA , 43 lbO,DTg 00 IMOF.DTg 87 IIXM,OTE 302 CAb$.DTE 596 HTEN.DT~ 900 DTbF.LSS 608 ~RES.bSS 250 DRHO,bD~ 250 bS,bD 250 SSi.gDT 250 $.iRH.bDT 250 SGR,bDT 250 HTEN.bDT 250 RHOB,CRC 250 RTNR,CNb 250 RCNT.CNb 250 SGR,CNb 250 HTEN,CNb 250 URAN,KAb -999.250 CDERePHA -999.250 CZMP.PHA 964 CILM.DTE 0 000 IIRD.DTE -0:446 SFbU.DTE TENS,DTE 9~.300 GR.b$S 596 HTEN.LSS :999: .bO°bDT -999,250 bSRH bDT '999 ' PHND,$AN -999.250 -999,]50 TNPH.CNb -999. 50 RCrT.CNb -999.250 -999.250 -999.~50 THORoKAb 2So '99' 250 , 23 44 38~5 000 .30 '-99' 2 -99' 2250 '-,,' '999 "999 '999 250 "999 25O .Tape veriticat?on bist no 'Schlumoerget Alaska Computinq Center POTA.KAL THOR.ALP C8.NGT W4NG.NGT MRE$.NGT HTEN.AIT DEPT. IDER,PHA IMPH.PHA IMVR.PHA IbM.DTE IIXD.DTE SP.DTE MTEMeDTE DT~.LSS TENS.LSS DPHI.LDT OhS.bDT Lb,bDT bSHV,LDT bURH,bOT MTE~.bDT PFDC,SAN DRHO.CRC NT~,~ Nb Nb MRESeCNL TNPH,SAN POTR, w4CS.NGT .,NG.NGT M~E$,NGT HTEN,AIT IMPH PHA IMVE PHA IIXD SP DTE HTE~ OTE OTb bSS TENS.LS$ DPHIebDT ~LS,LDT Lb,LOT LSHV,bDT LURH.LDT MTEM.,LDT PrOC,SAN OR. HO.CRC TNR~eCNL '999,250 '999,250 '999,250 '999.250 ~999.250 '999.250 1180~,000 ,922 3,636 3,901 3.756 32.674 '20.500 178.608 89 110 7125 000 96 658 1252 795 18~ 646 -00 0 577 37 706 4O 17~4 940 8 906 0 577 653 336 11600 000 6 ~84 6 97 6 267 6 181 6840 000 18 266 -0 063 181,~063 1253.109 2 !68 18~ 44 1° ~0 5 2 87! SGR,KAL POTA,AbP WlNG.NGT W5NG.NGT HTEMeNGT TENS,AIT CDVR.PHA CMER.PHA C~LD,DTE IDQF DTE IIRM DTE GR DTE MRE$ OTE DTbN. LS$ MTEM, LSS RHOS, LDT QS$,LDT LXTH bDT $$HV, bDT CALX. bDT ~R~8 NRHO CRC ~P~! CNb aPOR CNb CfTC CNL ~EM. CNb NPHX. SAN SGR~KAb POTA~AbP ~ING.NG~ WLNG.NG? CZDP.PHA ~DVR.PHR CMER.PHA CXLO ]DQr GR OTB. ~TEM RHOS, bOT ~$$ bDT blTH bDT $SHV:LDT CALX, bDT ~RES, LDT ~RHO, C.RC ~PH! NPOR CNL 27-APR-1992 08157 '999,1~0 CGR,KAL -999, 0 SGR.ALP '999,250 W2NG.NGT '999, 0 GR,AIT -999,250 251, 262,64 299.51 0 O. 89.01 178.60 2.63 -0 O0 1339 12 30 0 57 2,64 35,.03 35.12 734,23 ~87.07 37.70 125.30 4.08 85 6620,00 ! XDPH.PHA 8 IDVR.PHA 7 IMER.PHA 3 ILD.DTE 0 IMQF.DTE 7 IIX~,DTE CALS,DTE HTE~,DTE 3 OTbr,b$S 8 ~RES,bSS 0 DRHO,bDT 2 LS,bDT 6 8SI.bDT 4 81RH,LDT 1 SGR,bDT 7 HTEN,bDT RHOB.CRC RTNR,CNL 9 RCNT.CNb I SGR,CNb 0 HTEN.CNb 6 URAN,KAL 3 CGR.KA[, 2 SGR.AbP 2 W2NG.NGT 5 TENS.NGT 0 GR,AIT 0 150,808 IDPH.PHA 49,:138 IDVR,PHA {60.663 IMER,PHA ILO.DTE 1.5~,~ IMQF.D'rE 61, CALS:DTg DTLF,bSS 178. ~RES DRHO,bDT 43, 5 SSi,bDT ~343. $1RH,bDT 1'3. SGR,LDT 0,~ i HTE~,bDT i, ' RHOB,CRC '2 ,~58 RTNR,CNL 29, 63 RCNT.CNb 999.250 -"999,250 -999o250 -99~.250 -99 , 25O 3.359 3.980 3.807 3.339 3. 12.134 910,240 -0 005 195 533 18~ 384 657 125 303 553 931 2 645 3 302 2446 87O 125 303 553 5 210 95,208 168.779 207.818 6110,000 141.627 6.631 6.705 6.224 6.572 0.000 6,031 13.088 2 060O 0 .098 351 928 24~ 655 O48 72.967 58 3 2509 ~1934 URANeALP CGR,ALP W3NG,NGT HTEN,NGT SP,AIT CDER,PHA CIMP,PHA CHVR,PHA CILM.DTE IIRD,DTE SFbU,DTE TEN$.DTE DT.L$$ GR,GSS HTEN.LSS PEFeLDT LU,LDT SS2.LDT LSRH,LDT TENS bDT PHND. SAN PEr CRC TNPH CNL RCFTCNL TENS CNL NPOR :SAN THOR KAL URAN ALP CGR ALP ~3NG NGT HTEN,NGT SP,AIT' CDER,PHR CI~P,PHA CILM.OTE IIRO,DTE SFLU DTE TENS DTE DT bSS GR LSS HTEN bSS PEF bDT LU LOT 882 bDT GSRH LOT TENS bDT PHND SAN PEr CRC TNPH CNL RCFT CNb PAOEi '999,25 .-999i2500 '999,2500 256, 0 256, 259 · 55 12 23~ 6 0 ' 692~318 6110,O00 149 61.9 161 .7.96 13~ 914 bis Ta~e VerIfLcat/on ~Lsting Sc~lumoerger Alaska ~om~uting Center 27-APR-!992 09;57 PAGE! CNTC.CNb 2368.128 CFTC.CNb MRES.CNb 0.591 MTEM.CNb TNPH.SAN 30.928 NPHI,SAN POTA.KAb 2.383 SGR,KAb THOR,ALP 10,425 POTAoAbP w4CS,NGT 1832,316 W1NG,NGT 836.927 SGR,CNL 185,144 HTEN,C~L 30.928 URAN.KAL 72.967 CGR.KAL 2.383 8GR.AbP 250.000 W2NG.NGT 8051! TENSoNGT 185.144 GR,AIT 6450.OO0 72.967 TENS,CNb 63[0.000 901 09 574 W3NG,NGT 320 9 6310 000 HTEN.NGT 61X,884 5! 647 8P.AIT -62. DEPT. IDER, IMPH. IbM, ~IXD SP MTEM DTb TENS DPH! Lb hSHV, hURH'. MTEM PFDC DRHO ~NRA CNTC MRE8 TNPH POTA THOR C$ W4NG MaE8 H?EN PHA PHA PHA DTE DTE DTE DTE bSS hSS bDT bDT bDT bDT bDT bDT SAN CNb CNh .CNb 'SAN KAL ALP NGT NGT 11400.000 ,'747 ~,590 6.484 6,423 14,9i0 '45,938 175e905 78,400 7320,000 19,350 "0,088 174.458 125~.998 .268 18. 6 0 066 3295 2007 637 0 6O2 34 834 2 338 ! 12 li.852 0,602 671,384 CZDP.PHA 147.362 IDPH.PHA 6.786 CDER,PHA CDVR.PHA 149.878 IDVR.PHA ~.672 ClMP.PHA 15X~ 50 CMERePHA 152.408 IMER,PHA .561 CMVRePHA 154,~33 IDQF,DTE ,000 IMOF.DTE .000 IIRD,DTE 131,716 GRDTE 67.328 CAL$,DTE 14 486 TENS,DTE 73 MRE$ DTE ~.605 HTEN,DTE 910 104 DT.bSS .78.355 DTLN bS$ I ,737 DTbF.b$$ 67,328 MTEM hSS ! ),905 MRE$.b8$ 0 605 RHOB 085 blTH SSHV CAbI MRES, NRHO, NPHI NPOR CFTC MTEM NPHX POTA TENS bDT bDT bDT LOT bDT bDT CRC CN NG? 4~ *080 ,924 ~342.8~643 15. 0 602 3~ 34! 698 .3 63~ 143 427 180 918 4.834 2.609 .586 7, 1 180.918 6510,000 DRHO.LDT kS.bDT SSt,bDT S1RH,bDT SGR,bDT RHOBeCRC RTNR,CN~ RCNT.CN5 SGR.CNb HTEN.CNb URAN,KAb CGR,KAL SGR.AbP W2NG.NGT TEN$,NGT GReAIT 8! 203 _ GR,b$$ HTEN.b$8 910.104 0 070 PEr,bDT 17,933 345 ~94 hU.bDT 34~,671 233326 8S2.bDT 289,862 72 609 TENS.bDT 639~;000 9 022 PHND.$AN ~8.,736 542:341 PEF,CRC 13,674 201§. 8 RCFT. Nb 6 42 62,887 URANeAbP 138. W3NG,NGT 642 6395.000 HTEN.NGT 549,022 62.095 DEPT° IDER. I~PH IMVR 'IbM IIX~ 8P MTEM TENS DPH! Ob8 bURH MTEM PI. IA PHA OTB bBS 11200,000 5,.313 5,201 5,,191 5 094 18 882 6675 000 ,$$ 22 ~79 -0 .$0 177~80! CIDP CDVR CMER ClbO IOOF XIRM ~R MRES DThN MTEM RHOB bITH SSHV CAbI MaES PHA PHA PHA DTE DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT 185.503 .248 ~'8 .703 8~ *000 .661 174.641 0.60! 83,556 173,642 2,275 0,096 47.878 1341.461 14,938 0.599 IDPH IDVR IMKR ltd IIXM CAbS HTEN DTLF MaES DRHO S~RH SGR HTEN , PHA ,PHA .PHA .DTE ,DTE .DTE .DTE .hSS ,bSS .bDT ,bDT ,bDT .bDT ,bDT , LOT 5.39t 5.332 5.175 5.328 0,000 12,640 1~.543 943.806 267 0.062 37~.801 47 74.568 530.440 CDER PHA CIMP PHA CMVR PHA ClbM DTE IIRD DTE 8FLU OTB TENS DTE DT LS8 GReLSS HTEN,LS$ PEFiLDT LU,LDT $S2,LDT LSRH.LDT TENS,LDT PHND.SAN 498 641. 94 806 ,14 79 367 ~48 288552 2 5755000 21895 bls Tape Verification blstinq Schlumberger Alaska Computing Center P~D¢ SAN DRHO CRC ~RES ~N~ TNPH,SAN DOTA,KAL THOR ALP CS NGT W4NG NGT MAES NGT HTEN AlT DBPT.pHA IDEA, IMPH,PHA IMVR,PHA TbM,DTE IIXD,DTE SD,DTE N?EN,DTE DTL,bSS TENS,bSS DPHI,bDT QbS,bOT Lb.bDT LSHV.LDT bURH bDT MTEN bDT PFDC SAN DRHO CRC TNRA CNb CN?C.CNb TNPH PO?A KA THOR .lb~ w4CS;NGT NG,NGT HTEN,~. 895 2~ 062 3 272 2119 973 0 599 33 960 2,514 15 699 1757 033 7 901 0 599 700 136 NRHO CRC NPHI CNb NPOR CNb CFTC CNL MTEN CNL NPHI,SAN SGR,KAb POTA.AbP WtNG,NGT W5NG,NGT ~TEM,NGT TENS,AIT IDER IMPH I~VR Z'XD TENS DPH! llO00,O00 4,422 4,333 3O4 4'281 85,214 6980,000 21.,756 '0,09~ 125 17~ '207 ,879 2~,8t9 ,086' 3,293 2130~235 0 1801;6 0,609 699,694 ClDP,PHA CDVR,PHA CMER,PHA CIbD,DTE IDQF,DTE ~IRH,D?E GR,DTE HRE$,DTE DTbN,bSS MTE~,bSS RHOB BDT blTH bDT SSHV bDT kbX BDT ~RES bDT NRHO CRC NPH! tnb NPOR CNL CFTC CNL ~TEM CNL NPHI.SAN SGR KAL POTR ALP UtNG.~GT WS.NG~ GT MTEM,N'GT TENSeAIT 10800,000 CIDP,PHA PHA 10,323 CDVR PHA PHA 9,497 CMER PHA DTE 3 I IIRM DTE 76 625 GR DT'E l~I ~16 MRES bSS 24. DTLN 6790 bSS 000 bDT 21 629 RHOB bDT '0.057 QSS BDT 181.214 LITH 27'APR'1992 08:57 771' ot 33,960 '74.568 ~3~ 946 O74 11 852 t77 801 6350 000 RHOB.CRC RTNR.CNb RCNT.CNb SGR.CNL HTBN.CNb URAN.KAb CGR,KAb SGR,AbP W2NG,NGT TENS.NGT GR.AIT 227.372 228.043 23 511 0.000 85.342 170.789 2 291 0 067 54 893 1339 842 ,16 23 0 60~ I645 8?9 ~ 4 453 8; 647 165 74 32 72 79 IDPH.PHA IDVR.PHA IMER.PHA ILD.DTE IMOF.DTE IIXM.DT£ CAbS,RTE HTEN,'DTE DTLF,bSS ~RES,LSS DRHO,bDT bS.I, DT SSI.bDT SiRH.LDT 8GR,LDT HTEN.LDT RHOB,CRC RTNR,CNb ~CNT CNb SGR:CNb N,KAL CG~,~Ab 8G ,.bP W2NGeNGT TE~.NGT ,AlT ].]89 PEF CRC . 13 TNPH CNL 2385.569 RCFT CNL 74 568 TENS CNL 530:440 NPOR SAN ~.153 THOR.KAL 7 .814 SP.AIT PAGEI 4.398 CDER.PHA 4.385 CIMP,PHA 4.338 CMVR.PHA 4.362 CIbM,DTE 0.000 IIRD.DTE 5.841 SFLUeDTE 14 650 TENS.~TE 934:001 DT. SS 19.458 32,448 610.I18 5755,000 37 31 530,440 -72,375 86.586 GR.bS8 0.610 HTEN,LSS 0 085 PEF,LDT 384 434 bU.LDT 084 SS2.LDT 24½ 024 LSRH.LDT 83 647 TENS.bDT 54~ 952 PHND,SAN 306 PBF.CRC 3 376 TNPH.CNL 2263.46~ RCFT,CNL 83.647 TENS,CNL 546..952 SAN 2.945 ~OR. . OR.KAL 66'637 URAN.AbP 134.214 CGR,AbP 126,357 WSNG,NGT 6~80,000 HTEN.NG~ 65.653 8P,AX.T 95.~28 IDPH,PHA 9i. 8'1 'IDVR,PHA 104.]54 IMER,PHA 96. 70 'ILD,DTE 0 000 IMQF,DTE DTE 104 530 IIX~eDTE 4 DTE 56 492 CALS.OTE 13 DTE 8 ~7 HTEN.DTE 889 LSS 8 5 DTLF,bS$ 80 Las 16~.~6 MRES.bSS bDT , 3 DRHO.bDT bDT ~.072 [,S.bOT ~50 bDT' 5 .'884 SS1.LDT 22 6O2 195 938 ? 93~ 19 ,! 20 61~ .000 'i57.3~3 ~ 457 DER,PHR 943 ~IMP,PHA 592 CMVR,PHA 10 377 ClLM DTE 0 000 IIRD DTE 707 SrbU OTB 363 TENS DTE 568 DT bS 924 GE 627 HTEN 030 PEr 454 LU 437 882 .9 0 67~0 80 bDT bDT i2 465 o oo b'IS Tape Verification Listing '$chlumverger laska Computing Center bSHV bDT bURH bDT MTEM bDT PFDC SAN DRHO CRC TNRR CNb CNTC Cgb MRE$ CNb TNPH SAN POTR KAL THOR ALP CS,NGT W4NG,NGT MRES·NGT HTEN,AIT DEPT. IDER.PHA MPH·PHA I;VR.'PHA bM,OTb IIXD·DTE 8P·DTE MTEM DTE DTL bSS TENS LSS DPHZ. LOT b HV MTEM bDT PFDC SAN TNRA CNTC T~PH SAN POTA KAL THOR ALP CS NGT W4NG NGT MRES NGT HTEN AlT DEPT. IDER,PHA I.~PH.PHR VR.PHA IILN,DTE .DTE MTEMeDTE DTL,LSS TEN$,LSS 1251.085 SSHV.LOT , 274 CALl,LOT 17 ,561 MRESeLDT 21.~46 NRHO.CRC O. 25 NPHXeCNb 3,~8 NPOR,CNb 2353, 5 CFTC,CNb 0.~18 MTEM.CNL 33, 8 NPHIeSAN 2,572 SGR.KAB 10,038 POTA.AbP 1803,348 W1NG..NGT 5,932 WSNG·NGT 0,618 MTEHeNGT 710,567 TENS.AlT 1060 4 686 1250~ 5, 0 270~ 0 31 2 ? 0 0,000 9.945 9,522 25 03:~ 24 58 O0 6ee~44 9 '174 021 :118 8? 4 6 8 659 '/O2 29O .9 1 1040~, · 6 6 '107 165 8 640~ 00.0 4"/4 285 :200 :206 880 88 355 000 CIDP,PHA CDVR,PHA CMER.PHA CIbD-,OTE IDOF.DTE IIRM..DTE GR,DTE MRES.DTE DTLN,bSS MTE,MebSS RHOBeLDT QSS,bDT LITHeLDT 8SHV.eLDT CALX,bDT MRESebDT NRHOeCRC NPHX,CNb NPOR,CNL CFTC,CNL MTEM,CNL NPHX.,SAN SGR·KAb POTR,AbP NINGeNGT WSNG,NGT MTEM,NGT TENS.AlT CIDP.PHA , CDVR,PHA CMER,PHA CILD.DTE IDQF,OTE IIRM.DTE iGR.DTE MRES,DTE DTLNebSS MTEM·bS$ 27-APR-1992 0g:57 14. 2 0.618 2.29i 32 054 33 974 770 787 218 7! 690 2.582 212.556 5.932 17~.56! 628 .000 94.524 O. . 4 16~,624 .547 St. 8 1337,469 13·338 0.629 2 567 897 914 580 2 565 207 4O7 3,951 ,000 668 0,000 151,923 62.418 0,626 $ $1RH.bDT SGR.bDT HTEN,LDT RHOR.CRC RTNR,CNb RCNT.CNL SGR.CNb HTEN.CNb URAN.KAL CGR,KAb SGR.ALP W2NG.NGT TENS.NGT GR.AIT XDPH.PHA IDVR.PHA IMERePHA ILD,DTE IMQF.DTE IlXM,DTE CAL$.DTE HTEN,DT~ DTLF,5$S MRES.bSS DRHO.bDT bS.bDT $SlebDT $1RH,bDT SGR.bDT HT~NebDT RH00,C~C RTNR,CNb RCNT·CNb SGR.CNb HTEN,CNb URAN,KAL CGR,KAG SGR,ALP W2NG,NGT T~NS,NGT GR.AIT IDPH.PHA IDVR,PHA IMER,PHA ILD.DTE IMQF.DTE IIXM,DTE CALS.DTE HTENeDT~ DTLF,L$$ MRES.LSS , 71. 536. 2364. 536. 2. 58 10! 5905 49 Om 19. 9. 3, 13. 945, 80. O. O. . 2 3023 580 2 60 103 128 5915 56. . 178 690 777 301 394 359 690 777 232 796 863 704 000 289 579 574 268 493 000 6:24 2O6 656 ,567 079 8OO 656 000 ooo 85 626 LSRH,bDT TENS.bDT PHND,SAN PEFeCRC TNPH.CNb RCFT.CNb NPOR.SAN THORoKAb URANoAbP CGR.AbP W3NG.NGT HTEN,NGT SP.AIT CDBR.PHA CIMP.PHA CMVRePHA ILM.DTE ~IRD,DTE SPbU.ST~ TENSe TE DT.b$$ HT ,bSS PEFebDT LUebDT ~S2.bDT bSRH,LDT TENS,bDT PHND,'SAN PEr,CRC TNPHeCNb RCFT,CNL T£NS~CNL NPOReSAN THOReKAb URAN,ALP CGR.·AbP W3NG.NGT HT~NeNGT SP,AXT CDER.PHA CI~P,PHA CMVR,PHA CILM,DTE IIRD,DTE SFLUeDTE TENSeDTE DT.b$$ GR.LSS HT~NeLSS 2.26{ 590 ,00 31 30 590 000 3 345 8,675 2 230 81 823 4~ 522 536.777 '-66 000 {. O0 549 1.05 023 1{.2 126 108 224 83 579 0 5 1 O, 0~0 6865 ,600 9455,458 59,667 '916,1' '591'S.000 .29,'364 9 660 2 145 83 812 .50 3'70 580 873 -62 438 154 465 I59 136 170 640~ 288 000 83 044 62 4 8 927 ,e LIS Tape Verification Listinq $chlUmoerger AlasKa Computing Center 27-APR-J992 08:57 PAGE~ i4 DPHI.LDT QL~.~DT bSHV.LDT bURH.LDT NT£M,LDT PFDC.SAN DRHO CRC TNRA CNb ES CNL TNpH SAN POTR KAL THOR ALP CS NGT W4NGeNGT MRES.NGT HTEN,AXT DEPT. IDER,PHA IMP~,PHA 'IMYR,PHA IbNeDTE IIXDeDTE SP.,DTE MTEM.DTE DTL,'bSS TENS,LSS OhS.bDT bDT b RH bDT MTEM bDT PFDC SAN DRHO CRC TNRA CNL ~RES TNPH SAN POTA.KAL THOR ALP NGT' MAES NGT HTEN AlT DEPT,.. IDER,PHA IMPH,PHA I~VR~PHA 'ILMeDTE IIXD,DTE SP.DTE 6.125 0.003 113.687 125~,56 168,077 5.276 '0,004 2.968 2405.495 ,635 3 .14~ 2.591 lO,54X 1835,937 14,8~5 69 . 59 1020~.~00 . 38 6,992 7,199 6 904 i4 719 164 3 0 6 809 -0 O02 52O 2,543 .!65,838 ,486 0,643 31.686 2'669 9,557 i84 . 38 4.233 0.643 705,514 iO00~..O00 ,255 6,089 , 006 ,962 '1...688 RHOBebD? 2.549 DRHO,bDT -0,005 PEr,bDT 4,536 OSS.LDT ~.01! LS.LDT 222.891 LU.LDT 218,407 bZTH.bDT 4 .670 SS1.LBT 190.502 $S2.bOT 245,102 CALl.bDT i2.8~9 SG .bDT I ,83 :Ea ,bDT 5845.000 MAES,bDT ~,635 ~TE~.bDT 5 ~.42i PHND.SAN 5.236 MRHO,CRC .564 HO .CRC .56 P£F.CRC 4.624 URAN, bP : NPOR.CNb CFTC.CNL MTEM.CNL NPHX.SAN SGR.KAb POTA,ALP W1NG,NGT W5NG,NGT MTEM,NGT TENS,AlT IDP.PHA DVR,PHA C~ER.PHA CZLD,DTE IDOFeDTE IIRMeDTE MR .DIE DTLNeLSS ~TEMeLSS RHOB bDT OSS bDT bXTH bDT SSHV bDT CALl bDT MRES bDT NRHO.,CRC NPH~,CNb NPOR,.CNL CFTC,CNL MTEM,CNL NPH.X,SAN SGR,KAL POTA.,AbD WlNG..NGT WLNG:.NGT MTE~,NGT TENS.AlT CIDP',PHA CDVR.,PHA CM£R.PHA CIbD,D?E ZDOF,DTE IIRM,DTE GR,DTE RTNR.CNb RCNT.CNb 794.951 SGR.C~L 168.077 HT£~.CNL 3~.14! URAN,KAb 7 .835 CGR.KAL .495 SGR,AbP 25 .085 W2NG.NGT 8.~66 TENS.NGT 68. 77 GR.AIT 635,000 i4o: 44,354 0,000 136.716 6~.00 82.025 164,[53 538 0~4 4 0,643 165 838 6035 000 62 97 164 60 0 O0 8 80 '1~4.3b9 .772 5845,000 HTEN,NGT 535.42~ 63.366 SP.AIT IDPH.PHA IDVR.PHA IMER.PHA ILD.DTE TMOF.DTE IlXM,DTE CRLS,DTE HTEN,DTE 10 DTLF bSS 82 MRES~LSS 0 DRHO,LDT 0 bS,LDT 231 SS 199 $1R~'bDT ,bDT 2 SGR bDT 74 RHO6,CRC RTNR,CNb 3 RCNT,CNb 25~ SGR,CNL HTEN.CNb 535 URAN.KAb 1 CGReKAb SGR,ALP 10 W2NG,NGT TENS,NGT 558 GR,'AIT 'IDPH.PHA IDVR,PHA IMER.PHA ILD,DTE IMOF,DTE IIX~.DTE CALSeDTE 7.02~ CDER..PHA ~,'~8 CIMP,PHA . 2i CMVR,PHA 6,927 CILM,DTE 0 000 IIRD DTE 731 SPbU DTE 975 TENS DTE 450 DT LSS 935 G~ bSS 634 HTE bSS 009 PEr bDT 743 LU LOT · 02 SS2,LDT ~94 bSRHLDT 163 TENS.bDT 694 PHND SAN :~60 PE~.CRC 89 TNP .CNL RCFT.CNL 39~ TENS,CNL NPOR,'SAN 971 THOR,KAL ,778 URAN,AbP ..:~93 CGR,AbP 9 W3NG,.,NGT 0 'HTEN,NGT 61,084 SD.AlT 136 4t4 25~ ¢53 oo , 2,5 2 85,,0!6 6,~ CDER,PHA CI,~P,'PHA :ooa 6,~91 CXLM.DTE O, O0 I~RD,DTE 12.345 SFLU,DTE 12.883 TENS,DTE .$c.blUm~erger Alas~:a Computin~ Center MT~M.DTE OTb,ESS TENS,bSS DPHI,gDT O~$,LDT ~SHV,gDT gURH,bDT NTE~,LDT PFDC. AN C~TC..CN~ ~RES CNb TNPH.S~N POTA KAL THOR AbP CS NGT N4N~ NGT ~RE$ NGT HT£N A~T DEPT, IDERtPHA IM?HtPHA IMVR,PHA Ib~,DTE IIXD,DTE SP.DTE MTEM DTE DTb ESS TE~$ LSS DPH! bDT ~URH,bDT ~TE~tbDT PrDC,SAN TNRA,CNg CNTC,CNb ~RES,CNL TNPH,SAN PO?A,KAb THOR.,~bP _C~,NGT W4NG,NGT MRESeNGT HTENeAIT D~PT,~HA IDER, IMPH,PHA IMYRePHA 161.856 MR£S.DTE 82,~ DTgN,bSS , MTEM,bSS 1136' blTH. . 8SHV.gDT , NRES.gDT , NPHI.CNg 86 NPOR.CNg crTc.c. 0.655 33,985 NPH~,SAN 2,608 SGR,KAb 9,505 POTA,AbP , 97 W5NG,NGT , 14 TENS,AlT 9800,000 CIDPiPHA 5.932 CDVR,,PHA 5,680 CMER,PHA , IDOF,DTE 19,077 IIR~,DTE '112,563 GR,DTE 159,~42 MRES.,DTE 84. O0 DTL, N,b$S 6205,~00 MTE~.bSS . 74 6 RHOB.bDT OSS.LDT ,.138 $8HVebDT ! 1.555 CAbI.'bDT 161.~? MRES.gDT 4. NRHO.CR¢ 0..004 3,.153 NPOR.CNg 2435,627 CFTC,CNb 0e666 3~.166 NPHI,SAN SGR',KAg 18,' 35 WING.eNGT 698.666 ~TE .:NGT .615 T~NSeAIT 9600.000 CIDP PHI 6.036 CDVR:P A ,.9~8 C~ER.PHA ~.5 2 ClbD,DTE 27-APR-1992 09157 ~.~ HTEN,DTE ~ · - DTbF,gSS 4 0 6 SSI,gDT 1334.555 $1RH.hDT 12.906 SGR.gDT 31,797 RCNT,CNb 719.137 SGR.¢Nb 163,473 HTEN.CNg 33.985 URAN.KAb 77,262 CGR.KAb 24~,506 SGR,ABP 5.2 TENS.NGT 163.~3 GR.AIT 5995..0 INEE,PHA lbD.DTE I 0.00~ IMOF,DTE 74. 3 CAbS,DTE 1 DTLF,gSS 550 DRHO,gDT 4~.017 LS.LDT 1333. 0 S1RH.gDT 14.549 SGR.~DT 31 RCNT. b 81, CGR.KAg SGR P . 86 GR,A~T 58 0,000 1 .9 8 IDVR,PHA I~.378 I~ER.PHA .143 IbD.DTE 898 0 266 211 77 518 2344 77 518 2 62 105 123 5545 62 5 5 5 5 0 13 13 922 84 0 0 225 194 2 81 529 2 3 2605. 529. 1. 70. 121. 141.. 5420. 80. .743 .677 .647 026 679 107 354 262 816 .479 .464 460 262 8~6 636 O37 629 .941 .000 .262 849 682 .779 000 676 658 658 002 510 538 522 577 568 57 949 262 DT,LSS GR.LSS HTEN.LSS P£F,gDT LU.bDT SS2.LDT LSRH.LDT TENS.bDT PHND.SAN PEr,CRC T~PH.CNb RCFT.CNg TENS.CNg NPOR.SAN THOReKAg W3NG,NGT HTENeNGT SP.AIT CDE~ PHA CIM PHA CHYR PHA SrgU DTE TENS DTE DT LSS G~ HTEN,gSS PEr.bDT .LOT gSRH.LDT TENS.gDT P~ND.SAN PEr,CRC TNPH.CNL RCFT,CN5 TENS.CN~ NPOR,SAN THOR,EA URAN,Ab CGR.AbP W3NG.NGT HTENeN T SP.A~T CDER..PHA Cl~P,PHR CHVR, P.HA CIgM,DTE PAGE= 15 83,695 6 369 74 .5.873 261.148 26~.438 5545 O0 10,337 7 33 33,360 9,594 7~'009 ,592 5 ,907 5.11,816 '60,375 16 8 71.628 248 0 5,2o o 4 8 I ..ooo ,,989 577 5~ 750 165" 85. 168,$79 179. 31 167.,~ 50 :0 hfs Tape Ve IbM,DTE IIXO,DT£ MTEM,DT£ DTb. LSS DPHI,bDT OhS,bDT bb,bD? bSHV,bD? LURH,LDT M?EM,bD? PFDC,$AN DRHO,CRC TNRA,CNb CHTC,CNb MRE$.CN~ TNPH,$AN POT~,KA~ THOR,.AbP CS,NGT W4NG,NGT MRE$,NGT HTEN,AXT DEPT,pHA IDZR, IMPH,PHA IMVR,PHA IIXD,DTE 8P,DTE MTEM,DTE .DT TEN~*LS$ DPHILDT OL$ bDT Lb bDT LSHV t, DT PFD~ SAN DRH CRC TNRA CNb CNTC CNt, MR£$ CNL PO?A KAL THOR ALP CS NGT W4NG NGT MRES NGT HTEN'AXT rJAitcatlon Listing r laska Computing Center 5,955 18.05g 't15.158 157,364 82,334 6075,000 8,562 1;~ 'oo8 .065 1251,055 ,491 15 ,905 .487 0,031 3,145 2585.725 0.681 32,592 2,626 ,842 9.881. 0,681 710,404 IDOF.DTE IIRM.DTE GR.DTE MRE$,DTE DTLN,b$S MTEMeb$$ RHO$.bDT OSS.bDT LITH,bDT $SHV.LDT CALX.bDT MRES.bDT NRHO,CRC NPHX CNL NPOR CNL CFTC CNL MT£M CNL NPHI SAN SGR KAL POTA,ALP W1NG,NGT W5NG,NGT MTEM.NGT TEN$,AXT 5 5 607~ 12 -0 2 156 12 0 2455 0 1891 1. O 0 704 .000 .844 .564 ,305 : ot 80 :' ½1 ,008 ,000 .647 ,031 ,991 ,655 ,407 ,429 .122 .039 ,966 .328 695 :135 396 623 5 2 695 1¢8 CIDP,PHA CDV'R,PHA CMER,.PHA ClI, D,DTE IDQF,DTE IIRM,,DTE GR,DTE MRES,DTE DTLN,LS3 RHOB,LDT. OS$,LDT LITH,LDT $SHV,LDT CALZ,bDT MRE$..LDT NPHZ. NPOR CNb CFTC CNL MTEM CNL NPHX SAN SGR KAL POTA. ALP W NOT MTEM NGT TENS AlT 27'APR-1992 08157 0.000 IMQF.DTE 158.261 IIX~.DTE 66.309 CAI.S.DTE 0,669 HTEN,DTE 81'.14i DTLF.bSS 157.364 MRES.bS$ 2.509 DRHO.bDT .029 LS.b.DT 5 .898 $$1.bDT 1332.689 81RH.bDT 14.765 SGR.LDT 0,681 HTEN.bDT 2.526 RHOO,CRC 3~.78t RTN.?.CNb 845.218 SCR.CNb 158.905 HTE~.C~L 32.592 URAN.KAL 75.726 CGR.KA~ .716 SGR,AbP 22 .249 W2NG,NGT 8.893 TENS,NGT 5 .000 182.110 169.09! 0.000 174.295 ?0 ?42 05 228 2 441 0 0.35 5 955 3 987 0 695 450 3 81~ 299 6'36 156 429 7~ 135 ~00 8 457 156 429 5640 000 IDPH,PHA IDVR,PHA IMER.PHA ILD,DTE IMOF,DTE IIX~,DTE CALS,.DTE HTEN,DTE DTLF,L$$ MRES.LS$ DRHO,L, DT LS,LDT SSI.LDT $iRH,LDT SGR,LDT HTEN,LDT RHOB,CRC RTNR.CNL RCNT.CNL SGR,CNL HTEN CNL URAN:KAL CGR,KAL SGR,AbP W2NG.NGT TENS.NGT GR.AXT ! ! 91 7 25 20 7 52 266 7 52 6 11 il 550 6 1 88 8 28 53 53 5 10 12 53*/ 6 0..~00 2. 71 3,939 . 80 0,669 0.030 2 394 5 726 9 ] 295 7 216 5 6 2 ~77 1 97 7 583 1 660 0,000 6,089 5.973 5.656 5.491 5.914 2. 3 300 3 588 2 836 0 682 , ½o 2 450 3 140 ~09 ~ 119 156 ~ 634 0 507 5 000 7 535 IIRD.DTE 3FLU,DT£ TENS.DTE DT,LSS GR.LS$ HTEN.LS$ PEr.bDT bU.bOT 8S2.LDT ~DT PRND.SAN PEF.CRC TNPH.CNb RCFT.CNb TENS.CNL NPOR.SAN THOR,KAL URAN.ALP CGR.ALP W3NG,NGT HTEN.NGT SP.AIT CDER,PHA CIMP.PH.A CMVRePHA CILM,DTE IIRD,DTE SFLU.DTE TEN$.ETE DT. SS GR,LSS HTEN,LSS PEr.hD. LU,LD? SS2.E, DT LSRH.LDT TENS,LDT PHND,$AN PEr. CRC TNPH,CNL RCFT.CNL TENS,CNL NPDR,'SAN THOR,KAb' URANe.AbP CGR,ALP W3NG,NGT HTEN.NGT SP,AIT PAGEI 16 474 607ii000 8 228 6 309 91 140 4.189 243.558 265,954 550~ .479 .000 7,487 -5,369 714 '836 .54! .000 550 3~;661 5 ~5~0 ,04! ,455 529,85 "55,.06~ '17t.,215 179,935 188,516 X85,159 148,459 ,5~'299 6070,000 84.919 70.342 .883,586 '5,406' ,275,391 .279+181 .... 2,.397 5375,000 '5,3'32 '3~,46~ 7.84'103 5.375,000 ' 35,564 .9~527 bis Tape Verification Llstinq schlumberger Alaska Computin.q Center DEPT, IDER, IMVR, IbM, IIXD. OTb, TENSe DPHXe LURH MTEM DRHO TNRA CNTC MRES TNPN POTA THOR MRES DEPT IMPH DTL TENS DPH! MTEM pro(: DRHO TNRA TNpH POTA THOR CS PHA PHA PHA DTE DTE DTE DTE bSS LSS LOT bDT bDT LOT LOT bDT SAN CRC CNL CNb SAN KAL ALP NGT NGT NGT AlT .PHA PHA PHA DTE DTE DTE DTE bDT bDT .bDT bDT LOT LOT KAl,, NGT 9200,000 5.464 5.093 5.163 5.098 20.378 'li7,~25 153, 65 8 663 o :ooo 11,461 -0.032 136.656 1250,550 2,442 153,894 10,470 0,027 339 36:161 2 921 10 833 1880 696 5 291 694 9000,000 5,447 5,085 5,170 5,005 i9,894 -121,563 1~,907 .618 603~0000 ~0'~01 131, 125~,953 ,464 15 '. ~0 O,Oll 227~ '253 ,843 0,722 .366 3~,499 188~ '.392 ,204 CIDP~PHA CDVRePHA CMER,PHA CXLD.DTE IDQF,DTE XXRM,DTE GR.,DTE MRESeDTE DTLN,bSS MTEM,LS$ RHOB,bDT OSSeLDT LXTH,LDT SSHV,LDT CALl,bDT MRES, LDT NRHO,CRC NPHI,CNL NPOR,CNb CFTC.CNL MTEM,CN'L NPHI,SAN SGR,KAL PO?A,ALP WtNG,NGT WSNG,NGT MTEM.NGT TENS,AlT CIDP,PHA CDVR.PHA CMER,PHA CILD.DTE IDOF,DTE IIRM.DTE GR,DTE MRES, DTE DTLN.LSS MTEM, LSS RHOBZbDT .LOT SSHV bDT CALl bDT MRES bDT NRHO CRC NPHX CNb NPOR CNL CFTC CNL ~TEM CNL NPHI SAN SGR KAL POTA ALP WING NGT 27-APR-1992 08157 182.~4 IDPH.PHA 181. 0 IDVR.PHA 196.4t2 IMER.PHA 184.916 ILD.DTE 0,000 ~OF.DTE 184.523 IIXM.DTE 67,477 CALS,DTE 0,696 HTEN.DTE 87.~2 DTLF.LSS 57. 6 SSI,bDT 1331.148 SIRI{.LDT 12.690 SGR.LDT 0.711 HTEN.GDT 2.477 RHOB,CRC 36.019 RTNR,CNL 33.315 RCNT.CNL 716.984 SGR.CNL 1~,894 HTEN.CNL .163 URAN.KAL · 78.356 CGR.KAL 2.760 SGR.ALP 269.841 W2NG.NGT 1.407 TENS.NGT ~ .894 GR.AIT 5 5.000 184,204 IDPH,PH~ ~,541 IDVR.PHA ~ ,891 IMER.PHA 186,576 ILD*DTE 0,000 IMOF,DTE 187,891 IIXM.DTE 63,047 CALS,DTE 0,706 HTEN,DTE 86,606 DTt..F,bS5 . DRHO.LDT 5 , ~ SSI.bDT ,025 SGR.bDT o 3 3 RTNR,CNb o6 4 RCNT,CNL 69~.722 SGR,CNb 15 .315 HTEN,C'NL 3~,366 [IRAN,KAL 7 .926 CGR.KAL 2,767 SGR.AbP 250.794 W2NG.NGT 5.483 5.522 5.091 5.408 0 000 14:441 12.533 .762 0.696 0 023 267 283 209 962 2 365 78 356 54O 019 477 '512 . 245~ 144 7 56 540 019 1 450 69 ,~ 114 286 5265 000 68 664 5 429 5 o° 13 174 14 57 872 236 86 276 0 258 ' 4 5O5 120 9 CDER.PHA CIMP.PHA CMVR,PHA CXLM.DTE IIRD,DTE SPLU.DTE TENS.DTE DT.GS$ GR.LSS HT£N,LSS PEF,LDT ~U,LDT SS2,LDT bSRH,LDT TENS.bDT PHND,SAN PEr. CRC TNPH.CNL RCFTeCNL TENS,CNL NPOR,SAN THOR,KAb URAN,AbP (:GR,AbP W3NG.NGT HTEN,NGT SP.AXT CDBR,PHA CI~ PHA SF~U,DT~ TENS.DTE DT.L GR.LIS HTEN,LSS P~F,LDT bU,bOT SS2.LDT LSRH LDT TENS bDT P.HN9 SAN PEF CRC TNPH CNL RCrT CNb TENS.INL NPOR.' AN THOR,KA~ URAN,AbP CGR W3NG*~bp , GT PAGEI 17 196. 1 170 16}.151 5, '°II:. oo 900, 16 52 271,'225 5265 '~38 o000 '~0,~?0 3 352 690,~8 5265, 0 .35,068 10,909 81,3 40e.~12 '56,250 183 587 196 644 ~9. 431 1:9~ 800 .16~ 560 895 6035 000 · 8 676 6~ 047 87'i 236 : 894 253 .267 32 ,2, 461 5195 000 ,~ 8i0 956 .093 5195 O00 36 890 11 056 3 066 93 36O 47 619 LiS TeDe Verification btstin~ $chlu'mberqer Alaska Computtnq Center ~IRES,NGT . 22 MTF. M.NGT HTEN.AIT 694,069 TENS.AlT DEPT. IDER.PHA IMPH,PHA IMVR.PHA IbM.DTE IIXD,DTE SP.DTE MTEM.DTE DPHI,bDT OhS.bDT bL,LDT bSHVeLDT bURHebDT ~?EM,bDT PrOC,SAN DRHOeCRC TNRA,CNL CNTC CNb MRES tnb TNPH SAN POTA KAL THOR ALP C$ NGT W4NG,NGT MRES,NGT HTEN,AIT DEPT IDER PHA IMPH PHA .!MYR PHA IbM DTE IIXD 'DTE DPHZ,LDT OLS.LDT Lb,bDT bSHV,LDT LURH,LDT MTEMebDT PrOC.SAN DRHOoCRC TNRA,CNL CNTC.CNL MRES,CNL TNPH~'SAN 8800.000 7.070 6,924 6,862 6,667 15 84 148,655 59481 '910 .000 9,758 -0 003 128 639 148 802 8 842 0 005 279~ 814 86 0 1 i 779 193 082 4'~28 O, 36 698,465 6oo; oo 5.. 81 5, !8 6 ~27 "119.438 146.807 5855. 0 .i6 054 -0 034 15 814 1.25~ 648 2 367 [46 869 15 525 0 025 3,168 2166.~7! O. 46 36,343 CLOP, CDVR, CMER, CILD. IOOF. IIRM. GR. MRES. DTbN, MTEM. RHOB. QSS LIT~ SSHV CALX MRE$ NRHO NPHX NPOR CFTC NPHI SGR POTA W1NG WbNG MTEM TEN& CXDP, CDVR-, CMER. CXLD, IDQF, IIRM GR MRES DTbN MTEM: R~OB, QS$ LITH SSHV CALl MRE$ .NRHO, NPHX NPOR~ CFTC. MTEH. NPHI PHA PHA PHA DTE DTE DTE DTE DTE LS8 bDT bDT bDT bDT bDT LOT CRC CNb CNL SAN KAL NGT N T PHA PHA PHA DTE DTE DTE DTE DTE bBS bDT bDT LOT bDT bDT bDT 27-APR-!992 08:57 13.757 TENS.NGT 151.315 GR,AIT 5620.000 140.653 IDPH.PHA ~42.~57 IDVR.PHA 44, 46 IME~.PHA 14~.~31 ILD.DTE 141: ~ IMQF.DTE IIXM,DTE 57. 11 CALS.DTE 0.720 HTEN.DTE 57. 0 SSI.bDT I 814 SGR,LDT 0.736 HTS,,bDT ,509 RHOB,CRC 27, 7 RCNT,CNL 1 27, 4 URAN,KAb 65. 0 CGR,KAL 2 W2NG,NGT 540 00~ ' 8~ 949 146 807 0 3 58 39 . 5 .746 35:447 679.3~8 146,869 36,343 IDPH,PHA IDVR,PHA IMER,.PHA ILO.,DTE IMOF.DTE IIXM.DTE CAbS OTE HTEN:DTE DTbF.LSS MRES.bSS DRHO.bDT bS,bDT SSl,bDT S1RH.bDT SGR,LDT HTEN,bDT RHOB.CRC RTNR,CNb RCNT.CNb SGR.CNb HTEN,CNb U~AN.KAb 7~.241 7.110 7.025 6.909 6.933 .000 1 770 889.~34 82. 03 0 ~20 O: 04 49 405 99:463 2.467 65.040 523°389 2.504 3 064 2913 195 65 040 523 389 I 078 58 811 98 005 84 567 ,510 0 00~ 10 84 12 488 878 074 8!1943 729 302 936 70 397 564 837 2 394 3 333 2269 206 70 397 564 837 2 531 HTEN.NGT SP,AXT CDER.PHA CIMP.PHA CMVR.PHA CILM.DTE IIRD.DTE SFbU.DTE TENS.DTE DT,bSS GR,LSS HTEN.LSS PEr,bDT S .bDT bSRH.LDT TENS.LOT PH~Do&AN PEr. CRC TNPH.~NL RCFT. Nb TENS,CNL NPOR.&AN THOR KAb URAN ALP BP AlT DER PHA IMP PHA CMVR PHA CILM DTE IIRDDTE SFLU DT.E TENS DTE DT USS GR.eL$S HTEN.b$S $$2.LDT bSRH bDT TENS bDT PHND SAN PEr CRC TNPH CNb RCFT CNL TENS CNL NPOR SAN THOR KAL PAGEI 18 ~05,848 55,250 14t,441 145,~ 150.004 128.006 6., 22 5945,~00 85, 04 889,,9 3.863 24~,530 259.,.244 2.485 5115,000 8,570 4,287 27,174 985,287 51t5,000 27.904' 9,689 i,'256 .86,,~7 .'36~998 194.5 2 190,5 6 185,681 152.,442 .5',363 5855,000 '90,9t~ .67.;4 280.,:8 2~ 15, ~95 4 637 457 ..000 5005 .781 · 3~..294 Tape Verification LLst/nq 'Scl~lumberqer AlaSka Computlnq Center 2T-APR-t992 08=57 8400.000 4.223 4.035 4.206 3,927 28,410 ,963 90.48! 5795,000 17,615 '0.033 165.936 1250,397 .338 14 ,325 1~,097 .028 3,454 2099,608 0,758 41.~38 1,786 931 6 363 0 7 8 694 CIDP, CDVR. CMER, ClbD. IDQF, GR, MRES, DTLN, MTEN, RHOB, OSS. LITH, SSHV, CAb! MRE$ NRHO NPHI, NPOR CFTC NTEM NPHI SGR POTA WING., W5NG., MTEM., TENS. PHA PHA PHA DTE DTE DTE DTE DTE bSS bSS LOT bDT bDT bDT bDT bDT CRC CNb .CNL Nb SAN KAL ALP NGT NGT NGT A~T DEPT, IDER,PHA IMPH,PHA IMVR,PHA ILM,DTE IIXD.DTE SP.DTE MTEM,DTE DTb,bSS TENS,LSS DPHI.LDT OhS.bDT Lb,bDT LSHV.LDT bURH.bD? MTEM bDT PFDC SAN DRHO CRC TNRA CNb CNTC CNL ~RES,CNb TNPH,SAN POTR.,KAb THOR.ALP MAES N T HTEN AlT 8200.000 ~.1.49 .,153 3,096 3,249 3~.614 '12 ,375 43,~83 191,32~ ,000 - ~021 146,280 1250,541 2,414 1~,476 ,968 0,006 3,244 CIDP. CDVR. CMER.. CILD, ~DQF, ~IRH., DTbN, MTEM, RHOB, QSS. blTH, SSHV. CALl. ~RES, NRHD, NPHX, NPOR, PHA PHA PHA DTE DTE DTE DTE DTE bDT bDT bDT bDT bDT bDT CRC CNb DEPT ~MPH.PHA IMVR PHR ~bM DTE IIXD DTE SP DTE MTEM DTE DTL bSS T£ OLS bDT bb bDT ~,V bDT RH LOT PFDC.SAN DRHO.CRC TNRA.CNb 240.003 230.759 243.424 243.487 0.000 238.563 58,762 0,739 90.527 144.963 2.359 0.040 67.04I .1328.034 12,776 0.758 368 3~ 085 3 61~ 528 248 62.979 2.~67 199.364 6.363 ,000 324.58½ 3 4 300 ~ 3 78 0 000 87 264 0 , 09 5~.024 ' 1½ 0~771 .299 36.276 IDPH.PHA IDVR.PHA IM£R,PHA ILD.DTE IMOF,DTE IIXM.DTE CALS,DTE HTEN,DTE DTLF,LSS MRESeLSS DRHO.LDT LSeLDT SSI.LOT S1RH,LOT SGR.LDT HTEN.bDT RHOB,CRC RTNR,CNb RCNTeCN~ SGReCNL HTEN.CNb URAN.KA5 CGR,KAb SGR,ALP W2NG.NGT TENS.NGT GR.AIT IDPH,PHA IDVR.PHA IMER,PHA ILD,OTE IMOF,DTE IIXM,DTE CAbS,DTE HTEN,DTE DTLF.LSS ~RES,bSS D.RHO.bDT LS,LDT SSI,bDT S1RH.LDT SGR.LDT HTEN.LDT RHOB,CRC RTNR.CNb RCNTeCN5 4 4 334 4 4 ~08 07 0 000 17 723 12 727 889 959 90 414 0 739 0 030 319 890 218 474 2 244 62 979 545 993 368 ~',.603 2199'~65 545.993 1.336 55.~62 92. 19 96.50! 4875.~00 6~. 41 ~ 085 3 o gg8 282. 498 205 32~ 2 37 77 897 488 594 2 420 3 URAN.ALP CGR.ALP W3NG.NGT HTEN.NGT SP.AIT CDER.PHA CIMP.PHA C~VR.PHA CILM.DTE IIRD.DTE SFbU.D?E TENS.OTB DT.LSS GR.LSS HTEN.LSS PEr.bDT LU.LDT SS2.LDT LSRH.LDT TENS bDT PHND SAN PEr CRC TNPH CNL RCFT TENS Nb NPOR SAN THOR KAL URAN ALP CGR ALP W3NG NGT HTEN NGT SP AlT .CDER PHA CXMP PHA CMVR PHA CILM DTE IIRD DTE SFbU DTE TENS DTE PT bSS GR bSS HTEN bSS PEr LOT LU b T SS2 bSRH bDT TENS bDT PHND SAN PEr CRC TNPH CNb RCFT CNL PAGEI .19 2,848 69.8:~0 28.541 564,837 -59'000 236. 23 247.,~49 237,765 1254,~16 208, 76 5795, 0 86,867 762 589 959 88 ..34 995 545 993 ,5~ 000 3t7, 41 323,0 307,806 250,,112 77 ~9~:398 383 ,0 ,bis Tape Vertf/cat/on bLstlng SchlumDerqer AlasKa Computing Center CNT¢.CNL 2141,849 CFTC,CNL MRES,CNb 0,~71 MTEM.~Nh TNPH.SAN 38,551 NPHI. AN POTA,KAb 2,307 SGR.KRb THOR.AbP 11.540 POTA.AbP CS.NGT 1824.011 NING.NGT W4NG.NGT 5,929 N5NG,NGT MRES.NGT 0.771 MTEM.NGT HTEN,AIT 6?8,806 TENSeAIT DEFT, IDER,PHR INVR,PHA IIXD,DTE SP.DTE MTE~,DTE DTL,bS$ TENS.bSS DPHI.bD? .~07 bSHV.bD? bURH,bD? ORHO,CRC TNRA.CNb CNTC.~Nb MRES, Nb TNpH SRN PO?R KAL THOR AbP C8 NGT W4NG NGT MRES NGT HTEN,.RIT 8000.000 7,472 6 938 '18 609 -149 188 141 273 83 686 5365,000 14,288 1 ,'712 1250.514 I ,68 -0 006 253~ ?22 342' 0 981 .29 078 I 890 182~ '378 ,529 683:118 CIDP.PHA CDVR PHA CMER FHA ¢IbD DTE IDQF DTE IIRM DTE GR.DTE MRES.DTE DTbNebSS MTEM.bSS RHOB.bDT OSS,bDT kITH.bDT ,bDT MRE$,bDT NRHO.CRC NPHI CHh NPOR CNb MTEM SG~ SAN KAb POTA,AbP W1NG,NGT ~bNG.NGT TENS.,RIT DEPT, IDER,PH.A IMPH,PHA IMVR,PHA ILMeDT£ IIXD,DTE SP,DTE MTEM,DTE DT.b,bSS TENS.bSS DPHI,bDT OhS,bDT Lb,bDT LSHV,LDT bURH,bDT MTEM.LDT 7800.000 4.410 ,02~ ~84 4,970 ,438 ~39,194 9 539~ .267 ,000 19,81~ '0,021 16~.543 125 ,278 131''355 ,082 CID 'PHA CDV~:PHA ¢ih~ 'PHA ,DTE IDQF.DTE IIRM.DTE GR.DTE MRE$,DTE DTbN,LSS MTEMebSS RHOB.bDT QSS,bDT kITH.bDT SSHVebDT CALl.bDT MRES..bDT 27-APR-J992 08:57 648.~8 SG~.CNb 1~. 6 ~TEN,CNL ,551 URAN,KAb 77.897 CGR.KAL 231.176 SGR,ALP .190 W2NG.NGT 17.787 TENS,NGT 14~,476 GR.AIT 5230.000 165.309 1 , 48 167',283 306 *000 .056 153,i52 0,7761 87, 80 4~ .033 ,59 9 4 0 6 870 O78 56 357 181 588 322 1404 237 116 5100,000 . 79 Oo 93, 99 139,~94 2.3~3 5 o6 132 ,7 12.171 0.797 IDPH,PHA IDVR.PHA IMER.PHA ILD,DTE IMOF,DTE IIXM,OTE ~AbS,DTE HTEN,DTE DTLFebSS MRES,BSS DRHO,bDT bSeLDT SSI.bDT Sl~H.bOT S R.LDT HTEN LDT RHOB:CRC RTN~.~NL RCN , N~ SGR,CNb HTEN.CNb URAN,KAb CGR,KAb SGR,ALP W2NG,NGT TENSeNGT GR.AIT IDPH,PHA IDVR,PHA IMZR.PHA ILD,DTE IMQF,DTE IIXM,DTE C.AbS,DTE HTEN,DTE DTLF,LSS MRES,LSS DRHO,bDT bS,LDT SSI.LDT SiRH,bDT SGR,bDT HTEN,[,DT 48 2 61 102 121 4790 70 6 6 7 5 0 9 12 866 84 0 -0 270 197 2 56 511 267] 56 463~ 4 897 TENS.CNL 594 NPOR.SRN 820 THOR.KAL 607 URAN ALP 542 W3NG, GT 000 HTEN,NGT 447 SP.AIT .049 .526 .297 .978 .000 .430 .174 .91! .867 7 1 479 860 T~NS 917 PHND 24 per RCrT 357 TENS 217 NPOR 32 THOR 465 URAN 8P CDER.PHA IM~,PHA ~MV .PHA CIbM.DTE IIRD,DTE SFL~,DTE TEN ,DTE DT.LSS GR.bSS HTEN.LSS PEr.bDT .bDT ,bDT ,bDT .SAN :CRC .KAL ALP NGT NGT A2~ 4 i~ COBR 4: C M. 4,913 CMVR 4.461 CIbN 0,000 IIRD 12. TENS 86i.548 DT 94 ~4 GR O: 71 HTfN -0,~10 PEr 312. 84 bU 2. 2 bSRH 61,309 TENS. 482.317 PHND, PHA PHA DTE DTE DTE bSS bS8 bDT SAN PAGEI 20 10,71 2.57 36,561 488,594 '"60.313 156,699 139.079 133,839 144,137 147.633 000 84 633 53 152 866 9! ! ,,7 709 26t. 534 254 428 4 0 .2 0~0 ooo II 206'158 20i 4 193 8 ,,6 6 48 54! 29 . 4650 0 19 2. .LIS Tape Verification Listing SchlumuerqerAlasKa Computing Center 27-RPR-1992 09:57 PAGEI .21 PFDC, DRHO, TNRA CNTC MRES TNPH POTA THOR CS N4NG. MRES. NTEN. SAN ~9.284 CRC 0.0~1 CNL 3.3 2 CNL 2365.441 CNb 0,797 SAN 37.981 KAL 2.163 ALP 7.402 NGT {867.839 NGT 5,297 NGT 0,797 AlT 693.193 NPOR.CNL 6.392 RCNT.CN~ 24~ . RCFT.CNL 667 CFTC.CNb ~.953 SGR.CN ~.~? TENS.CNL 4650 M?EM.CNb .082 HTEN.CN~ 40 . NPOR.$AN . W1NG,NGT 19 ·797 W2NG,NG'r 10 . W3NG.NGT . WSNG.NGT ~ ~34 TBNS.NGT 4650,000 HTEN."GT 48~ MTEM,NGT 13 : 82 GR,AIT 46.514 SP.AIT -7 TEN$.AIT 5060,000 000 1 3 783 DEPT. IDER. IMVR. TENS DPH! bb bSHV LURH MTEM DRHO TNRA CNT¢ TNPH PO?A THOR CS W4NG MRE8 HTEN 7600. PHA PHA 4. PHA 4. DTE 4 DTE 28 DTE -132 DTE 136 LSS 96 ESS 5190 bDT 21 bDT -0 bDT 183 bDT 1250 bDT 1 SAN ' CRC 0 CNL ,0 SAN 39 KAL ALP . NOT 1804 NGT O, NOT O. AlT 69,4, 000 197 292 13! 114 822 563 992 270 000 298 046 681 659 276 643 479 O37 334 8O6 39i 535 4O6 358 989 8O6 379 CIDP. CDVR. CMER. CILD, IDQF. IIRM, GR, MRE$. DTLN. MTEH. RHOB. OSS, LITH, SSHV. CALX, ~RES. NRHO, NPHX, NPOR. CFTC, MTEM. NPHZ. SGR POTA WiNG ws~o HTEM TENS, PHA PHA PHA DTE DTE DTE DTE DTE bDT bDT bDT bDT LOT bDT CRC CNL CNb CNL CNb SAN KAL ALP NGT NGT NGT A:I:? .001 23 24) '464 .123 22~ '000 .915 62.777 0.782 94.183 136.992 2 299 0 046 13 9'95 863 0 8O6 40 397 613 638 135 643 39 39! 12! 7) 422 243 323 946 .55 000 IDPH IDVR ILD IMQF CAbS HTEN DTLF MRES DRHO b$ 881 $1RH H?BN RHOB RTNR RCNT $GR HTEN URAN W2~G TENS .PHA .PHA PHA *DTE · ,DTE .DTE ,DTE .DTE ,bSS .bSS .bDT bDT 'bDT m .LDT .bDT ,bDT ,CRC .tNb .CNL ,CNb KAL AI.P NGT 4.159 4.049 4. 0.000 15.440 12 544 861 976 94 945 0 782 034 223 2 171 72 121 7 616 652,31~ .859 208 .,~28 72. 21 292 120 673 4495 000 60 599 CDER.PHA ClMP.PHA CMVR.PHA CILM.DTE IIRD,DTE SFbU.DTE TENS.DTE DT.bSS GR,LSS HTENebSS PEr.bDT LU.LDT SS2.LDT LSRH.LDT TENS.bDT PHNDeSAN PEr,CRC TNPH.CNL RCFT.CNb TENS.CNL NPOR.SAN THOR.KAL URAN.ALP CGR.AbP W3NG.NGT HTEN.NGT SP.AIT 238.~ 20 DEPT 'ZDER IMPH IMVR IIXD, .TSp. ~ EM, DTL, TENS DPH! bb ~ 7400.000 PHA 3.979 PHA 4.597 .PHA 4.864 DTE 4.254 DTE 42.301 DTE -136,375 DTE 135.2~ LSS 94,:30~ LSS 5220..000 bDT 14.287 bDT -0,0i5 bDT 147.393 CIDP PHA CDVR PHA CMER PHA CILD DTE IDOF DTE IXRM.DTE GR,DTE MRESeDTE DTLN.,LSS MTEM.LSS RHOBeLDT QSS,LDT LITH,LDT 259.15! 241,~42 214. gO 258.792 .000 o: 2. XDPH IDYR IMER ILD IMOF CAbS HTEN DTLF MRES DRHO b$ ,PHA .PHA .PHA .DTE ,DTE .DTE .DTE .DTE ,DSS ,bDT .bDT .LOT 3 859 4 143 4 667 3 864 0 000 9.564 2.273 0.~94 0.013 28~ 497 20:943 CDER,PHA CI~P,PHA CMVR,PHA CIbM.DTE IIRD.DTE SFbU.DTE TENS.DTE DT.LSS GR.LSS HTEN,LSS PEFeLDT .bDT 25~ '342 1756 o5 57 ' .95 314 fi o 8 271, ,O l,I'S Tape Ver.ltication Listing Schlumberger Alaska Computing Center LURH,LDT PFDC SAN DRHO CRC TNRR CNb CNTC CNb MRES CNb TNPH.SRN POTA KAL THOR AbP C8 NOT W4NG NGT MRE8 GT 1250 422 2 4i4 133 435 13 410 0 013 3.386 196{,422 0,821 39,134 2,387 10,202 1819,~13 8. 02 0,821 683,080 $$HV.LDT CALX,bDT HRE$,bDT NRHO,CRC NPHX,CNb NPOR,CNb CFTC,CNb MTEM,CN~ NPHZ,SAN SGR.,KAb POTA,AbP N1NG,NGT WSNG,NGT MTEM,NGT TEN$,AIT DEPT IDER'PHA Z~VR,PHR ILM,DTE IIXD DTE SP DTE MTEM DTE OTb bSS TENS bSS DPHI bDT OhS,bDT' Lb,LOT LSHV,bDT bURH,LDT PrOC.SAN DRHO. CRC ?NRA. CNb HRES T~PH SAN pOTA KAL THOR A P .CS N~T W~NG NG? MRES NGT H?ENAIT 7200.000 5.097 5,099 5,210 4,979 23,315 -1.40,500 ,750 5005,000 14.188 145 7 1250.213 .2,438 1~.075 ! ,313 ~16~~00 ~50 ,155 ,897 ,.839 694,122 CIDP,PHA CDVR.PHA CMER,PHA C/LD,DTE IDOF,DTE IIRM,DTE GR.,DTE MR.E$,DTE OTbN,b$$ ~TEM.,bSS RHDB,bDT OSS, bDT bl?H,bDT 8$HV bDT CAb:! MRE$ bDT NRHO CRC NPHI CNb NPOR CNb NPHI SAN &OR KAL POTk,kbP WING..NGT WSNG,NGT MTEM,NGT TENS,AIT DEPT:,~ IDER,PHA IMPH,PHA 2MVR,PHA 'IbM,DTE 2IXD,DTE SP,DTE HTEMeDTE PTb,b$S TENS,b$8 700~,000 ,~20 4 231 4 155 131 103 100 50t0 000 ClDP, HA CDVR,~HA C~ER,PHA CIbD,DTE IDOF..DTE IIRM~DTE GR,DTE MRE$,DTE DT~N,b$S MTEM,bSS 27-APR-1992 08:57 1324.640 $1RH,LDT 14.073 SGR,bOT 0.821 HTEN.LDT 8 RTNR,CNL ~ 4 RCNT.CNL 35 HTEN,C~L 1 i34 i{R~N,KAb Io 5 5 &OR,ALP 6, 4 TENS.NOT 133.~5 GR.AIT 4870. 0 200,254 194,237 194,160 202.160 0,000 .326 0.808 95.592 t, .l o 0,002 6i,510 ,47 0 839 7 37 138 818 74 920 38 77 75 ooo O, 0 222,~74 ! O. 103,463 131.233 IDPH,PHA IDVR,PHA IMER.PHA ILD,DTE IMOF,DTE IIXM,DTE CALS,DTE HTEN,DTE DTLF,bSS MRES.LSS DRHO.SDT LS,LDT SSi,bDT Si. RH,bDT &OR,bDT HT£N.bDT RHOB,CRC RTNR,CNb RCNT,CNL SGR,CNb HTEN,CNb URANeKAL CGR,KAL &OR,ALP ~2N.G,NGT TENS.NOT OR,AlT IDPH,PHA IDVR,PHA IMER,PHA ILDeDTE IMOF,DTE IlXM,DTE CALS,DTE HTEN,DTE DTbF.bSS MRE$.bSS 2.351 bSRH.LDT 73.730 TENS,LOT , 39 TNPH, Nb RCFT.CNb 2037,050 73.7.30 TENS.CNL THOR,KAb 56 027 URAN 107 250 CGR*~bp · bP 123 640 ~3NO.NGT 4460 000 HTBN.NGT 60 330 SP.A2T 4.994 CDER,PHA 5.148 CIMP,PHA 5.150 CMVR,PHA 947 CILM,DTE ~ 000 IIRD,DTE 413 SFL~,DTE ~, 492 TEN .DTE 879 409 DT.b$$ 96 222 GR.L$S 0 808 HTEN.bS8 -o &&2.bDT 6 LSRH,bDT 74 TENS,~DT 8 959 PHND SAN 532 428 PEF CRC 3 388 TNPH CNb 2299 797 RCFT tnb 74 920 TENS CNb 538 959 NPOR &AN 2 O38 THOR KAL 63 146 URAN AbP 103 356 ~GR ALP 123 396 W3NG NOT 4390 000 HTEN,NGT 63 714 SP.AIT 4 798 CDER.PHA CMVR,PHA 000 IIRO,~?g 884, ~ TENS.D PAGE! 22 2 402 ooo 588 047 4460 000 4~ 04 46 499 487 607 -56 375 196 20 858 175 330 13 545 ' 12 2,0 -240: '5010; 884, Schlu,muercjer AlasKa eom DPHI. bSHV. bURH PrOC DRHO TNRR CNTC MAE8 TNPH POTA THOR CS W4NG. MAES. HTEN. bDT ]9.771 LOT '0.011 bDT 172..395 bDT 1250.298 bDT 2,334 LOT 129.298 SAN 18.971 CRC 0,004 CNb 3.854 CNb 1892.364 CNb 0.855 SAN 45,092 KAL 2.760 ALP I~.436 NGT 18 .521 NGT 3.949 NOT 0.855 AlT 695.200 DEPT IDER IbM IIXD SP DTb TENS DPH! bb LSHV LURH MTEM PrDC DRHO TNRA. CNTC ~RES TNpH THOR 4NO ~RES HTEN PHA 680~ PHA 6 PHA 6 DTE 6 DTE 10 DTE -158 DTE 129 LSS 94 bSS 4835 DT 20 DT -0 DT 125 bDT .bDT 12~ SAN 19 CRC -0 CNb 3 CNb 2228 CNL 0 SAN 35 KAL ~ ALP NGT 1857 NGT 6 NGT 0 A~T 706 .000 .18i ,814 ,766 ,751 ,929 750 :I 91 063 000 32 8.75 469 3 0 547 ' 1o 869 ,90~ O'/7 663 ,869 ,.232 DEPT, IDER, IMPH. Z~VR. IbM, I~XD, ~HA 66006 PHA 6 PHA 6 DTE 6 DTE ~3 DTE -153 ,000 .903 ,724 ~590 ,656 .063 sting utinq Center RHOB.bDT OS$.bDT blTHeLDT SSHV.bDT CALl.bDT MRES.bDT NRHO,CRC NPHI,CNL NPOReCNb CFTC~CNb MTEM.CNL NPHI.SAN SGR.KAb POTA.AbP WlNG,NGT ~5NGeNGT MTEMeNGT TENS,AIT CID CDV~'PHA ,PHA CMER.PHA CILDeDTE IDQF,DTE IIRM.DTE GR,DTE ~RESeDTE' DTbN.b$8 MTEM.bSS AHOY.bDT QSS.bDT kITH,bDT SSHV.bDT CAbI,bDT MRES. eLDT NRHO,CRC NPHI.CNL NPOR.CNL CFTC,CNb ~TEM,CNb NPHI.SAN SGR,KAb POTA.AbP W1NG,NGT WLNG,.NGT HTEM,NGT TENSeAIT CIDP,PHA CDVR...PHA CMER,PHA CIED.'DTE IDOl. DIE IIR .DTE GR.DTE 27-APR-1992 08:57 2.324 DRHO.bDT 0.015 LS.LDT 77.109 SSi.bDT 1323.313 S1RH.bDT 14.030 SGR.bDT 0,855 HTEh,LOT .328 RHOB.CRC 4 ,795 RTNR.CNb 44.6&9 RCNT,C~b 505.426 SGR,CNI., t29.298 HTENeCNL 45.092 URAN.KAb 84.046 CGR.KAb .8 47 SGR.AbP 28 .343 W2NG.NGT .897 TENS.NGT 12 .298 GR.AIT 4540.000 .393 147,49 162.35~ .000 1.3 .792 52,156 0.834 1 .191 2.318 3~.327 3 .894 .237 13~.875 .902 58.582 765 1.7~ 042 5 935 2 875 417~ 000 337 .1 148 254 149 446 O 000 .790 IDPH.PHA IDVR,PHA IMER,PHA IbO,DTE XMO~:DTE XXX DTE HTEN,DTE DTLF,bSS MRES.bSS ORHO,~DT bS.DDT SS~,~DT S1RH.bDT SGR.bDT HTEN,LDT RHO~.CRC RTNR.CN~ RCNT.C~L SGR.CNL HTEN,~L URAN. CGR,KAb SGR,AbP W2NG.NGT TENS.NGT GR.AIT IDPH,PHA IDVR,PHA IMER.PHA IH ,DTE IIXM.DTE CRbS,DTE 0 004 PEF.bDT 3, 208:770 8S2,bUT 279: .046 TENS.bDT 4181. 48~:3~7 PEFeCRC I~:~6 194~.898 TNPH.CNL 4~, .429 RCrT,¢Nb 494,399 ,046 TBNS,CNL 4185 .071 ~POR.SAN B4 486 67 .782 ,979 .000 .370 THOR.KAL URAN, P W3NG.~GT HTEN.NGT SP,AIT 46, 10, 3, 53, 48 · .., 516 0 9 378 504 307 31 19 5 51 240 5 51 412 5 6 6 780 6 159 0 000 3 065 858 717 9 7 256 8 582 8, 6 7.043 0.000 1.808 CDER CMVR PHA ClbM DTE IZRD srbu DTE TENS DTE DT bSS GR bSS HTEN bSS PEF.LDT LU.bDT SS2 bDT bSRH bDT TENS PHND ~TN PEr CRC TNPH CNL RCFT.~Nb TENS. Nb NPOR.$AN THOR.KAL URAN. bP CGR,~bP W3NGeNGT HTEN.NGT SPeAXT 16i,, 7 147,789 ~!48,135 7,2 4835,0 :52 1 883, 7 ii'' 4120 0 7t5, 9 4~20, 000 ,".~ 6.787 6 691 0 000 20 412 13 584 CDER.PHA CZMP.PHA CMVR,PHA CXbM.DTE IIRD.DTE SFLU.DTE TENS.DTE ~44',868 48,9 1 31,8 'I .0 bls Tape Verification LisCinn Schlumberger AlasRa Computlnq Center DTL.LSS DPHI.LDT OhS.bDT LSHV,LDT LURH.LDT MTEM,LDT PFDC,$AN DRHO.CRC TNRA.CNL CNTC,CNL MRE$,CNL TNPH,SAN POTA KAL THOR ALP CA NGT WANG NGT NRES NGT HTEN DEPT,. IDER,PHA IMPH,PHA I,~VR .'IIXD DIE SP. DTE MTEM. DTE DTL bSS TEN bSS DPHI bDT Qb8 LOT Lb tDT LGHV DT LURH bDT HTEM PrDC SAN DRHO C~TC;CNL HRES,CNL T~PH,SAN POTReKAL THOR,ALP CS,NGT WANG.NGT MRES.NGT HTEN,A~T DEPT, 'IDER,~HA I~PH,PHA 'IMVR.PHA 126.975 93.934 4825.000 13.677 '0.002 14~.703 1250.469 2,445 124.706 12.800 '0.003 ,285224 .693 0,879 36,749 2,660 17 .717 0,989 0,879 705,6~0 6400,000 4,~16 5.247 29'188 ~7~. 13 89 4540 000 19 ~25 -0 ~14 ~61 01 1250 499 122, 7 ~9,125 '0,020 38.~29 ~. 80 178 .~6 ~.'297 .~01 705. 85 00 :27o MRES.DTE DT[.N.hSS RHOBeLDT OSS. bDT LITH.LDT SSHV.LDT CALI,LDT MRES.LDT NRHO.CRC NP~I.CNb NPOR.CNL CrTC.~Nb MTEM.CNh NPHI,SAN SGR,KAb POTA,AbP W1NG,N'GT ~bNG,NGT MTE~,NGT TEN$,.A~T CIDP,PHA DVR,PHA MER,..PHA CILD,DT~ IDO.r,DTE IIRM,.DTE GR,DTE MRES,DTE DTbN,LSS RHOB,LDT QS$,L.DT blTH,bDT SSH¥,bDT CALl.bDT MRESeLDT NRHO.CRC NPHI,CNb NPOR.,CNL CFTC,C~b ~PHI, AN 8GR,~Ab POTA,AhP ~INGeNGT ~5~G,NGT TENSeAIT C~DP';PHA CDVRsPHA CMER~PHA CILDeDTE 27'~PR-1992 08:57 0.846 HTEN,DTE 94.~1 DTLF.b$$ 126. 5 HRES.LSS 2.~24 DRHO,bDT O. 21 LS.LDT 58.235 $S~.bDT 1322.039 S~RH.LDT 14.t60 SGR.bDT 3 440 RHOB,CRC iii13 RTNR,CNL 3 98 67 56 SGR,CNL 1~.706 HTEN.CNL 73:749 (IRAN.KAb 2, SGR.AbP 3. 6 TENS,NGT 124,706 GR.AIT 4395.000 23 294 184 8 3 0 7 ~24,789 2'325 35 4295 000 IDPH,PHA IDVR,PHA IMER,PHA ILD,DTE 'IMOF,DTE IIXM.DTE CALS,DTE HTEN.DT~ DTLFebSS ~RES,bSS DRHO,LDT bS,bDT SSI.bDT SIRH,LDT SGR.LDT HT~N.bDT RHOB,CRC RTNR.CNb RCNT.CNb SGR CNL HTEN:CNb URAN.KAL CGR.KAb SGR,ADP W2NG.NGT T£NS,NGT GR,AIT IDPH,PHA IDVR,PHA IMER,PHA II,,O,DTE 905.923 0~003 271,768 8.617 ~92.442 73.3~2 457.577 .439 .400 . 12 457.577 1.645 63,~13 108. 51 126 607 3960'000 68:455 ~:324 437 5. 15 4 ~86 0 000 12 150 ii .I 6 896 ~8 98 191 0 867 -0 020 308 304 1942 I~53 59 121 48~ 054 334 3 725 2373 905 59 ! 52~ 50 29 80 482 82 627 3780 000 52 082 5,484 5o 5.559 DT,LSS GR.b$8 HTEN.LSS PEF,LDT LU.LDT SS2.LDT LSRH.bDT TENS,bDT PHND,SAN PEP.CRC TNPH,CNL RCFT.CNL TENS.CNL NPOR,$AN THOR,KAL URAN ALP CGR ALP W3NG NOT HTEN SP ~GT IT CDER.PHA CIMP,PHA CMVR.PHA CILM.DTE IIRD.DTE SFbU.DTE TENS,DTE DT.bSS GR,bS8 HTEN [.SS PEr bDT LSR. H bDT TEN& bDT PHND SAN PEP CRC TNPH Nb RCFT ~NL TENS CNL ~POR 'SAN THOR Ab URAN IbP CGR ALP WSNG NGT HTEN CDER,PHA CIMP,PHA CMVR,PHA CILM,DTE PAGEI 24 93 67 ~38 99 905 923 4 0 25~ 792 428 3960 000 36 055 3960 0 -3~ 58 457 577 -7Z 625 226 449 186 433 · 37 13 690 378O 0 0 .'39 bis Tape Verification Listing SchlUmberger AlasKa Computing Center IbM DTE 11XD DTE 8~ DT£ MTEM DT£ DPHI.LDT ObS~LDT Lb. DDT LSHVLDT bURH bDT MTEM bDT PFDC SAN DRHO CRC TNRA CNL CNTC CNL ~RES CNb TNeH 8AN POTA KAL THOR ADP CS NGT WLNG NGT MAES NGT HTEN DEP~ IDEI'PHA lb1 PTE IlXl D?E TEN bSS Lb bDT bSHV bDT LURH LOT MTEM bDT FD¢ SAN RHO CRC T1RA CNb CITC CNL MI ES CNL TIeR SAN PTA KAL T OR Abe '~ NGT w4i ~R~S,NGT HT~N..AZT 5.099 9.596 '154.250 889 4455.000 14,184 '0.028 143.777 1250,~83 2, 19 120.107 13.415 0,003 3.060 2323,294 0.914 32.048 2,400 17 ,007 11,858 0.914 ?04,545 6000 000 2 566 443 ~ 410 2 446 45 661 -134 813 120 978 4119.129 55 000 18 755 124~' ,841 2 294 9O4 $26 0 038 48 671 1~ '441 ,051 ,66.2 t82~,88! 0.938 715,566 IDOF.DTE IIRM.DTE GReDTE MRE$,DTE DTbN,L$S RHOB,LDT O$$.LDT LITH.LDT SSHV,LDT CALl,LOT MRESeLDT NRHOeCRC NPHI.CNb NPOR.CNL CF?C.CNb MTEM,CNb NPHI.SAN SGR KAL POTA ALP WING NGT WSNG NGT ~TEM NGT TEM$,AIT CIDP..PHA CDVR,PHA CMER,PHA CILDeDTE IDOF,DTE IZRM..DTE GR,DTE MRE~,DTE DTLN,bSS MTE~ DSS ~HO~ bDT ~SS bITH bDT SSHV bDT CAbI,LDT ~RE$,LDT NPHI. NPOR',CN5 C~TC,CN5 ~TE~,CNb NPHI,SAN SGR,KAb POTA,ASP WlNG,'NGT MTEM,NGT TENS.AlT 27-APR=1992 08:57 184. 9 65,625 O0 5 1 12t.889 .416 O. 1321.400 13.382 0.914 2.4 1 3 768 317 120 107 32 048 74.139 .623 23 .~54 3.953 120.107 4175.000 384,779 393.421 ~1'.651 1.722 0.000 379.162 66,848 0,899 115 468 120~978 2.293 0,036 71.869 !31~,906 21,0i6 .938 41 304 172 44 6i7 158 671 8~ 808 4'42 275 692 88! ooo 158 IPQF,DTE IlXM.DTE CALS,OTE HTEN.DTE OTLF.LSS MAES.DSS DRHG.LDT DS.LOT SSI.LDT S1RH,LDT SGR.bDT HTEN.bDT RHOB.CRC RTNReCN~ RCNT.CNL SGR,CNL HTEN,CNL URAN.KAL CGR,KAb SGR,AbP W2NG,NGT TENS.NGT GR.AIT IDPH.PHA IDVR.PHA IMER.PHA ILD,DTE IIXM.DTE CAbS.DTE HTEN,DTE DTLF,LSS MRES,LSS DRHO.bDT LS,LOT SSa,bDT S1R ,LOT SGR,LDY HTEN,bDT RHOB,CRC RTNR,CNb RCNT.CNL SGR,CNL TEN,CNL RAN.KAL CGR.KAb SGR.AbP W2NG,NGT TENS,NGT GR.AIT 0 000 IIRD.DTE '5 ~19 SFLU,DTE 12 963 TENS.DTE 873 362 DT.bSS 96 7O7 GR.bSS 0.879 HTEN.LSS 0.003 eLF.bDT ~9.029 LU.LD, ~.927 SS2.LDT .401 LSRH.LDT 74.139 TENS.bDT 49~.701 PHND.SAN .429 PEF.CRC 256~.228 TNPH.CNL .124 RCFT,CNL 74 139 TENS.fNb 496:701 NPOR. AN 2.567 THOR.KAL 59.3i1 URAN.ALP ,874 SP.AIT 2 599 2 542 2 ~29 2 53 0 ~00 16 06 82 114 0 0 345 215 8O 538 3 67 1 69 CDER',PHA CIMP.PHA CHVR,PHA CIbM.DTE IIRD,DTE SFbU.DXE TENS'DTE DT.LSS 578 GR.bSS 899 HTEN.bSS 12 PEF.bDT 65 bU,LDT 1 5 SS2.LDT 33 LSRH.LDT 808 TEN,,bDT 591 PHN .SAN PEr,CRC ~ TNP,.CNb 05 RCFT.CNb 08 TENS.CNb {91 NPO~.'SAN 49 THO .KAL 243 URANeAbP 771 CGR,AbP 447 W3NG.NG~ 000 HTEN,NGT 138 'SP.AIT 166 753 102 602 65 625 873 362 .4 147 270 505 267 954 3 765e~88 3675,000 '30.492 64 '.389 656 409 405 41.4 932 408 3585:0 '"20,~ 3585,0 0 2,453' 89,732 "57,938 L~'s TaD, Verification btstino Schlumberger Alaska Computtnq Center DEPT. IDER.PHA IHPH,PHR IMVR.PHR IbM.DTE IZXD.DTE M?EMeDTE DTL.LSS TENS,L$$ DP~I ObSbDT Lb bDT bSHV bDT bURH bDT MTEM bDT PFDC SAN DRHO CRC TNRk CNb CNTC CNb MAES CNb TNPH SAN POTA KAL THOR ALP C$ NGT W4NG NGT MAES NGT ,HTEN AlT D£PT IDER PHA 'iMPN PHA IMVR PHA '~bM OTE IIXD DTE SP. DTE aTEa. D E DTb, hl$ OhS,bDT ..bL,bDT bSHV. bDT bURH ~TEM bDT PrOC $~N DRHO CRC CNb CN?C CNb MRES CNb P TR b THO~ ALP CS NGT 5800.000 2.88! o932 ,944 6 8 125 t02.200 3595.000 75.294 0.003 104.370 1250.066 2,653 115,914 75o.~22 -~. 85 120~ 'i09 .907 0,958 88.932 0,993 7,0,35 .958 71 633 5600,000 1~42~ 1,518 1,520 8,125 84,688 104,800 3375.0 0 '999 '~0 -999;.250 -999 .,~50 -999~ 50 -999.250 -999.250 '999,250 -999,250 '999,250 'g99.250 '999,250 -999,250 '999,250 CZDP.PHA COVR.PHA CMER.PHA CILD,DTE IDQF,DTE IIRM,DTE GR.DTE MRES,DTE DTbN.bSS MTEM,L$S RHOBeLDT OSS, bDT bITH.LDT SSHV,LDT CALl.bDT MRES.bDT NRHO.CRC NPHI,CNb NPOR CN[, CFTC CNL ~TE~ SGR KAL PO?k ALP W1NG,NGT W5NG,NGT MTE~.NGT TENS.AlT CDVR~PHA ~MER,PHA CIbD,DTE IDQF,DTE IIRMeDTE GR,DTE MRE$eDTE DTLN~LS~ ~TEM,bSS RHOB, bDT 9SS,bDT blTH,bDT 8SHV~bDT CALl,bDT MRES,bDT NRHOeCRC NPHIeCNL NPOR.CNb MTEM, NPH'Io~AN SGR,KRb PO?A,AbP W1NG.,NGT 27-APR-1902 08=57 34 68 IDPH.PHA 34~'~49 'DVR.PHA ~:~67 CDER.PHA 347 . 74 CI~P PHA 34i CIb~.DTE O0 IMOF.DTE 000 IIRD,DTE ~ ~50 IIXM.DTE 1~:766 SFbU.DTE DTE 500 DT · , 589, · Sl~,bDT 031 bSRB,bDT · HTEN,bDT 51~ 622 PHND.SAN 75 68.468 RTNR,CNL 5 630 TNPH CNb 84. 4 ° 242 115 88 35 0 4 115 3975 637 8 000 SGR.CNL HTEN.CNL URAN.KAb CGR,KAL SGR.AbP W2NG.NGT TENS.NGT GR,AIT 35 514 0 3O 48 58 3595. 35 637 TENS THOR 41 URAN ~90 CGR 300 W3NG 000 HTEN 430 SP CN~ CNG 'SAN .KAL ALP ALP NGT NGT 3595 68 .5 0 691'723 660. 3 715. 0 ~3. 3 '84.688 -999.250 '999,250 °999,250 ~999. 50 999.~50 '999,250 '999,~0 -999. -999.258 -999. 0 -999,250 IDPH.PHA IDVR,PHA IMER.PHA ILD.DTE IMQF,DTE IIX~.DTE CAb$.DTE HTENeDTE DTLF.L$S MRE$.LSS DRHO,bDT L$,LDT SSi,bDT $1RH hOT SGR~LDT HTEN,bDT RHOB.CRC RTNR.CNb RCNT~CNL SGR.CNb HTEN,CNL U~AN.KAb CGR.KAb SGR'AbP W2NG:NGT i.446 CDER.PHA , CMVR PHA 1.397 o. SFbU DTE -99~,§~8 TENS DTE . LSS 2, 3 H?EN .999,~4 LSS 50 PEF ~DT -999. 50 PHND '~AN PEr RC -999: -999.~8 THOR,KAL URAN,AbP -999. , ~3NG NGT 70 65' 65, .6 8 -999 .6999 "~999 -999 '999 '"999 '999 "999 "999 -999 -999 -999 -999 -999 -999 26 70t 750 250 332 000 800 643 500 618 916 000 643 ~0 r,~:S Tspe Verl~lcstlon Llst~no 'Schlumberger Alisa8 Computin~ Center ~RES.NGT =999,250 HTEN.AIT -999.250 DEPT'PHA IDEA. IMPH.PHA IMVR.PH~ ILM.DTE IIXD DTE 8P DTE ~TE~ DTE DTD DSS TENS LS$ DPH! bDT ODS DDT LL DDT bSHV DDT bURH DDT MTZM DDT PFDC SAN DRHO CRC TNRA CNb CNTC CND TNPH SAN .POTA KAL .THOR ALP CS aGT W4NG NGT MAE8 NGT 'HTEN AZT DEPT 'ZNPH PH~ IMVR DTE DTE DTE DTL ~SS TENS LSS DPH! .bDT ODS LDT Lb LD? bSHV LOT LURH bDT ~TE~ bDT PFD~ SAN DRHO CRC TNRR CND CNTC CN~ MAES CNL 5400.000 0.959 1.031 1 036 22~ 061 125 48 813 84 063 118 900 3865 000 -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 '-9 250 :-999 250 .999 250 -999.250 5200,000 2,462 2,45] 2.50 6~ 428 656 114.50 3665 OOg -999 250 '999 250 -999. 0 -999,250 "999,250 '999.25O -999.250 -999.250 .999.250 -999~.250 -999,250 W5NG.NOT HTEM,NGT TENS,blT CIDP,PHA CDVR.PHA CHER,PHA CZLD,DTE IDQF.DTE IIRM.DTE GRoDTE MRES,DTE DTLN,L$S MTEM.bS$ RHOB.LDT OS$,LDT LITH.LDT SSHVeLDT CALl.LOT ~RES bDT NRHO CRC NPHI CNL NPOR CNL CFTC CNL ~TE~ tnb NPHI,SAN SGR,KAL POTA,AbP WiNG,NOT WbNG.NGT MTE~,NGT TENS,AlT CZ.DP PHA CDVR PHA CMER PHA tiED DTE ZDQF DTE IIRM DTE GR DTE MRE$ DTE DTLN,.bSS MTE~,LSS RHOBebDT QSS. bDT LZTH,LDT 8SHV,LDT CALl.bDT MRE$,LDT NRHO.CRC NPHI.CNb NPOR..CNL CFTC,CNL MTEM.CNL NPHZ,SAN 27-APR-1992 08:57 -999,250 TENS.HOT -999.250 C;~.AIT -999.250 I047 655 046 129 968 032 1071 000 0 000 845.000 31.063 1.814 116.900 84,063 -999,250 :999.250 999.25O -999.250 -999.250 -999,250 -999.250 '9 ,250 '999.250 "999,250 "999,250 -999,250 "999, °9 ,250 -999,250 40~,250 42 .250 0.000 38i,500 7~.000 ,807 .188 '999.250 -999 250 '999 250 "999 250 "999 250 '999 250 2~0 -999 250 -999 250 -999 250 -999 250 IDPH.PHA IDVR.PHA IMERePHA ILO.DTE IHOF,DTE IIX~.DTE CALS,DTE HTEN.DTE DTLF.bSS ~RES,LSS DRHO.bDT DS.bDT SSi.bDT S1Rfi. LDT SGR,LDT HTEN.LDT RHOB,CRC RTNR.CNb RCNT,CNL SGR,CNL HTE~,CNb []RAN,KAL CGR,KAL SGR,ALP W2NG.NGT TEN$,NGT GR,AIT IDPH,PHA IDVR,PHA IMER.PHA IbD,OTE IHQF,DTE CALS,DT'E HTEN,DTE DTLF,LSS ~RES,LS$ DRHO,bDT bS,DDT SSI.bDT $1RH.bDT SGR.EDT HTEN,LDT RHOB,CRC RTNR,CNb RCNT,CNb SGR.CNL HTEN,CNL URANeKAL -999.250 HTEN.NGT -999.250 SP.AIT 0.955 CDER,PHA 0 956 CINP.PHA 1:033 CMVR.PHA 0 933 CILMeDTE 0:000 IIRD.DTE 111.~63 SFLU,DTE '999. 50 TENS,DTE 881.000 DT.LSS 116 500 OR,DSS 1~814 HTEN.LS& '999.250 PEF.LDT -999 250 LU,LDT -999:250 S$2,LDT -999.~50 LSRH.LDT -999. 50 TENSeLDT -999 250 PHND,$AN -999 250 PEF,CRC '999 '999 250 -999 250 -999 250 TNPH.CNb RCFT,CNL TENS.CNL NPOR.'$AN THOR,KAL "999 250 URAN,AbP '999 ~50 CGR,ALP -999 50 W3NG,NGT . 50 SP,AIT . CI~P.PHA 2.480 C~VR,PHA 371 CIbN.DTE g:ooo .DIE 23 ~00 SFLU,DTE 99:50 TENS.DTE ~13.500 DT,LSS o. ..Ioo . 07 HTEN.b$$ - 9 250 PEF,LDT '999 250 SS2,LDT -999 250 bSRH..LDT -~99 250 TENS.bDT - 99 250 PHND.SAN -~99 250 PEF.CRC - 99 250 TNPHeC.NL 999 250 RCFT.CNb i999:2S0 TEN$.CNL 99.250 NPO~,SAN PAGE:~ 27 .-999,250 -999.250 969 965 219 942 500 759 500 386~ '490 ,000 il9 600 31-063 88 000 -99~ 250 -999 o "999 -999 -999 50 -999.~50 -999 -999. 50 -999 ~50 '-999 -999 ~50 -999 50 O0 -999.;.250 ,,999,250 .-999,250 ,.999~250 999,250 .,,999,250 -999,250 ,,,999;,250 ~"'999~250 .,.999,~250 "'999,250 .,999,250 lum rqer ~laska Computing Center 27-APR-1992 08:57 POTA,KA~ '999,250 SGR.KAb THOR Ab '9~.250 POTA.AbP 4NG.NGT;- '999,250 WbNG,NGT MRES,NGT '999,250 MTEM.NGT HTEN,AIT '999,250 TENS,AlT -999,250 CGRoKAb -999.250 DEPT, 5000.000 CIDP.PHR 996.832 IDER.PHA 1.033 CDVR,PHA 966,410 894.182 IMER,PHA IDPH.PHA '999.250 URANeAbP '999.250 ~GR.AbP '999.250 W NG,NGT '999.250 HTEN,NGT -999.250 SP.AIT 1DVR.PHA CM£R.PHA CILD,DTE 1028,000 ILD,DTE 0 IDOF,DTE 0,000 IMQF,DTE 0 IIRM,DTE 804.500 IIXM.DTE 9 GR..DTE 39,969 CAbS.DTE -999 MRES.DTE 15.89 HTEN,DTE 894 DTbN.bS$ DTbF,bSS MTEM.LSS RHOB, .LDT 1 003 CDER.PHA 035 CIMP.PHA 1 118 CMVR,PHA 973 CIbM,DTE 000 IIRD,DTE 188 SFbU.DTE 250 TENS.DTE 000 DT.bSS 849.200 81.625 ~RES,bSS IMPH PHA IMVR:PHA IbN.DTE I~ED..DTE SP..DTE MTEN.DTE DTL.bSS TENS.DSS DPHI.DDT QbS.LDT .bb.LDT bSHV.bDT bURM,LDT MTE~.LDT PrDC.'SAN DRHO.CRC TNRA.CNb CNTC.CND MAES tnb TNPH SAN POTA KAL THOR ALP CS NGT W4NG .NGT ~R S T~N NGT H AlT DEPT., I~ER.PHA I PH,PHA I~VR PHA 'bM DTE lIED DTb bSS TENS bSS DPHI bDT bi, bDT bSHV bDT bURH bDT MTEM D~O,C~ TNRA CNL 1.108 1,123 1.117 199.500 .625 241 800 3515 000 -999 250 -999 250 -999 0 -999 .250 -999 250 -999 250 -999 250 -999 250 '-999 250 -999 250 -999 250 -999 2~0 -999 250 -999 250 -999 250 4800 000 1 5!6 1 608 1 ,'596 I ,63! 123:138 -83 75 81 O0 000 -999 250 -999,250 -99~,250 -99 .250 '999,250 '99~,250 -99 .250 '99~,250 '99 .250 bDT QSS LITH,LOT SSHV,LDT CALl,bDT MRE$,bDT NRHO, CRC NPHI',CNb NPOR CNL CFTC CNL NPH~ SGR POTA W NG WING NTEM TENS CNL SAN KAL ALP NGT NGT NGT AlT -999.250 -999.250 -999.250 -999,250 '999,~50 '999. 50 '999, 0 -999. 0 - 250 9 9 250 "9 9 250 99 250 '999.250 '999,250 '999.250 '999.250 DRHO,bDT LS.LDT SSI,LDT S1RH.bDT SGR,LDT HTEN,hDT RHOO.CRC RTNR.CNL RCNTeCNb SGR~CNL HTEN.CNb URAN,KAb CGR.KAb SGR.ALP W2NG,NGT TENS,NGT GR,AIT '99~.500 GR.LSS .895 HTEN.LSS '~99,250 PEr,bDT - 99.250 LU.LDT '~99,250 SS2.bDT ' 99.250 ~SRH.LDT ' EN ,bDT ' 99 250 ~HN .SAN '~99 250 PEF,CRC ' 99 250 TNPH.CNL -~9 250 RCFT. CNL - 9 250 TENS CNL '999.250 NPOR SAN '999.250 THOR KAL '999 250 ORAN ALP -999 250 CGR ALP -999 250 W3NG.NGT -999 250 HTEN,NGT '999 250 SP.AIT CXDP.PItA CDVR,PHA CMER.PHA ClLD.DTE IDQF,DTE II~M,DTE GR,DTE MRES,DTE DTLN.bSS MTEM,,LSS RHOB~LDT QSS.LDT blTH.LDT SSHV,bDT CALl.bDT MRES.bDT NRHO.CRC NPHI.CNb NPOR.CNb 65~,197 .968 '~ 5.397 653.000 0 000 ½:ooo ,906 92! 11~ 600 8 500 -999 250 ~99 250 "99~ 250 "999 250 -999 250 -9 '999 250 IDPH.PHA IDVR,PHA IMER,PHA IMQ DTE IIXM DTE CAbS DTE HTEN OTB DTLF LSS MRE$ bSS DRHO gDT bS bDT SS1. bDT S1RH gDT SGR bDT HTEN,LDT RHOB.CRC RTNR,CNb RCNT,CNb 1.531 CDER.~HA 1.513 CIMP. HA 1.599 CMVR.PHA 1.530 CIbM,DTE 0.000 IIRD.DTE 59'250 . 594 -999 965 500 197 ~00 1 -999 250 -999 250 -999 -999 -999 -999 -999 -999 SrbUiOTE TENS.DTE DT LS bU bDT 8S2 bDT T 50 TEN 250 PHND SAN 250 PEF CRC RCFT,CNb PAGEt 28 '-999 250 -999 250 '999 250 -999 250 -999 250 967 820 902 134 890 530 894 5O0 732 500 ! ?[3 39 969 894 000 -999 250 -999 25O -999 250 .999 250. ,999 250 -999 250 -999 )50 '999 50 '9 250 '99~ 250 6~6 59 965, -999 250 "999 250 -999 50 ,.999 2250 -999;2250 "999, 50 "999,250 '999,~50 "999, 50 · I8 Tape Verification btsttnq ' chlumVerqer AlasKa Comput/nq Center CNTC CNL MAES CNL TNpH SAN PDTA KAL THOR ALP C$ NGT w4NG NGT MRES NGT HTEN AlT DEPT,. IDER,PHA I~PH.PHA I~VR,PHA 'IUM,DTE IIXD,DTE SP.DTE MTE~,DTE TENS,USS D~HI.iLDT OLS/UDT UL UDT LSHV. UDT LURH bDT MTEM DRHO CRC T~RA CNb, CNTC CNb MAE'8 CNb TNPH SAN POTA KAU THOR ALP CS NGT W4NG Nb.. HTEN AlT' D I ER,FHA ~ P~,PHA I VA,FHA _UM,DTE I]XD,DTE _$P,DTE MTEM.DTE DTL USS DPH! UURH BDT MT.E~ ~DT 27-APR-1992 08t57 -999.250 CFTC.CNb -999.250 SGR.¢Nb -999.250 ~T£M.CNL -999.250 HTEN.CNb -999.250 NPHI.$A~ -999.250 URAN.KAL -999.250 SGR.KAL -999.250 CGR.KAb -999.250 POTA.ALP -999.250 SG~.ALP -999.250 WtNG,NGT -999.250 W2NG.NGT -999.250 WLNG.NGT -999.250 TENS,NGT -999.250 MTEM.NGT -999.250 GA.AlT -999.250 TENS.AlT -999.250 4600,000 t.902 1.989 1,972 1.979 0 -36, 79,438 1~8,600 3450,000 -999~250 -999.250 -999,250 ~999 25'0 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 ~999~250 999,250 -999,250 -~99,2.50 - 99.250 CIDP.PHA CDVR.PHA C~ER.PHA CILD.DTE IDGF,DTE IIRM.DTE GR.DTE MRES,DTE DTLN,LSS MTEM,bSS RHOBeLDT QSS LOT bXTH bDT SSHV. LDT CAUl BDT MRES bDT NRHO CRC NPHI CN6 NPOR CNG CFTC CNb MTEM CNU NPH! SAN SGR KAL POTA,AbP W~NG,NGT WSNG.NGT MTEM.NGT TENS.AIT CIDP.PHA CDVR,PHA CMER,PHA CILD.DTE IDQ~ DTE TlR DTE GR. DTE MRES, DTE DTLN 688 ~TEM RtiOS. UDT ~S$.LDT LITH UDT $SHV BDT CALl,bDT MRE$~bDT 4400,000 ,965 ,074 2.080 2 076 81 438 188 ! 9 .~00 .3215 O0 -999 50 -999 ~50 -999 250 ~999 250 -999,~50 -999, 50 527. 4 505.619 528,5O0 0,000 465 0 888 61:,oo 79,438 -999.250 -999 0 -999 5O .999 ~50 -999 250 -999 250 -999 25O -999 250 '~99 250 - 99 250 -9 2 0 -99~ 250 -99 250 -999 250 51 48 * . '999 -999 50 -999 ~50 IDPH.PHA IDVR.PHA I~ER.PHA ILD.DTE IMOF.DTE IIXM.DTE CALS.DTE HTEN~DTE DTEF,bSS MRES.bSS DRHO,LDT LS.LDT SSi,LOT S1RH.LDT SbA.bDT HTEN bDT EHOB CRC RTflR CNb RCNT CN6 SGR CNG HTE~ CNG URAN,KAb CGR.KAb SGR,ALP W2NG.NGT TENS.NGT GR.AIT IDPH,PHA IDVR,PHA IHER,PHA ILD.DTE IMOF DTE IIX~,DTE CALS,DTE HTEN.DTE DTLF.b5$ ~RES,I~SS DRHO,SDT 6S.bDT S$I.GDT S1RH.LDT 5GR,bDT HTEN.~DT PAGEt 29 99 NPOR,$AN -999,250 99~ THOR,KAL -999,250 99.~I~ URAN.AbP -999,250 -999, CGR.AGP -999,250 -999.I~~ W3NG.NGT -999,250 -999, HTEN,NGT .-999,250 -999,250 SP,AXT '999,250 1.927 CDER.PHA 1,~96 CX~P,PHA 1, 78 C~VR.PHA 1 891 CIbM,DTE 000 IIRD,DTE '3 563 SFLU.DTE -999 250 TEN$,DTE 939 500 DT,6SS GE,USS ~05 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 99 -999 -999 -999 -999 100 BBB HTEN GSS 250 PEr UDT 250 bDT bU 250 682 250 USRH 250 TENS 250 PHND 250 PEF 250 TNPH 250 RCFT 250 TENS 250 NPOR 250 THOR 250 URAN 250 CGR 250 W3NG bDT BDT .BDT SAN CRC .CNL .CNL ,SAN ,NGT HTEN,NGT SP,AI:T 525 875 502 800 507 147 .505 250 417 750 0o0 · i2t 400 52 4 8 · - 250 '999 250 '999 250 -99~ 250 "99 250 -99 -99~ 2 0 -99 ~0 -99~ .250 -999 250 -999 ~50 -999 50 -999 250 -999 250 -999 ~50 '999 50 1 1 2 1 0 43 -999 952 225 -999 -999 -999 -999 -999 -999 CIHP.PHA ~II CMVR,'PHA CIGM,DTE gOO IIRD.DTE 94 SFLU.DTE 50 TENS.DTE 0 DT,LSS 908 HTEN,LS8 50 PEF bDT SRH LDT PHND SAN 508 482 480 48. "~99 - 99 000 ~00 2 0 Tape verification ~tstin "SchZ'Umb~rger Iaska Computtn~ Center 'm PFDC,SRN DRHO,CRC TNRA.CN~ CN~C.CN~ ~RES.CNb TNPH.SAN POTAeKAb THOR.AbP CS.NGT W4NGeNGT MRES.NGT HTEN,AIT DEPT. ZDER.PHA I~PH,PHA INVRePHA 'IbM,DTE: II, XD.DTE SP DTE MTEM DTE: DTL DSS TENS DSS DPH! bDT OhS hOT MTEM,LDT PFDC.SAN DRH0.,CRC CNTC,CNb ~ES,CNL TNPH.,$RN P~TR,KAb THOR.ALP _C$,NGT ~4NG, NGT HTE:N,Ai? DEPT~ 'IDE:~*PHA iNPHtPHA I~V .b .uTE: I~X .DTE _$ ~TE: DT ,bSS TEN, .'DSS DPH .bDT Ob, ,bDT L,',LDT ' 99,250 '~99,250 '999,250 1999,2~0 999.250 -999~2~0 -999.250 -999&2~0 -999~2~0 '999,250 4200.000 2.829 2 668 2 658 45 '8 3 ooo 000 "999.250 '99g.250 ~.250 -9 ,.250 '999,250 '999.250 '999,150 '99g, 50 '999,150 "999, 50 '999,150 '999, 50 -999,250 -999,250 -999,250 -999,250 4000,000 ,368 ,512 1 492 I 502 1.20 ~38 -85 38 76 188 30 000 -999 250 -999 250 -999 250 NRHO.CRC NPHI.CNb NPOR.CNb CFTC,CN5 MTEM.CNL NPHZ.SAN SGR.KAb A-.AbP W5NG.NGT MTE~,NGT TENS.AlT CIDP.PHA CDVR,PHA C~ER.PHA CIbD,DTE iDQF.DTE IIRM.DTE GR.DTE ~RES.DTE DTbN,LSS MTEM.LSS RHOB.EDT SS~ bDT . bDT CAbI bDT ~RES bDT NRHO. C~C NPHI .CNL NPOR.CN6 CFTC CN6 MTE~ CNb NPHI.SAN SGR AL PDTA,~[,P ~.NGT NTEM, NGT TENS. AIT CDVR.PHA CHERePHA CILD.DTE ID~F.DTE IIRM.DTE GR.DTE ~RES.DTE DTLN,LSS MTENeLSS RHOB.LDT 0SSeLDT LITH.~DT 27-APR-J992 08:57 '999.250 RHOB,CRC -9 .250 RCNT.CNL -99~.250 SGR.CNL -99 .250 HTEN,CNL -999.250 URAN,KAL -999,250 CGR.KA[, -999.250 SGR.ALP 9. 50 TENS.~GT 99. 50 GR,AIT '999.~50 3~.;~! IDPH.PHA 3 . 3 IDVR.PHA 31~.132 I,ER.PHA 3 .250 ILDeDTE 0.000 IMOF.DTE 344.750 68.;13 CAb$.DT~ 1. 26 HTEN,DTE DTLF.5SS . 63 ~RES,DSS -99 50 R 0 bDT -99~'~ 0 H , 50 -999.~50 SS DT '999. 50 S1R~'b ,bDT '999,~50 SGR,LDT '999. 50 HTEN,bDT . 50 RTNR,CNI~ -999. 0 RCNT,CNb '999,.~50 HTEN.CNb ~999, 50 URAN;KAL '999, ,999,~I0 CGR.KAb '999. § ,NGT 999, 0 GR.AIT 70~,479 IDPH.PHA 73 'i~? IDVR.PHA 669. I~ER,PHA 729.500 ILD,DTE o.ooo · . 9 CAbS.OTE .96S HTEN.DTg 7~,188 MRES,~SS '99 ,250 DRHO,~DT ,250 SSi.SOT PAGEI '30 ~.~ RCFT.CNL -999, . TENS,CNL -999-~250 -9~'~ NPOR.SAN -999,250 . THOR.KAL -999 ~ 0 -9 -,,, 0 000 IIRD 29 641 SFLU -999 1017 189 -999 -999 -999 -999 -999 -999 250 TENS 000 DT 00 GR 26 HTEN bSRH PHND .DTE .DTE: ,DTE .LSS LSS LSS bDT bDT DT -99 -999 -999 -999 -999. -999 -999 -999 -999 -999 ~ TE:NS HTEN 25O SP PEF CRC TNPM tnb RCFT CNL AN A P NGT NGT 281.7 0 3295.000 ~38.600 -999,~ -999 '999, ~999i -999~250 -999,250 -999 250 .999 250 '999. 50 '999 ~50 '-999 250 ,-999 250 '999 250 ,4t3 CDER,'PHA , CMVR,PHA 1~369 CILN.DTE 0.~00 IIRD.-.DTE 51. 999.2~ SFGU DTE - TENS DTE 94~.000 DT I, SS i! .400 GR DSS - . ~DT 6 5'50 .946 008 · 999 250 -999 'Schl mDerger laska Computln~ Center 27-AP~-1992 0g~57 PAGEI 31 LSHV.bDT LURH bDT MTEM bDT Pr C DR~O SAN TNRA CNb CNTC CNL MRE8 CNL TNPH SAN POTA KAL THOR AbP C$,NGT ~4NG,NGT MRES,NGT H?ENoAIT DEpT IDER ~HA IMPH PHA I~VR PEA IbM DTE IlXP D~ SP D?~ HTEM DTE DTb b88 TEN$,b$S DPHIebPT Qb8 bDT .kb.LDT bSH~ bUR PFDC DRHO CNTC T~PH P~TA THOR ¢$ N4NG MAES HTEN -999.2s0 $SHV.t, DT -99~.~S0 SlR..~T -999.2S0 bS~..~OT -999 -999,250 NPHI,CNL -99 . 50 RTNR,CNb -999. TNPH,CNL -999 -999,250 ,POR..CN~ -99~,~50 RC~T.C~L -999.~§ RCFT,CNb -999 -999.250 CFTC, CNb -99 . 50 SGR.C~b -999. TE.$.CNb -999 -999.250 MTE~ CNL -99~ ~50 HTEN.CN6 -999.~ NPOR,$AN .-ggg -999,250 NPH! SAN -99 : 50 URAN.KA6 -999. ?HOR.KAb -999 -999,250 SGR KAL -9~.~50 CGR,~Ab -999.~ URAN,AbP -999 -9990250 ~OTA AbP -9 , 50 SGR, bP -999. CGR,AbP '999.250 TEM NGT '99~.250 GR.~IT -999.250 SP.AIT -999.250 TENS AIT -99 .250 3800,000 CIDP.PHA 10471 CDVR.PHA 1,937 CHER.PHA 1,704 CILD.DTE 742 IDQF,DTE 10 750 IIR~.DTE "104 500 GR.DTE 74 875 bDT 999 bDT -999 &AN -999 '-999 -g9g ~999 SAN 999 KAb -999 ALP -999 NOT -999 NOT -g99 NGT "999 AZT 4 200 ooo . 250 ~9 .250 25O 25O MRE$,DTE DTLNeLS$ MTEM,L$$ RHOBeLDT blTH,LDT $$HV,LDT '9~ CAbZ,bDT 250 MRES, LDT '99~ 250 NRHQ,CRC '99 .250 NPHI,CNb .50 NPOR,CNL 150 -9'99~ CFTC,CNb ,-9~ 250 ~TEM.CNb SGI..SAN '"99 ,KAL 250 POT ,NGT 250 WlN~'ALp '99 .250 ~5N ,~GT -9994.250 TENS,AlT -999 664,.523 ~ ,300 684,000 0.000 .813 !2~ 989 8OO .7 875 -99 250 25O 250 25;0 25;0 25 25,0 250 25.0 25.0 250 25,0 ,50 ~o 250 IDPH,PHA IDVR.PHA IMER.PHA I[,D,DTg IMQF,DTE IIXH,DTE CALSeDTE HTEN.DTE DTLF.LS$ MRESeLSS DRHO,LDT L$,bDT SSI,bDT 51Rfl, T 'lIEN,bDT RHO.B,CEC RTNR,CNb ECNT,CNb SGR,CNL HTEN.CNb URAN,KRb CGR.KAb SGR,ALP W2NG,NGT TEN$,NGT (;R.AIT 1.505 CDER,PHA 1, CMVR,PHA 1.46! ClbM DTE srbu DTE -999:2 0 TENS DTE , -999. PEr DT -999,250 TENS bDT -999,250 PHND SAN -999.250 PEr CRC '9990~50 TNPH CNb '999, 50 RCFT C'Nb '999..~50 TENS CNL -999, 50 NPOR SAN -999.250 THOR -999.250 W NGeNGT -999.250 HTEN.NGT -999.2so Se. AZ? D~pT~ IDER P.HA I~PH PHA Z~¥R PHA ~bM ~ZXD SP DTE ~TEM DTE TENS ~oo..o,o0 1,368 1,583 1,539 '5 344 7~ 313 000 DV~ *PHA ,PHA CIL~ PHA D?B IVQ D.TE IIR~ DTE GR,DTE MRE$,DTE TLN,bS5 ~TEN,L$$ 3! 6_85 .398 661 5OO 000 000 578 000 80~ 313 IDPH,PHA IDVR,PHA IBER,PHA IbD,DTE IMQF,DTE IIX~.DT~ CALS.DTE HTEN.DTE DTLF,LSS ~RES,bSS I J~ CDER.PHA I* CILM.DTE 0:000 IXRD,DTE 60.25i SF~U.DTE -999.250 TEN$.DTE 939.500 DT,L$$ '12,700 GR,L$S 2,000 250 250 250 250 250 2 0 ~o -999 250 -999 250 '-999 250 -999 250 679 887 5t6 37~ 000 e999 'ggg 250 0999 250 250 ~999 20 ~990 ~ 0 .~¢¢¢ '999 250 730,847 .631..~985 649,939 618,500 546,500 ..2~832 2725,000 .138~600 .31,~ 78 .939~00 I Tape veri~Aicatton blsttn~ SchlumDerqer laska Computln Center PAGE= .32 DPH~,kD? GbS,bD? bb·bDT kSHV,bO? kURH,bD? MTEM·bDT PFDC,SAN DRHO,CRC ?NRR.CNL CN?C,CNL MRES.CNb TNPHeSAN POTAeKAb THOR,ALP CS·NGT N4NG,NGT D~P?,pHA ~MPH·PHA Z~VR·PHA Ibl~ DTE ~[XO D?E DTb LSS TEN8 bS8 bDT b T BURH ~DT MTEM ~DT PrO~ 6AN DRHg CRC TNRR Nb CNTC ~N.L MRE8 CNL ~N~H ~AN P~TA . MAES NGT HTEN ,AIT D~PT IMVR,'PHA I~XD,.DTE SP,DTE -999,250 RHOB,LD? -999 250 DRHO.kDT -999 250 PEF,bD~ -999,250 -999,250 Q$$..LDT -999 250 kS.bDT -999'250 bU.bDT -999,250 -999·250 kITH.LOT -999 250 SSi,bDT -9991250 SS2oLDT -999 250 · 250 ~RHO,CRC '999 ~DT -999· RC PEr. CRC -999,250 , Nb RCNT, '999, RCrT CNL ,9~.250 CrTC..CNL -999 50 250 M?£M,CN~ -999,~50 SGR, N~ N~ -999. NPOR SAN -999,250 -9 · URAN ALP -999,250 -9 .250 POTA.AbP -999.250 SGR, bP 3409,000 1 .966 ,083 1,054 1 093 191 250 139 800 2745 000 -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 CZDP,PHA CDVR,PHA CHER,PHA CIbD,DTE I.DOF,DTE IIRMeDT~ GR·DTE MRE$,DTE DTLN bSS MTEM LSS RHOB bDT Q85 bDT MRE$ bDT NRHO CRC ~PHI CNL. NPOR CNb Cr?C CNb ~PH! SAN SGR KAb PO?A AbP H1NG NGT ~SNG NGT HTE~ NGT TENS .AIT I000.07047,40~ 1042, 0 000 0 '999 50 '999 ~50 -999 250 .999 0 -99~ 25 25O '99' 250 -999 250 · 999 250 9¢9 -999 250 '999 "999 '99~ 250 250 -999 .250 ID.PH·PHA IDVR,PHA IMER,PHA ILD DTE I~QF DTE IIXM DTE CAkS DTE XTEN OTg DTbF [,SS ~RES bSS DRHO bDT kS bDT S$1,bDT ~IRH,LDT 8GR,LDT HTEN,bDT RHO~,CRC RT~R,CNb RCNT,CNk SGR,CNb HTEN CNL URAN KAb CGR KAL SGR ALP W2~G TENS NGT GR,AIT 1,000 ~F.R,PHA 0,955 ~P,PHA 1,066 C~VRePHA 0,958 CILM,DTE 0 98 -999 946 -999 -999 999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 "999 000 IIRD DTE 250 SrbU DTE 250 TENS 000 PT ?oo 0~9 250 PEF 250 250 250 bSRH 250 250 PEF 250 TNPH 25O 25O 25O 25O 25O ,250 25O 25O 25O DTE LSS LSS bSS .LOT bDT bDT .LDT bDT CRC CNL RCFT,CNL T~NS,CNL NPOReSAN THOReKAb URAN,AbP CGR,ALP ~3NG,,NGT TEN.,NGT SP,AXT .00 73 ~0. o -,9 :Ilo -99 250 -999 250 '999 "999 -999 250 -9 25 ° -9 0 "99 250 3200,000 65. 1,375 1,40! 157,750 '121,625 iIDP,PHA DVR,PHA HER,PHA ClLD,DTE IDQF,D?E 794 793 725 801 0 015 664 304 500 00 Oo° 0 IDPH,PHA IDVR,PHA IMER,PHA ILD,DTE I~QF,.DTE IIXM,DTE CAIJ$,DTE 25~ CIMP,PXA 26 CDER,PHA 379 CMVR,'PHA 247 ~XLM.,DTE 000 ~RD,DTE 500 8 LU.,DTE 250 TENS,DTE 259 '40 ~c~.1moetqet At aska Computlnb. Center MTEN.DTE DTbeLSS TENS,LSS DPHI,bDT ObS,bD? Lb,bDT bSHVeLD? bURHeLDT MTEM,bDT PFDC,SAN DRHOeCRC TNRA,CNb CNTC,CNb MRES,CNb- ?NPHeSAN POTReKAb THOR,ALP 4C8,NGT MAES,NOT H?EN,AIT 70.375 146.800 2590.000 -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 -999 25O -999 -999 ,)5050 '999o250 '999,250 MRES. DTE DTLN,LSS MTEM.bSS RHOB,bDT OSS.bDT bITH,EDT SSHV,LDT CALl,bDT MRES~bDT NRHO.CRC NPHI,CNb NPOR.CNb CFTC.CNb M?EM.CMb NPHI.$AN SGR KAL POTA ALP W1NG NOT WSNG NOT TENS AIT DEPT, IDER,PHA IMPH.,PHA IMVR..PHA IbM,DOTE IIXD.DTE SP.DTE MTEM.DTE, DTb,bSS TENS,bS8 DPHI,bDT bDT bD? bSHV,bD?' bURH,bDT MTEM,bDT PrDC,SA.N DRHO, POTA,KAb THOR,ALP w.CS,NGT 4NG~NGT M. RES,NGT HTEN,AIT 3000~000 1. 491 ! 564 ! 582 1 576 122 688 -! 9 750 ½o -999 250 -999 250 -~99 250 - 99 250 -999 250 -999 250 -999 250 -999 '250 -9 g 0 -999 ~$0 "9'99 50 -999 ~50 -999 50 - 250 -999 25O CIDP.PHA CDVR. PHA CMER:PHA CIbD.DTE IDQF,DTE IIR,q. DTE GReDTE MRE$,DTg DTLNeL$S MTEM,bSS RHOBebDT OS3., bDT blTH,bDT 88HV,bDT CAbI,LDT MRESobD~ NRHO,C.R NPHX CNb NPOR CNb MTEM NPHI 8AN SGR KAL A P · POTA N~T ~LNO MTE~ NOT TENS,AIT DER, IMPH,PHA IMVR,PHA 2800,000 1,891 , 935 ,961 CIDP,PHA CDVR.'PHA CMER.PHA CILD,DTE 27-APR-1992 08157 14~ i33 -999 -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 25 "999 25~ -~99 250 - 99 250 678,320 6 .178 687.000 0 000 125 ! 9 7 063 -9909 250 ', 2 0 "9 '99 -9 250 - 250 '"999 250 "'999 250 -999 250 -999 250 -999 .~50 '"99 ,~ 50 '99 ~50 -999 50 .,999 250 512,623 525,000 HTEN.DTE DTLF.LSS MRE$,bSS DRHO.bDT LS,LDT SSi,bDT 81RHebDT SGR.bDT HTEN,LDT RHOB,CRC RTNR.CNb RCNT,CNb SGR,CNb HTEN.CNb URA~,KAb CGR.KAb SGR,AbP W2NG,NGT TENS,NOT GR,AIT IDPH.PHA IDVR.PHA IMER.PHA I[,~.DTE I~O .DTE IIXM OTC CALS~DTE DTLF,LS$ MR~S,GSS DEHO,LDT bS,LDT 8$1,'LDT SlRH.LDT $OR.LDT HTEN.LDT RHOB.CRC RTNR.~Nb RCNT, Nb SGR CNL HTEN:CNL URAN.KAb COR.KAL SOR,.ALP W2NO.NGT TENS,NOT GR..AIT IDP~,PHA IO¥ ,PHA IMER,PHA ILD,DTB 939.500 DT.LSS 144.600 GR.b88 2.133 HTEN,LSS -999.250 PEr,bDT -999.250 LU.LDT -999 250 $S2.LD? -999 250 LSRH,LDT -999 250 TENS.bDT -999 250 PHND.SAN -999 250 PEF.CRC -999 250 TNPH.CNL -999 250 RCFT.CNb -999 250 TENS.CML -999 250 NPOReSAN -999 250 THOReKAb - - -999 50 HTEN.NGT -999 250 SP.AZT ! ! 1 0 51 -999 -99~ -9 -999 -999 -999 -999 -9 474 CDER.PHA 494 CIMP,PHA 574 CMVR,PHA 455 CILM,DTE O0 IIRD,DTE ~25 SFLU,DTE 250 TENS,DTE 00 DT,GSS O0 GR,LSS 29 HTEN. LSS ~50 PEr bDT 25O bU 25O 882 250 LSRH. 25O TENS 250 PH~D. 250 PEP. 0 TNPH. 50 TENS 50 NPOR bbDT DT W3NG,NGT -999 50 AlT CIMP, HA · CILM.DTE .PAGEt 33 o~$0 -999;25 -999,2500 ""999. }50 '99~,250 '99 ,250 '999~,250 '9 ,250 "99 ' 25 "~99 ,.25 ' ,250 -999,250 . 670 789 00. 2585 707 .965" o -999, SO '999,~50 ~999 ' -999 250 , 250 '0999 1'250 ~999.250 528,8688 lO'i 953 250 'rape Verification b[stino Scbl.umuerger AlaSRa Computing Center 27-APR-1992 08:57 .PAGEt 34 IbN.DTE IIXD,DTE NTEN.DTE DPHZebDT QLS.bDT Lb,bDT bSHV,bDT bURH.bDT MTE~.bDT PFDC.$AN DRHO.CRC TNRA.~Nb CNTC.~Nb MRES. Nb TNPH,SAN PO~AoKAb THOR,ADP CSoNG? W4NG.,NGT NRES,NGT HTENeAIT I,ER PHA Z~PH PHA I~VR PHA IbM DTE I~XD DTE DPH! bb bDT bSHV bDT ~1 bDT pF i SAN DR~t CRC .TNR~ CNb carI cab MR SAN PO NRE8 !958 IDOF',DTE 9 313 IIRM.DTE '17 500 GR,DTE 70,313 MRE$,DTE 139,000 DTbN.bSS 2480,000 '999,250 RHOB,bDT '999,250 QS$.bDT -999,250 LITH,LDT '999,250 SSHV.bDT -999,250 CALl,bDT -999,250 ~RESebDT -999.250 NRHO,CRC -~99,250 ~PHI,CNL -ggg - 99.250 PO ,CNb -999 -~99,250 CFTC,CNb -9 NPHI.SAN -999,250 -999 -999 50 POTA,AbP -999 '999,250 WING,NOT '999 -999 50 MTEM,NGT -999 -999,250 TENS, AlT 0.000 IMOF,DTE -7 40 DTbF.bSS 70 313 MRES.GSS -999 250 DRHO.LDT '999 250 DS,bDT -999 250 SS1,LDT -999 250 SIgH,bDT '999 250 $ R,LDT :999,250 HTE~,bDT 999,250 RHOBeCRC 250 RTNR.~Nb -g 50 $GR ~b -9 50 HTE~'~ ~ . Nb -9 50 URAN,KAb -999 50 CGR,KAb -999 250 SGR,AbP -999 50 W2NG,NGT -999 50 TENS,NGT -999 250 GReAIT -999 -999,250 0,000 39,500 -999,250 939,500 159.400 2 123 -999 250 ~999 250 -999 250 -999 250 -999 250 -999 250 -999 250 IIRD.DTE 428, SFbU.DTE 2, TENS.DTE 2480. DT,b$S 145, GR,bS$ 56, HTEN,bS8 939. PEF,bDT '999. bUobDT -999 S$2,bD? -999 SRH,bDT -999 ~ENS,bDT '999 PHND.SAN '999 PEFeCRC '999 ~lg TNPH.CNb -999 RCFT.CNL -999 ]~ TENS.CNb -999 NPOR.SA., -999 ~ THOR.KAL -999 URAN.Ab~ -999 250 CGR.AbP -999 250 W3NG,NG? -999 250 HTENeNGT .~999 250 SP,AIT '"999 500 707 000 100 438 500 250 250 250 o . ~.50 ~0 25O ~50 25O 250 2600 000 I 544 i 697 I 782 ! 691 142 '.125 22 484 69 375 147 900 2250 000 -999 ~50 -999 50 -999 250 -999 250 -999 250 -999 250 -99 . 50 '999 ~,50 '999 50 -999 250 '999 250 "99 -99 ~50 '99~ 250 CIDP PHA CDVR PHA CMER PHA CIbD DTE IDOF DTE IlRM DTE GR DTE MRES DTE DTbN MTEM RtIOB bDT QSS bDT bETH bDT $SHV bDT CAbI bDT MAES bDT NRHO CRC NPH! CNL NPOR CNb CF?C,C~b ~TEM,CN5 NPHI SAN SGR KAL PO?A ADP WINGeNG? WDNG,.NGT MTEM,NGT TENS, AlT 710 54 640 37~ 570 i20 691 000 . 0 000 54i 500 969 135 144 700 69 375 250 .-99~ 250 -9. 250 -99 -99~ 250 '999 !50 '99 50 -99~ 250 -99 50 "999. 50 -999,150 -999,~50 -999, 50 IDPH,PHA IDVR,PHA IMER,PHA ILD,,DTE IMOF,DTE IIXM,DTE CAbS,DTE HTEN,DTE DTLF,b$S MRES,bSS DRHO bDT b$ibDT $$~ bDT 81RHebDT SGR.LDT HTENebDT RHOB,CRC RTNR,CNb ,RCNT CNL SGR:CNb HTE~,CNb URAN,KAL CGR,KAb SGR,AbP W2NG,NGT TEN$,NGT GR,AIT l 1 0 62 -999 997 208 2 -999 -999 -999 -999 -999 -999 -99 -999, -999, :999, .999. 999, -999. -999, 407 562 754 446 000 656 25O 50O 3O0 135 250 25O 250 250 250 250 250 250 50 ],o CDER,.PHA ClMP.'PHA CMVR PHA Clb~ D~E D~ IIRD DT~ $rbu TENS DTE DT GR bSS HTEN PEP bDT LU bDT 8$2 bDT bSRH bDT TENS bDT PHND SAN PEP.CRC TNPH..CNb ~POR;:SAN THOR.KAL URAN;AbP CGR~AbP W3NG.NGT HTEN,NGT SP.AXT 647 489 '589 208 ~ 06 2250 000 152 ~OO 4 69 991 500 -999, 50 '999,~50 '999~'250 .999, -999,2 .~999.250 .-999 250 ~-999 250 '-999 250 °o .-999 250 · -999 250 -999..250 -999.250 -999250 .m £I8 Tape. Veriflcation LtstlnO · Schlumberger AlasKa Computing Center ID~- ~HA INPH~PHA INVR.PHA XZXDiOTZ .DTE TENS,LSS DPHIobDT OhS.bDT .Lb.bDT bSH¥.bOT LURH.bDT MTEN.bDT PFDC..'$AN DRHO.CRC CNTC..CNL MRES,CNL TNPH,,SAN POTl.:~Ab, THOR bP CS NGT W4NG, NGT MRES..NGT HTEN.AIT DEPTi IPER PHA I~VR PHA IbM DTE IIXD,DTE EP,DTE M_TE MeDTE D~L,LSS DPF I.LDT Ot 8 bDT t b bDT bS~ V ,bDT bUS H LOT TN],~ 'SAN PO'?~; KAL TH~ )F, ALP C8,NGT 240~.000 .597 1,773 1,734 , 50 o 13 150.900 2490.000 3,534 30,022 273,250 1706,000 2,'115 68.813 "999,250 '999,250 3'495 1759 034 4 .-999 250 -999 250 -999 250 .999,250 .999 250 -999 250 2200 000 909 ~ 124 :111 131 76 313 152 0 001 226 375 170i 000 199 68 188 26.253 95 1869 575 2 207 -999 25§ -999 250 CIDP.PHA CDVR ..PHA CHER,PHA C IX, D. DTE IDOF,DTE IIRM,DTE GR.DTE MRES.DTE DTLNeLS$ MTEM.LSS RHOB;EDT Q$$,LDT LITH, LOT SSHV.LDT CALX, LDT MRES bDT NRHO CRC NPH! CNb NPOR CNb CFTC CNb MTEM CNb NPH! SAN $GR KAL POTA ALP MTEM NGT TENS AIT CXDP,PHA CDVR.,PHA CMER,PHA CILD'DTE XDQF DTE IIRM DTE GR DTE MRES DTE DTLN MTEM' RHOB bDT OS& bDT blTH bDT SSHV bDT CAb! bDT MAES bDT NRHO CRC NPH! CNb ~POR CNL CFTC tnb ~TEM CNL NPH! SAN SGR KAL POTS ALP WlNG.NGT 27-APR-1992 08:57 63 642 57 522 629.500 ,0 00 51 ,000 37.969 2,154 149 2,097 0,024 219.375 1350.000 3.3~3 2.i 4 .037 36.618 51~..249 -999 0 '999 0 ,999 0 -999 250 -999 250 525 6 529 0 4 15~ 207 5OO 0 350 000 18 813 207 220 ,36 686 -999 250 -999 250 -999 250 IDPH,PHA IDVR.PHA IMER,PHA ILD,DTE IMOF,OTE IIXM,DTE CALSeDTE HTEN.DTE DTLF,bSS MRES.bSS DRHO,bDT LS,bDT S$1.bOT S1RH.LDT SGR.bDT HTEN.bDT RHO&.CRC RTNR,CNb RCNT.CNL SGR.CNL HTEN.CNL URAN,KAb CGR KAb SGR ALP W2NG NG'r TENS NGT GR AlT IDPH,PHA IDVR,PHA IMER.P.HA XLD.DTE IIXM,DT~ A~S,DTE ~T N,DTE DTLF.bS$ MRE$,ESS DRHO.bDT [,S'LDT SSI:LDT $1R~,bDT SG ,bDT HTEN.LDT RHOB,CRC RTNR CNL RCNT~CNL SGR.CNL HTEN,CNb URANeKAL CGR.KAh 8GR ALP W~NG~NGT 87 OTB -999.25~ 1062.00 154 -0.010 497.500 225.500 2.146 37 969 1062 000 -999 250 3,725 IIRDeDTE . TENSeDTE DT,L8$ GR.LSS HTENebSS PEF'LDT $S ,LOT LSRH.LDT TENS,LOT PHND.$AN PEF CRC TNPH CNL ooo ..o. sA. u.s. :999,250 HT~ 999,250 ~ NG? 902 C[MP 2,t15 CMVR I 890 ClLM 0 000 IIRD 34 563 SF -999 2,50 TE~ O0 2 -0 420 226 2 4~ 946 2 3 1911 4i 946 99 999 -999 PHA PHA PHA DTE DTE DTE DTE LSS bSS 207 HTEN LSS 001 PEr bDT 37.5 S bDT 95 LSRH bDT 88 TENS bDT 000 PHND,SRN 217 PEF,~RC RCFT.CNb 0 TENS~CNL NPOR.'SAN 5 0 THOR.KAL 50 UR w~GR.AbP NG.NGT PAGEI 35 62~,254 56 .857 :576 668 559 500 484 000 · 2 576 2490 O00 151 800 37 969 1062 000 1,746 ,2,105 ,000 ~490.000 999,250 ,250 '9{~.618 47°: 8 ., 99,250 "999.'25,0 '"99~,250 -99 i~250 -999 0 -999 0 6O 47 66 461 750 419 500 0 ,4 079 -9 ~ 250 '999 : 0 b~S Tape Verification bistinq SchlummergerAlaska Comput[n.q Center W4NG.NGT MRES.NGT HTEN.AIT DEPT., I .PHA I~VR,PHA bM,DTE ZIXD.DTE SP.DTE HTE~,DTE. DTL,bSS TENS.bSS .bDT bSHV,bDT bURH,hDT ~TZ~,bDT PFDC,SAN DRHO,CRC TNRA,CNL MRES,CNL TNPH,SA.N NT HTEH AlT ~V ,PHA T~,DTE IIX .DTE DTb bSS TENS:LSS DPHI.hDT OLS.LDT ~L,LDT LURH.bDT HTE~,bD? PFDC..SAN DRHO.CRC TN ,'SAN 27"APR-1992 08=57 50 MTEM.NGT -999. 50 'GR.AIT 99".250 TENS. AlT -999. 50 2000,000 2.220 2,384 ,417 ~.293 56.344 i3.938 67,750 156,300 20~5,000 0,264 0.022 170 000 2,170 67,150 29, 65 -0,007 1.571 92 2,.195 -999 50 '999.~.50 -999,~ 50 -999 50 -999 50 CIDP.PHA CDVR,PHA CMER,PHA CIbD,DTE IDOF,DTE II~M.DTE R,DTE MRES,DTE DTbN.LSS ~TEM,LSS RHOB,LDT OSS,[,DT 5ITH,~DT SSHV bDT CA~l bDT MRES~.bDT NRHO..CRC NPHI Nb NPOR'~Nb CFTC CNL MTEM CNb NPHI SAN SOR,KAL POTA,AbP WiNG,NGT WLNG,NGT MTEM,NGT TENS,AlT IDP,PHA DVR,PHA CMER,PHA CILD,DTE IDOF,DTE IIRM,DTE GR,DTE ~RES,DTE OTLN bSS ~TEM DSS RHOB DT QSS ~DT bITH bDT SSHV CArl ~DTDT MRES bDT NPHI NPOR CNL ~ . CN~ NPHI SAN 0 6, 6,294 6.741 6,i52 30,203 ,$I~ gOOoo O2 0 ! 00Sl 4 1255 5~ 135 439.057 44! ~bO,?50 0.000 2.195 155.000 67.750 2,151 O. 2 1349. ,37 8 9 40 74 -999 ~50 1 -999, -999 50 IDPH,PHA IDVR.PHA IMER,PHA ILD,DTE IMOF.DTE IIX~.DTE CAbS,OTB HTE~,OTE DTLF,LSS MRES.[,SS DRHU,LDT LS,DDT 'SSi.DDT S1RM.~DT SGR,LDT HTEN,LDT RHOB,CRC RTNR,CNb RCNT,CNL SGR,CN/., HTEN.CNL URAN,KAL CGR,KAb W2NG, TE'NS,NGT GR,AIT 72. * ILO.OTE 15 , 25 IIX~,DTg 2, 5 HTEN,DTE 189,~0 DTI.,F.[,SS 68. 3 MRES.bSS li!93 DRHO,bDT 0 12 bS,bOT O0 SSI,bDT ,!35 HTEN,LDT 5 :' RTNR,CNb 5,515 RCNT,CNb 264,109 SGR,CNb 8,8~3 HTEN,CNh 52,2 7 URAN,KA5 PAGEI ' 36 -999.250 HTEN,NGT -999,250 SP.AZT "999.~50 "999, 50 2,278 CDER.PHA 450 'ooo 984.500 186.300 2.195 -0.008 449.750 ~24.000 2.~89 ~6,938 984,500 2.169 4 000 1595 36 984, -999 -999 -999 -999 -999 -999 009 938 500 ~50 25O 417 396 TENS. DT. GR. HTEN, PEF, bU 8S2 bSRH TENS PHND PEF TNPH RCFT TENS NPOR THOR URAN CGR W3NG HTEN, SP, DTE /.,SS bSS bDT bDT bDT bDT bDT SAN CRC tnb CNb tnb SAN KAl, ALP AI.,P NGT NGT AlT 158 O0 36 984 500 2 053 40~ 1999,2.5~ 5 6 6 5 0 9 '999 959 0 902 262 ~0 959 959 -999 25O 000 400 135 5O ooo 5O CDER CIMP CMVR. SrbU TENS DT GR HTEN PEF bU SS2 bSRH TENS PHND PEr TNPH RCFT TENS NPOR THOR PHA PHA PHA DTE DTE DTE DTE bBS bSS bS$ DT SAN 162 i4475 .1.945~065 267,35! !,945,.000 -999,2 LIS Tape Verlflcatlon Listtnq Schlumberger Alaska ¢omputtnq Center 27-APR-I 992 08.'57 POTA KAL -999.250 SGR.KAb '999.250 eSR.KAL ?HeR:ALP -999.250 PO?A.AbP -999.250 SSA.ALP CS.NGT -999,250 WlNG,NGT -999.250 W2NG.NGT W4NG.NG? -999.250 W5NG.NGT -999.250 TENS.~GT MRES.NGT -999.250 MTEM.NGT -999.250 GR.AIT H?EN.AI? '999.250 TENS.AlT '999.250 1600,000 12.872 10.0.77 10.266 9,367 ]1.242 -57.281 68,125 167.600 1755.000 51,691 -0.005 465.500 1703.000 1,787 68.125 50.8 4 0,'0~9 4.518 1291,570 '999. ' .999..~50 '999.'250 CIDP.PHA CDVR.PHA CMER.PHA C[{.D,DTE XDOF.DTE IIRM,DTE GR,DTE MRE$.D?E DTbN,LSS MTEM.b$S RHOB.bDT SSS,bDT LITH,LDT SSHV.~DT · ,bDT NRHO.CRC NPHI.CNb NPOR,CN[, CFTC.CN~ MTEM,CN~ NPHX.$AN POTA A~P WSNG NGT MTBM NOT T~N$ AX? DEPT. IDER.PHA I~PH,PHA IMVR.PHA I~M.DTE IrXD.DTE SP.DTE MTE¥ DTE DTb~SS DPHX,bDT OLS.hDT hh. LOT bSHV LOT ~URH LOT MTE~ bDT PrOC'SAN DRHO CRC TNR~ tnb C~TC MRES CN~ TNP~ SAN MRE$ NOT HTEN ,AlT 1400,000 1084., 1,8 89 17 ~09 -1, 25~ -67 50 73 813. 2048400 O0 o :ooo ,.813 ~0.032 4,772 CIDP.PHA CDVR.PHA CMER.PHA CXLD OTB IOOF DTE IIRM DTE GE DTE MRE$ OTB OT~N bSS RHOB,LDT QS$,~DT ~ITH,~DT SSHV,bDT CALl.hOT MRE$,~DT NRHO,CRC NPHI,CNb NPOR,CNh DEPT,~HA IDE,R, IMPH.PHA I~VR PHA IbM DTE IIXD DTE SP 'DTE MTEM DTE OTb TENS DPH! LO? ~$HV bURH MTE~DT Proc. SAN DRHO.CRC TNR~.CNb 81.430 76.045 98.155 89.625 0.000 lO1.000 2,1 164.000 68.125 1.797 0.002 376.500 1349.000 '999. 550 '.999.2 0 '999.250 -999.~50 -999, $$0 '999,2 0 4,~67 O, 74 54,435 8.281 0.000 065 .-21~ 400 ,! 6 -0 0 56.762 IDPH.PHA IDVR,PHA IMER,PHA IbD,DTE XHOF.DTE TIXM.DTE CALS,DTE HTEN,DTE DTLF,LS$ MRES,LSS DRHO.LDT LS.LDT SSI.LOT SIRH,LDT SGR,LDT HTEflebDT RHOB,CRC RTNR,CNL RCNT,CNb SGR,CND HTEN,CN5 URAN.KAb CGReKAb SGR.AbP W2NG NGT TENS:NGT GR,AIT XDPH,PHA IDVR,PHA XMER.PHA 'ILO.OTB IMOF.DTE IIX~.DT£ CAbS.DTg HTEN,DT£ DTLF,LSS MRES,L$S DEHO,bDT h$,bOT . SSI.bDT S1E}'I.bDT SGR,bDT HTEN bDT RHOB:CRC RTNR CNb RCNT' ,CNb .~999.250 URAN.AbP 999.250 CGR.AbP 999.250 W3NG.NGT -.999.250 HTEN.NGT 999.250 SP.AXT ]. 281 CDER.PHA .150 CIMP.PHA 10.188 CMVR.PHA 11.156 CIbM,DTE 0.000 IIRD.DTE 2.850 SFLU.D?E '999.250 TENS,DTE 926,500 DT,bSS 48~.300 .172 0.014 876.000 257.250 1.725 28 516 926 500 I 81~ 4 73 9 500 -999 250 -999 250 -999 250 -999 250 -999 -999 GR,bSS HTEN.bS$ PEa.bDT b .~DT SS2.5DT bSRH.bDT TENS bDT PHND SAN PEr TNPH RCFT TENS NPOR THOR URA~ 250 HTE 250 SP CRC CNL S~N 239 992 HA PgA 18 C,VR:PHA 128 688 CIBM,DTE 000 -0 159 ooo 3~ 500 GR,bSS 06~ HTEN,bS8 -0 03 PEr.bDT 1 335 bSRH.bDT 26 141 TENS.bDT ~ PEr.CRC '94~ TNPH.CNL 124~936 RCFT.CN~ PAGEt 37 '999.250 '999.250 '999.250 '999,250 '999.250 77,689 99~240 97.,407 106.688 93, 88 12,~61 1755,000 20~,800 82S 0 403 250 O0 5 949 0 '999 250 , 922 4 8 lO 859 1425 0 o .% .0 6IS Te · Verificatlon blstlnq Schlum~erqer AlasRa Computlnq Center 27-APR-1992 08:57 CNTC,CNb 1228.603 CFTC,CNb 272.037 SGR.CNL 26.141 TENS.CNL NRES.CNh 2,063 MTEMoCNL 73.81] HTEN.CNb 1425.000 ~POR.SAN POTA,KAb -999, SGR,~AB -999. CGR,KAb -999.250 URAN.AbP DEPT.. IDER.PHR IMPH,PHR IMVRM.PHA Ib ,DTE IIXD,DTE S~.DTE HTEN,DTE DTL,LSS TENS~,bSS DPH , bDT ~bS.bOT bb, bDT LSH~ bDT bUR bDT ~TE~ LOT proc SAN DRHO CNTC CNb MRE$ CNb TNPH SAN POTA ,KAL THO~C8 N~T W4NG,NGT ~RES,NGT HTEN.AIT IMPH ,PHA I.~VR:PHA ~ ~M OTB I.IXD OTB DTL LSS T~$ bSS DPH~ LOT ODS bDT bDT ~UR~ b T TE~ 1200.000 1884.393 22,917 32,956 24.t25 '1.529 -83.688 72.563 53,300 O~ 1701,000 .232 "0,016 , 642 127 2. 03 o '999, 2 '999 0 '999.250 -999,250 '999,250 lO0.000 95~.000 35,781 '~.441 7~ .500 ,250 ,000 ,381 I .ooo ,000 1.'~64 77:250 CIDPePHA CDVRePHA CMER,PHA CILD,DTE IDQF.DTE I.XRM.DTE GR,DTE MRES.DTE DTLN,LSS RHQB.LDT QS$.bDT bITH,LDT $$HV~.bDT CAbI~..bDT ~RE$.bDT NRHO..CRC NPH~ CNb NPOR CNb CFTC CNL NPHI:.~AN SGR Ab POTA,AbP WING~NGT WSNG.NGT NTEN,NGT TENSeAXT oPHA NER,PHA ILD.DTE IDQF,DTE IIRM~DTE GR,DTE MRES,DTE DTLN LSS MTE~ bBS RHOB bDT ~S$ bDT bXTH,bDT SSH~,LDT CAb .LOT MRES,[,DT 12.518 IDPH,PHA 79 -4 940 IDVR,PHA 1950 37'637. I~ER.PHA 26 15.477 ILO,OTB 64 3~,375 IIXM.DTE '0 2 .500 CALS.DTB 'gg9 ,2 03 HTEN,DTg 1425 7 .100 DTGFebS$ 315 2.563 ~RE$.bSS 2 -o . O0 S I.LDT 2 ~ , 6 SGR.bDT 25 ~§ HTEN.bDT 1425 · RCNT.¢Nb 131~ 2 2 URA~ KAL 99 CGR KAL -999 '999, 50 GR,AIT '99 -999,250 -0.816 IDP. H,PHA 1950 0.787 IDVR,PHA 1271 30.93~ I~ER Pi'iA 32 -0,42~ ILO:DTE !950 ,000 IM'QF,DTE 0 29,375 C&LS OTE -999 1,864 HTEN:DT~ 1464 8~.700 DThl*, L$$ 1,61 1,1 6 DRHO,bDT 0.0 8 bS.bDT 2728 I0.ooo 22,000. 81RH.bD~ 1. 375 SGR.bDT 29 1,864 HTEN,LOT t464 .886 .563 .000 .203 o 0 .750 279 50O 250 ~50 0 250 25O .000 .374 .600 864 032 000 375 284 375 000 CDER.PHA ClMP.PHA CMVR.PHA CZb~ OTB IXRD DTE SFLU DTE TENS DTE DT LSS GR bSS HTEN b$S PEr bDT bU LOT 862 bDT bSRHobDT TEN$,~DT PHN'D. AN PEr. CRC TNPH.CNL RCFT NPOR~SAN THOR HTEN T CDER,PHA CIMP,PHA CMVR,PHA ClbM,DTE IIRD,DTE SFbU,D~E TENS.DTE DT,LSS GReLSS HTENeL$S P£F.bDT TENS,bDT PHND,'SAN 2265 000 55 0.18 -999 250 ~999 250 -999 250 999,250 999.250 999,250 0,531 4~,438 14,047 48,563 2185,000 216.800 -25.500 1425,000, 't,396 ,2476.000 435.0~ '.87,425 '.t,061 6~,636 237,578 2~85,000 .:$9,308 999,250 -999;250 '999;2550 '999,2 0 -999,2 0 ,-.999,25~0 . , 245 0 goo 500 2 3~5 618 Taoe Verification Uistinq .Schlumberger AlasKa Computinq Center PFDC.SAN DRHO,CRC TNRA,CNL. CNTC CNb MRES CNL TNP~ SAN POTA KAL THOR ALP CS NGT N4NG,NGT MRESeNGT HTEN.AIT 92,325 NRHO,CRC "~,030 NPHI,CNL ,935 NPOR,CNL ~,864 MTEM,CNL ,459 NPHI,SAN '999,250 SGR.KAb '999,250 POTA.ALP -999,250 W1NG.NGT -999,250 W5NG.NGT -999.250 MTEM,NGT -999,250 TEN$,AIT DEPT., IDER,PHA INPH,PHA I_MVR, FHA I bM, DTE IZXD,DTE SP.DTE MTEM.DTE DTL.LSS TENS,LSS DPHI,bDT OLS,LDT Lb bDT ;aS}iV bDT bURH bDT MTEM bDT PFDC SAN DRHO CRC TMRA CNb ~RE, T~9I SAN P~T~ KAL ' THO~ ALP w4a{ NOT N T 80~, 4, 4, 4. ?, 7. 1 70, 90, 89. I192 -999 -999 -999 -999 000 CIDP. 544 CDVR, 117 CM£R. 029 ClLD, 47 IDOF, 42 IIRM. 00 GR, 75 500 DTLN, 000 MTEM, 1.21 RHOB, 070 000 LITH, 000 SSHV, 8 CALl, 988 NRHO 022 NPHI 455 NPOR 653 CFTC 845 MTEM 104 NPHI 250 SGR 250 POTA 250 WiNG 2~0 WSNG TENS FHA FHA PHA DTE DTE DTE DTE DTE LSS bDT bDT LOT bDT LDT CRC CNb CNb CNL CNb KAL NOT NOT NPH FHA X~'VR FHA LM.DTE iXXD DTE SP DTE MTEM DTE DTL hSS TENS,USS DPHX,'bDT ,LDT O.~ ,LDT 600,000 CIDP ,.150 CMER 11',i65 CILD 10,898 XDOF ,250 OR 70,313 ~RE$ 142,900 DTLN 1810,000 MTEM .164 RHOB 3~,'029 OSS . 273..500 LXTH FHA FHA FHA DTE DTE DTE DTE DTE bSS bDT LOT bDT 27-APR-1992 08:57 1.127 AHOY.CRC 60.569 RTNR.CNL 81.210 RCNT.CNb 243.148 SGR.CNb 77.250 HTEa. CNb 75.459 URA~.KAL -999.250 CG~.KAL -999.250 SGR.ALP -999.250 W2~G.NGT :999.250 TENS.~GT 999.250 GReAIT -999.250 .05~ 246.998 176.375 000 25,266 1.845 ,875 13f4 516 i 845 6~ 164 O7O 75 999 243 348 '76 875 74 104 "9 250 '999 250 -999 250 '99 250 -99~ 250 43,564 41,410 8~.340 4 .469 0,000 ,609 '047 , :ooo 70 13 218'~28 . 50 IDPH,PHA IDVR.PHA IMER.PHA IbD.DTE IMQF.DTE IXX~.DTE CAUS.DTE HTEN.OTE DTUF.hSS M'RES,LSS DRHO.LDT SS.bDT SS~,LDT 51R .bDT &UR.bDT HT£N,bDT RHOO,CRC RTNR,CNb RCNT,C~b SGR,CNb HTEN,CNb URAN.KAb CGR.KAb SGR,AbP W2NG,NGT TEN$~NGT GR.AIT IDPH XDVR IMER HTEN DTLF ~RES DRHO , FHA ,FHA ,FHA ,DTE ,DTE :OTE .DTE , L, SS ,bSS , LDT ,LDT . bDT 1.127 PEF.CRC 5.300 TNPH.CNL 1139.988 RCFT.CNL 29.~75 TENS.CNL 1464.000 ~POR.SAN 999.250 THOR.KAL :999.250 URAN.AbP -999,250 CGR,ALP -999,250 W3NG.NGT -999.250 HTEN,NGT -999,250 SP,AXT 5 966 CDER.PHA 5:493 CXMP,PHA 4.049 CMVR,PHA 8 ooo :035 FL ,DTE '9;9.~50 TENS.DIE 1451,000 DT.LSS 1~ GR,bSS HTEN,LSS PEF,GDT 2~8 LU.GDT LSRH, 2 145 119 2 145 -99 -99 -99 -99 -99 -99 . oo 45 °023 . .000 $90 0 ~$0 ~$0 250 TENS bDT PHND. SA.N PEFCRC TNPH CNG RCFT b TENS ~N NL NPO~ SAN THOR. KAL URAN CGR W3NG,NGT HTEN,NGT SP.AIT 2 2 -99 140 9 000 81 )50 0 O0 50 CDER FHA CIMP FHA CMVR PHA TENS 8 DT bSS GR USS PEF LDT LU,LDT $S2,bDT PAGEI 39 77 48 '999,250 '999,250 -999 '999 0 42 !6 149 2) 4.95 . 1910,,000 1,400 225,2 44~ 6 '1970 0 90 1042 .2 .483 1970 .000 ' ,74 -999 50 ",999 250 -999 250 -999 250 -999 250 · ,999 250 .683 565 18 ooo ?00 1'27 609 1406 O00 4.7~ 876 25O 359 000 ?ape Verification bistino 'Schlumverger Alaska Computinq Center 27-APR-1992 08:57 o4.ooo NTEM,LDT 7 . MRESeLD? 2. HTEN.hDT PFDC,SAN 29,522 NRHD,CRC 2.1~3 RHOS.CRC TNPHeSAN 26,782 NPHX.SAN , 2 URAN.KAL POTA.KAb -999.250 SGR.KAL -999.250 CGR.KAL THOR,ALP '999,250 POTA.AbP -999.250 SGR,ALP CS.NG? -990.250 WlNG.N T -099.250 W4NG,NGT -999,250 WSNG,NGT -999.250 TEN$.NGT ~RES,NGT -999,250 ~TEN,NGT -999.250 G~,AIT HTEN.AIT -999.250 TEN$.AIT -999.250 44~,500 ~4 0 872 -77 000 o °04? 68,.375 -999,250 -999 250 4 04! 1654 868 1 964 -999 250 -909 25O -999 250 -999 250 -999 -999 50 -999 250 ClDP PHA CDVR PHA CMER.PHA CILD DTE IDQF DTE IlRM DTE GRDTE ~RE$ DTE DTLN LSS MTEM. LSS RHOB, LDT OSS bDT LITHLDT SSHVoLDT CAhI,~DT MRES DT NRHO *bI ,CRC NPH! CNb NPOR CNL CFTC CNb ~TE~ CNb NPH! SAN SGR KAb POTA ALP WING NGT WLNG NGT MTEM NGT .TEN$.AIT DEpT I PH PHA DTE SP DTE MTEM. DTE. DTLibSS TENS bSS' DPH! bDT 0~$ bDT b8~'~LoTLOT LURH bDT MTEM LDT PFDC SAN DRHO CRC TNRA CNL NTC CNb iRES CND T~PH SAN POTA KAL THOR ALP CS NGT W4NG NGT MEE8 ~GT HTEN,AIT END OF DATA Ill.048 11 68 og: lo 1!~,688 0 '080 .000 2, 4 1353' 5 22 °oo0 .906 ~ 964 -99 250' 43 436 139 68 375 -999 250 ~90 250 ' 99 250 - 250 -9 25O -999 250 IDPH,PHA IDVR,PHA INER,PHA ILD,DTE IMQF,DTE IIXM.DTE CALS,OTE HTEN.DTE DTbF,~SS "RES.kSS DRHO, DT LS,bDT SSI,LOT $iRH.LDT HTEN, RHOB, C RTNR,CNb NT CNL RIGRiC~L. 'HTE:N CNL URAN,KAL CGReKAb SGR ALP W2NG~NGT TEN$.NGT GE,AlT PAGEI 40 1 973 LSRH.LDT 27 609 TENS,LOT 1406 000 PHND,SAN 2 163 PEFeCRC 3 915 TNPH.CNL 1965.765 RCFT.CN~ 27,609 TENS.CNL 1406 000 NPOR,SAN -999:250 THOR.KAL -999.250 URAN,AbP -999 -999.250 CGR,ALP -999 -999.250 WSNG,NGT -999 -999.250 HTEN.NGT · '999 '999.250 SP.AIT -999 18 , 2 2~ 086 203 583.672 1810 000 50 250 250 250 . CXM. PePH 4.982 C~VR,PHA 8.641 C[bN,DTE 0,000 ~IRD,OTE 1,766 SFLU,DTE -999.250 1438.000 DT bSS 135..100 GR LSS i'.964 HTEN LSS '0.004 PEr bDT 551,500 LU LOT 23~o375 '852 ,064 hSRH 28,797 TENS bDT 1438 000 PHND SAN '999 250 PEr CRC ,4 367 TNPH CNb 1559 677 RCFT CNb 28 797 TENS CNL 1438 000 NPOR'SAN '.99~.250 THOR.,KA.b -99 .250 URAN,AbP '999.250 CGR,ALP -999,250 W3NG,NGT '999.~8 HTEN,NO? '999,' SP,A!T 119 104 1890 -9 .40 359 i890 .-999 '999 "999 '999 'gg9 'ggg '9gg 744 113 625. 063. 934 000 500 000 0 250 .250 Tape Verification Listing chlumberger AlasRa Computing Center ~** FILE TRAILER **** F~LE NAME I EDIT ,OOi SERVICE ~ FLIC VERSION ~ OOIA07 DATE ~ 92/04/27 MAX REC SIZE ~ 8t92 FILE TYPE ~ LO bAST F/bE I **** FILE HEADER **** FILE NAME = EDIT ,002 SERVICE = FLIC VERSION = O0 A07 DATE = g2~04/27 ~AX REC SIZE = 8192 FILE TYPE = bO LAST FILE = 27-APR-[g92 08t57 PAGEI 41 FILE - EDIT,O02 COMPANY NAMEI ' conoco INC, WEbb~ BADA~! #2 FIEbDI WILDCAT MAIN PASS bOG DATA DATA SAMPLED EVERY -,1667 FEET DATA INCLUDED - TO0~ EXTENSION TOO[, TYPE USED NAME MSFt ,MSF MICRO SPHERICALLY FOCUSED L'IS Tape Verification t, tstinq ,Schlumberger AlasKa Computing Center TABLE TYPE : CONS 27-APR-1992 08:57 TUN! VAbU DEFI CN CONOCO INC. Comp, r~eld FN WN A~IN SECT TOW~ RANG COUN STAT NATI WITN SON PDAT EPD FT APD FT 37, EKB FT 3 EDF FT $~, PAGES 42 WILDCAT BADAMI #2 50-029-22230 2700' 3O 20E NORTH SLOPE ALASKA USA HERCER/HAND/PB¥4A 548510 Well AP1 $ Field Sect~ Town Range Count Nat~ e o Withe Servl Perm, gleva ny Name Name Name erial Number bocat£on lp Y or Province n s s Name ce Order N~mber ntdatum on of Perm,n,hr.'Datum bog Measured From Above Permanent .Datum ~. Elevation of'Kelly..~ushlno glevat on of Oetri¢ Floor. Elevation of Ground bevel' Total Depth.- Driller TOD TDL Bbl. TL~ DFT DFD DrPH DF¥ DFL AMS ~8T.. RMF8 MFST FT FT FT FT G/C3 F3 OHMM DEGF OHMM DEGF . 1~860, 11867, 11833. 445° GENERIC #2 11.5 9.,700001 1.85 Total Depth - LoDger ~ottom Log Intergal- ToD bOg l~terva[ Drilling Fluid Type. Drilling Fluid Density Drillln~ Fluid e,h.' ,.. Drilling Fluid,ViScosity Drllling:..Fluld boss. ' ResistiVity of..,Mud!'Sa~p}e Mud..Sa~ple, TenDeracut ResistiVity Ot MUd ~ud..FiXtrate. Samp~e..~Temperatu Resistivity og S~d Ca~e ~ud Cake.$ampz. e~Temperature Bottom.Hole Temperature. DEFI ,. D£eT De :h S~,IN Sy'nthet! [ ~ Inverse Resis~Iyity SMNO Synthetic. cro Normal ResistzvltY. ! bis Tape verification Listing .Schlumuerger AlasKa Computing Center 27-APR-1992 08=57 DATA FORMAT SP6CIFICATION RECORD SET ? TYPE" 64ES ** YPE REPR CODE VA UE 1 66 0 2 66 0 3 73 16 4 66 i 5 6 7 65 8 68 0,166 9 65 FT 11 66 0 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 mmImmmmmmmmmmmmm.mmmmmmM)MmMmm TYPE - CHAN ** ~m~mmmmmmmmmmmmmImmm}mmm~mmmmmmmmmmmm~mmmmmmmmm{mmmmmmmmmm~mm~mm~{~ SERVICE AP! APl API AP1 FILE NUMB NUMB SIZE REPR PROCESS ORDER # bOG TYPE CGASS MOD NUMB $AMP EDE~ CODE (HEX) mmmmmmmmmm~m{m~mmm{mm~mmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmm{mm~m~mmm~{~ oo~o ° ~ , , ~ ,, oooooooooo S48S10 O0 O0 0 2 ! , 4 68 0000000000 5 85 0 O0 000 O0 0 ~ 1 ! 4 68 0000000000 ~I Io o ooo oo o 85 0 ~ ! 1 ~ 68 0000000000 mmmmmm~mmmmmmmmm{mmm{~mI~mmmmmmmmmmmmmmmmmmmmmm~mmmm{mmm~mmm~mmm~m~ · ** SET tm~m~m~mmm{mmmmm NAME' SERV UNIT ID DEPT FT MSPb MSP OHM~ MIN MSF OHMM MNO M$~ OHMM ** DATA DEPT, DEPT. DEPT. DEPT, DEPT. DEPT, 1188 1180 1160 li40 1120 1100 0,500 MSFb,MSF 5,980 SMIN.MSF 5.087 SMNO.MSF 0.000 MSFb. MSF 3.956 SEIN,MSF 1.788 SMNO,MSF 0,000 MSPL.MSF 0.928 SMIN,MSF 0.451 S~NO.MSF 0.000 MSFG,MSF 1.418 SMIN.MSF 0,547 SMNO,MSF 0.000 MSFL,MSF 1,898 5MIN,MSF 0.950 SMNO,MSF 0,000 MSFb. MSF j,726 SMIN,MSF i..218 SMNO.MSF !,108 '0,'03! 0,1'25 0,355 0.,344 e e I~lS ?me~e Verification btstlnc $chlu erqer Alaska Computing Center DEPT, D£PT,. DEPT, DEPT, DEPT, DEPT, D£PT, DEPT, DEP?, PEP?, DEPT, DEPT. DEPT, DEPT. DEPT. DEPT. DEPT. DEPT. DEPT, DEPT,. DEPT, DEPT, DEPT, DEPT,. 10800.000 M8FL.MSF 10600.000 10400.000 10200,000 10000,000 MSFL,MSF 9800.000 MSFb. MSF 9600,000 MSFb,MSF 9400.000 MSFL.~$F 9200,000 MSFL.MSF 9000,000 8800.000 MSFL.MSF 8600.000 8400.000 MSFL,MSF 8200,000 MSFL,MSF 8000,000 MSFL,MSF 7800.000 MSFLeMSF 7600,000 7400,000 7200,000 MSFL,MSF 7000,000 MSFL,~SF 6800.000 ~srx,.~sr .6600,000 ~$FL,MSF 6400,000 6200,000 6000,000 5800.000 MSFb.'~S~ 27-APR-1992 08157 7,575 SMI~{.~SF 5.888 2.31! 2,045 1.679 1.522 SMIN.MSF 1.672 1.512 $~IN,qSF 1.263 2,623 $MIN,~SF 1,615 1,707 1.034 3,599 S~I~,VSF 2.349 2.655 2.124 1.352 SMIN,MSF 2.664 $~IN.MSF 2.559 8MIN,~SF 2,120 S~IN,~Sr 2.710 0,927 SMI~,~SF 0.255 0.867 0.571 0.908 1.000 0.952 1.259 0.845 0.820 1.141 1.584 1.531 0.998 1.690 0.986 1,397 1,380 1.247 1.727 1.808 1.836 1.084 1.524 1.112 1.401 1,446 ~51.343 SMNO,MSF SMNO.MSF SMNO,MSF SMNO,MSF $MNO.MSF s~No~sr SMNO,MSF SMNO~.MSF $MNO,MSF $MNO.MSF SMNO,MSF S~NO.MSF SMNO.MSF SMNO.MS? $~NO.MSF $~NO.~Sr PAGEI 1.142 0.698 0.455 0.407 0.290 0.443 0.223 0.262 0.261 0,1.98 0,678 0,277 0~.381 0,072 0,913 0,630 0.545 0,718 0,546 0,246 0,594 0,657 0,452. 0,680 0,050 .-0,.262 44 ,bis u~ape Verification Listing $chl meerger AIasRa Computing Center DEPT. 5739,667 ~SFb,MSF END OF DATA *~ 27-APR-1992 08:57 0.289 -51.071 SMNO.MSF PAGEI 45 -0.244 ~I* FILE TRAILER FILE NAME I EDIT ,002 SERVICE VERSION I 001A07 DATE I 92/04/27 MAX AEC SlZg t 8192 FILE TYPE LAST FILE ***~ FILE HEADER **** FILE NAME I EDIT ,003 SERVICE. I rbIC VERSION I OOIA07 DA~E I 92/04/2? MA REC SIZE ~ 8192 FIL£ TYPE I LO LAST FILE ~ FILE - EDIT,003 COMPANY NAMEI CONOCO INC, NELLI. BADAM! rIEbPI WILDCAT DATA SAMPLED EVERY -.25 FEET DATA INC[,UDED - Tool EXTE.S~O~ TYPE USED ,AlT T006 NAME ARRAY INDUCTION TOO[, (COMPUTING CENTER PROCESSED AND ENVIRONMENTAl, bY CORRECTED DATA) 'Schlumberger Alaska Computing Center 27-APR-1992 08:57 PAGEI 46 .e TAabE TYPE I CONS TUN] VALU FT CONOCO INC, NZEDCAT BAOAMI #2 50-029-22230 2?00' FNb & 700' FWE 3O 1ON NO~TH St, OPE A[,ASK~ USA EERCgR/HAND/POYEA 5485~0 0 36~ 3 ! ! 833~ N~RIC #2 0000! mmmmmmmmm~m~mm~mm~M~mN~MN~Nm( Company Name Field Name Well Name AP1 Serial Number r/eld bocation Section Township Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum bog Measured From Above Permanent Datum Elevation of Kelly BUShing Elevat on of Oer. ric~.F zeva lon rou.r CN FN WN APIN Fb SECT TOWN RANG COUN STAT NAT! SON PDAT EPD bmr APD rT EKE FT EDF FT EGE FT TDD FT TDb FT BbI FT Th{. FT DFT DFD G/C3 DFPH PrY s Drb. r3 RMS OHMM MS? DEGF RMF8 OHM~ RMC$ OHMM otal Depth - Driller oral De th - bO P gg.r Bottom bog Interval Top boo ISterval Orill!Sg f'lUid Type,, Drilling Fluid Density Drilling Fluid Ph .,.. Dri. llin~ Fluid Vl$¢osi:¥ Drllling Fluid boas ResistiVity ot Mud.'Sample Mud. Sample TemPerature Resistivity of.~ud r~ttate,a ,ud. rlltrate Sample ?empetatu Resistivity ot,~ud Ca~ei.sampi ~ud Ca~e Sample Temperature' 8ottom Hole Temperatuge. memmmleemmmemmmmmmmeemmmmme~me~mmmmmmeeeme~eeemmmm~ge~~m TABbg TYPE { CURV DEPT DePth AO 0 AO~O A030 AO60 Tape Verification bisttnq 'Schlumberqer Alasica Computinq Center 27-APR-199~ 08:5? DEFI ~~~m~~mm~m~mm~m~m~mm~~m~m~mmmmm~m~ ATIO AT20 A?30 A?60 ATgo ATRT ATRX AORT AORX m~)~MN~mmmmmmm~m~mmm~mmmmmmmMmmmmmmmm~mMmmm~mmmmmmmmmmmmm PAGEI DATA FORMAT SPECIFICATION RECORD SET TYPE - 64E8 ** TYPE REPR CODE VAhUE mm~mmNmmmmm~mmMmmmmmmmm~mmmm~m 6 0 5 66 ? 65 9 65 11 66 136 .12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 , '** SET TYPE - CHAN ** . NAME BERV UNIT SERVICE API APl API APl FILE NUMB NUMB SIZE REPR ID DRD~R # bOG TYPE C~S HOD NUHB SAMP E~ CODE (~X). D~PT FT 548510 O0 000 O0 0 3 1 t 4 68 0000000000 5.48510 A090 AlT AlT AlT AlT AlT ATI~. AlT AT2 AlT AT30 OHMM 548510 O0 OHMM 548510 O0 OHMM O0 OHMM O0 OHMM 5485~0 O0 OH'M~ 5485 0 O0 OHMM.548510 O0 OHMM 5,48510 O0 000 O0 0 ) 000 O0 0 ] 000 O0 0 3 000 O0 0 3 1 O0 O0 0 3 000 O0 0 3 1 000 O0 0 3 1 68 68 68 68 0000000 ooooooo 8 O0 O. oo ooo°°° i oo 000 00000 000~00000 ~iS Taee Verl~lcatlon htstlnq $~hlu,mber~er Alas~ ¢omputtn~ Center 27-APR-1992 08=57 PAGE! 48 mm~m#mem~mmmmmem~mmm~mmmmmm~mm~mmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmm~#~mmmm~mm#m NAME SERV UNIT SERVICE &PI AP1 AP1. AP1 FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # ~OG TYPE CbASS MOD NUMB SAMP ELEM CODE (HEX) ''''''''''''''''''''''''''''''''''''''''''''''''''''''''''60 RIT 0 000 0 3 1 ..... ''''''''''''''''''''''''68 0000 00000 ATg0 AlT OHMM 5485[0 00 000 O0 0 3 1 1 4 68 0000000000 ATRT AIT OHMM 5485[0 O0 000 00 0 3 1 I 4 68 0000000000 ATRX AIT OHMM 5485t0 00 000 O0 0 3 1 [ 4 68 0000000000 AORT AZT OHMM 548510 00 000 00 0 3 [ 1 4 68 0000000000 AORX kit QHMM 548510 O0 000 00 0 3 I 1 4 68 0000000000 ~~m~~m~mmm~mmm~mmmmm~m~m~m~~mm~~m~mm~mmm~m~mmmm~m~~~~~m~ *~ DATA DEPT. 11880.000 ~OIO.AIT 4.582 AO20.AIT ~.~17 AO30.AII AO60.AIT 2,296 Aog0.AIT 2.342 AT10.AIT . 9 AT20.AI AT30~IT 3.049 AT60.A[T 2.704 ATgO.AIT 3.105 ATRT.AIT A. TRX. IT 5.341 AORT.AIT 2.713 AORX.AIT 3.B88 DEPT. 11600,000 ~Ol0.AIT 31.880 AO20.AIT 6.744 AO30.AIT AO6OA?30,A,? 6.227 Aog0.AIT 6.094 ATi0.A,T 28.475 AT20,AIT .AlT 7.435 AT60.AIT 7.008 ATgO.AIT 6.83~ ATRT.AIT ATRX.A{T 421.889 AORT,A[T 7.032 AORX,AIT 162.229 11400.000 AOIO.AIT 296..199 AO20.AIT 1.1.603 AO30,AI? D~PT'AITAO60,- 7.872 AO90,AIT 7,092 AT10,AIT 125.043 AT20.AIT AT30.AIT 8,218 AT60.AIT 6.962 AT90oAIT 6.344 ATRToAIT ATRX.AIT 403.433 AORT.AIT 6.832 AORX.AIT 752.027 AD ,. IT 6 AD00 IT ' .879 AT[ .AIT 18. AT2 , IT AI~~. IT 5 86 AT60,AIT 5 356 ATg0.AIT 4.996 ATRT.AIT A___,AIT 62,402 AORT,AIT 5:60! AORX,AIT 118.268 ~: 0 AO10.AIT 11.466 AO20.AIT 5.~7 A030., IT ATRX,AIT 33.279 AORT,AIT 4,606 AORX.AIT 41~250 o o .ooo AT30,AIT' !~'896 AT60,AIT [l.:i.~ ATgO.AIT 9.761 ATRT.AIT 10600.000 AOIO'AIT 195~,000 AOIO.AIT 14 011 A030 AlT DEPT'AITAO60.: 8 520 R090.AIT ATI0.AIT 111962 AT60.AIT 9..~16 A. TgO.AII ~.787 ATRT,.AIT 2,60~ I,'3~ ,98~' ,544 6,182' ,752 9'144 1~* 22 ,, 98 6,952 6.83 5,08~ 46 9.83! £,~S Ta · Veriflcation Llstino ,6chlum~erger AlasKa Computing Center .~.m. ~o4oo.ooo ~o,o.~ AT30.AIT 262 AT60,AIT ATRX.iI? 327.983 AORT,AIT DEPT. 10200.000 AOIO.AIT AO60.'AI? 6.755 Aogo. AIT AT30.AIT 8.064 AT6OeAI? ATRX.AIT 792.473 AORT.AIT DEP?, 10000,000 AOIO,AIT AO60,AIT 6.230 Aogo. AIT AT30,AIT 7,187 AT60,AIT ATRX,AIT 278.683 AORT.AIT D~,~.~ ~oo.0oo AT 0 IT 6.431 AT60.AI? ATRX IT 68,526 AORT.AIT DEP?. g600.O00 AOIO,AIT AO60.~IT 5,549 AOOO.AIT AT30,AIT 6,71.3 A?60,AIT ATRX,AIT 75.823 AORT.AIT 9400.000 AOIO.AIT DEPT'AIT 6.791 AO90,AIT A060, AT30.AIT 6.906 AT60.AIT ATRX,AIT 206.8~.8 AORT.AIT , . ~ ~oo.ooo ~o~.~:~ ATRX,A 20 ~35 AORT,AIT ~. ~ooo,ooo ~o,o.~T AT O:kl? 5. ATSO,A~T ATRX-,AIT t23,420 AORT,AIT , oo.ooo A?3~.AIT 8.531 AT60.AIT ATRX,AIT 800.435 AORT.AIT DEFT'' 8600,000 AOiO.AIT ATIO..AIT 6.255 AT60. T ATRX.AIT 218.318 AORT.AIT 8400.000. DEPT'AIT' 4 460 A060, . AT30.'AIT 4,489 ATBO,AIT. ATRXeAIT 21.648 AORT.AIT 27-APR-1992 08:57 24.667 AO20.AIT 6.272 ATIO,AIT 6.468 AT~O.AIT 6.241 AORX.AIT 53.519 AO20.AIT 6.289 ATIO.AIT 6.87b AT~O.AIT 6,452 AORX.AIT 32,654 AO20.AIT 5.955 ATIO.AIT 6.311 ATOO.AIT 6.082 AORX.AIT 18.139 AO20.AIT 5. ~8 ATIO.AIT 5.7 5 AT90.AIT 5.511 AO~X.AIT 23.232 AO20,AIT 5.225 ATIO.AIT 6.223 AT~O.AIT 5,629 AORX.AIT 16.996 AO20,AIT 6.515 ATIO.AIT 6.421 ATgO,AIT 6.449 AORX.AIT 10.856 A020 ~.~,o4 A~o:~'~'r~ 5,~05 AT90.AIT 5. 72 AORX.AZT 13.730 AO20,AIT 5. 9 ATOO.AIT 5.240 AORX.AIT 13~.'315~ AO2§,AIT .0~2 AT1 .AlT 7,4 7 ATgO,AIT 6.'988 AORX.AIT ATIO.AIT ~'067 ATgO.AIT 6.386 AORX.AIT 0 050 AO20.AIT 4:434 ATIO.AIT 4.047 AT~O.AIT 4.107 AORX.AIT 8.50t AO3OeAIT 29.924 ~20.AIT 6.125 RT.AIT 33!.850 10.133 AO30.AIT . O1 ATR . IT 1063.9i4 28. AT20,*AIT 1950.000 7.006 AO30.AIT 18.294 AT20eAIT 5.463 ATRT.AIT 93.591 6.398 AO30.AIT 18.924 AT20.AXT 5,808 ATRT.AIT 56.544 8.906 AO30.AIT 1.348 AT20.AIT 26,159 ATRT.AIT 18.294 5.757 AO30;~IT 10.838 AT20, IT 5.369 ATRT.AIT 43.791 5 894 AO30,A~.T . ATR. T,~IT 99,202 , , AT20:~I? 302. ,! 7. AO30.AIT hT20,AI 5.~6 ATRT.AIT 70. 8 . 232 AO30,AIT .768 AT20.AXT 4.0~2 ATRT,AIT 13.3 9 7.202 8,468 6,228 8,274 9,729 6.579 6,' 48 6,224 7',266 5,606 5.793 , 525 .011 7,1~5 7.~ 7 6. 02 ,585 i,416 ,859 5,.~62 4, 84 4,053 I 'O Tape Verification Llstinq $chlummerqer Alaska Computinq Center DEPT. 8200,000 AOIO.AIT AO60.AZT 3.171 Aogo,AZT AT30,AI? 3,165 AT60eAI~ A?RX.AI? 13,212 DEP?,. 8000,000 AO60.AIT 6.457 AOg0oAIT A?30.AI? 8.544 ATRX,AI? 1950.000 AORT,AIT DEP?, 7800.000 AOIOeAIT AO60,AIT 4,549 AOgO.AIT A?30,AIT 5,394' AT60.AIT ATRX.,AIT 20.233 AORT.AIT DEPT. 7600,000 AOIO.AIT AO60,AIT ' 3,930 AO90.AI? AT30,AI? 4,680 AT60,AIT ATRX.AI? 30,275 AORT.AIT D~PT,~ 7400 000 AOIO,AI~ A060, IT 4:287 Aogo,AIT AT30.~IT 4,211 AT60,AI? ATRX,AIT 16,381 AORT,AIT DEPT, 7200,000 ROlO,AlT AO'60,iIT 4,415 AOgO,AIT 1730, T 5i532 AT60,AIT A?RX,AIT 5!,367 AORT,AIT ,ooo.ooo A060, 4,613 A090, T AI30,AIT 4.594 AT60,AIT A. RX,AIT 8,364 AORT,AIT 6800,000 AOiO.AIT DEPT'AITA060, 5,9B5 AOgO,AIT AT30.AIT 7,845 AT60,AIT ATRX.AIT 1950,000 AORT.AIT 6 oo OD Aolo A~30,AIT 7,613 AT6OeAI? ATRX,AI? 1950,000. AORTe. AIT DEP?,~ 6400,000 AOIO.AIT A060 ~IT 4,172 Aogo,AIT AT30:.~IT 5,862 AT60 ATRX, IT 51,116 AORT'AIT U60, IT 6,575 i09 'lit ltl0, I? 7i001 AT60 AlT A?R.X,AI? 66.128 AORT AlT 27-APR-1992 08:57 5.281 3.199 3,128 3,069 1950.000 5.902 5.948 6.006 15,086 4,440 4,313 4.440 9.295 3.892 4.160 3.967 3,808 4,045 12,301 4.726 87O 7O0 76 5,753 2t,49 6,687 6,6~1 31,629 4,029 4,.162 4.089 ,882 6,440 6,787 AO20.AIT ATIO,AIT AT90,AIT AORX,AIT ~020 ATIO ATgO AORX A020 ATIO AT90 AORX .AIT .AlT .AlT ,AIT .AlT ,AlT ,AlT ,AlT AO20,AIT AT10,AIT ATg0,RIT AORX.AIT AO20.AIT ATIO,AIT A?9OeAIT AORXeAIT AO20.AIT ATIO,AIT ATgO,AIT AORX.AIT AO20.AIT ATIO,AIT ATgO.AIT AORX.AIT AO20,AIT ATIO.A~T ATgO,AIT AORX,AIT A02 AlT ATi~:AIT ATgO.AXT AORX.AIT AO20.AI? ATi0.AIT ATg0.AIT AORX,AIT AO~O.AIT ATIO.AIT ATgO.AIT AORXoAIT 13 1950 5 1950 6 14 4 24 4 9 4 35 4 7 3 23 5 4 6 5 6 10 70 5 1950 8 22 6 170 8 31 4 53 7 13 6 20 279 ~135 .168 ,437 .800 .000 .467 ,000 .835 '7'71 .558 .896 .711 .120 .269 .466 ,830 ,687 ,712 .ggo .640 .051 ,626 o35~ ,049 ,740 2 328 .301 .541 .0lB ,44B ,.031 o113 .688 .759 AO30.AIT AT20.AIT ATRT.AIT AO30.AIT AT20.AI? ATRT.AIT AO30.Ai? ATR AlT AO30,AIT AT20.AIT ATRT.AIT AT20 IT AT~ToAIT AO30,AIT ATR , AO3~.AIT AT2 .AlT ATRTeAIT AO30,AIT ATgO.IIT, ATRT. IT AT20, ? ATRT,AIT AO30,AIT AT20.AIT ATRT.AIT A030 AlT AT20:AiT ATRT.AIT PAGB! 50 , 3,105 34 3,159 9,153 o 5 5,548 ,786 ,239 4.395 , 253 ,17i 4,235 4,588 3.694 5,173 , 05 ,868 15, 6,667 6, 99 bis ?ape Verification Ltstinq Schlumberger Alaska Computlnq Center 6000,000 AOIO.AIT DEPT'AITA060. 2,464 AOgO.AIT AT30.AIT 2,560 AT60,AIT ATRX,AIT 3.B51 AORT,AIT DEPT. 5800,000 AOIO.AIT AO3600.AIT 3.657 AogO.AIT AT .AIT 1950.000 AT60,AI? ATRX.AIT 2.609 AORT.AIT END OF DATA **** FILE TRAILER **** FILE NAME t EDIT ,003 SERVICE = FLIC VERSION = 001A07 DATE { 92/04/27 MAX REC SIZE { 8{92 FILE TYPE { bO bAST FILE = **** FILE HEADER FI 8EL~RV NAME , EDIT ,004 ICE = FblC V~ION I O01A07 O ~ 92/04/27 MAX REC SIZE I 8t92 FILE TYPE = bO bAST FILE 27-APR-1992 08157 3.439 AO20,AIT 2,~.6~4 AO30,AIT 2,791 ATIO,AIT 3,.,,,=.. AT20.AIT 2,500 ATgO.AIT 2,837 ATRT.AIT 2.608 AORX.AIT 3,608 O,c~.~! AO20.AIT 0,680 AO30,AIT 05 6 ATIO,AIT 1950,000 AT2OoAXT 195 **000 ATgO,AIT 1950,000 ATRT,AIT 1,849 AORX,AIT 8,505 PAGEt 51 2,662 FILE ' EDZT,O04 COMPANY NAME: CONOCO INC,. WEbbl BADAMI #2 FIEbDI WILDCAT REPEAT 'PASS RUN #2 HIGH RESO.bUT!ON bDT DATA SAMPLED EVERY -.0833 FEET ! I I l b~'s Tape verification Listtnq Schlumberger laska Computing Center 27-APR-1992 08=57 DATA * TOOL * TYPE , * bDT * LOT INCLUDED - EXTENSION TOOL USED NAME ,LDH LITHO DENSITY TOOL .CRC & .SAN ENVIRONMENTALLY CORRECTED 5ITHO DENSITY DATA TABLE TYPE = CONS TUNI VALU CONOCO INC. WILDCAT BADAM! #2 30 FT rT FT FT FT FT FT FT FT C,/C3 8 F3 OH.MM DEGF OHMM DEGF DEGF CN FN WN AP2N TOWN RANG COUN STAT NATI WITN PDAT APD EGb TDD TD'L DFPH DFV RMF$ MFST RMC8 MCST 20E NOR AbA USA M~R 548 TH SLOPE SKA ~/HAND/POYI,.,A Witness Name Service Order Number Permanent datum ElevatXon of Permanent Oatum bog Measured From Above Permanent Datum .. Elevation Of .Kelly Bushtnq Elevation Ot DerriCk Floor levatton of.Ground bevel oral Depth'- Driller u/' Total Depth - LOgger 33~ 8ottom bog Xnterv~l ~RIC #2 Top Log Ioterval Dr~llln~ {luld Type., 5 Dr!llin¢ FlUid Density 0000! Orllltn~ FlUid Ph ,~, Dr~lll Flu V it 11tnn id i.S¢OS ¥ Dr I .,.Fluid ~oss , 5 Resist~ itY o[ Mud:Sample Mud.,Sa le ~emperacure, 9 Resisti try of MUd ,'Filtrate $ MUd. Fi rate, Sample.':Temperatu ~ Resistivity Of MUd Ca~e.Sa. mui Mud cake Samp2e Temperature. , Bottom Hole Temperature lM~mmmmmmmmmmmmmmmmmmmmm~MmmmmmMmmmM~m~N~mmMmMmWmm~ ~lNWm~ DEr! mmmmmmlmmmemMemMemMeeMmemN~memm eld Name We1! Name AP! 8eFta1 Number Field bocation Section. Township Range ~ounty state, or Province Nation Tape Verification ListLng $c~lum~ercjer Alasica Computing Center 27'APR-1992 08~57 TABLE TYPE ~ CURV DEPT DeOth HPEF HIGH R~$OLHTION PHOTO-EL£CTR?C ~ACTOR HNRH HIGH RESOLUTION ENHANCED BULK DENSITY (ALPHA PROCESSED) HPHN HIGH RESOLUTZON POROSITY FROM ENHANCED DE~$I?Y HRHO HIGH RESOLUTION BULK DENSITY HDRH HIGH R£SOLUTION DENSITY CORRECTIOt~ HDPH HIGH RESOLUTION DENSITY POROS[T¥ Hbb HIGH RESOLUTION LONG LOWER WINDOW COUNTS HbU. HIGH RESOLUTION LONG UPPER 1-2 WINDOW COUNTS HL$ HIGH RESOLUTION LONG SPACING COMPUTED COUNTS HLIT HIGH RESOLUTION LITHOLOGY COUNTS HSS~ HIGH RESOLUTION SHORT SPACING ! COUNTS H$$2 HIGH RE$ObUTZON SHORT SPACING 2 COUNTS HPEF HIGH RESOLUTION PHOTO-ELECTRIC FACTOR HRHO HIGH RESOLUTION BULK DENSITY HDRHNRHO HIGH EnhancedREsObU[VeIoNtiCalD~.~$ITyReS°luti°nCORRECTIoNDensity PFDC POrOSity from the FDC TOOl PNND DENSITY POROSITY CALCULATED FROM THE ENHANCED RHOB m~)~M~MMm~mmmm*m~m~mmmmmmmmmmm~mm~M~)mmmmmmmNmmmmmmmmmm PAGEI DATA FORMAT SPECIFICATION RECORD bET TYPE - 64EB ** mmmMm~mmmmmmmmmmmmmwmm~m~m~mm TYPE REPR CODE, VALUE m~m~mm~mmmmmmmmmmMmmmmmN~mmmm I 66 0 2 66 0 3 73 76 4 66 5 66 6 73 7 65 8 68 0~083 g 65 ~07 11 66 . 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 LiS Ta~e YetiS!cation ~istin $¢blu~berqer ~las~a Com~utin~g Center 27-APR-tgg2 08:57 SET TYPE '''''''''''''''''''''''''''''''''N SERV I RVICE A APl ..... API''''[;'''''''''';~'I FILE NU ......... NUMB SIZE'''''''''''''''''''''R PROC ID ORDER ~ tOG TYPE: CLA'SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548510 O0 000 O0 0 4 1 i 4 68 0000000000 HPEF LDH 548510 O0 000 O0 0 4 I [ 4 68 0000000000 HNRH LDH G/C3 548510 O0 000 O0 0 4 ! 1 4 68 0000000000 HPHN bDH PU 548510 O0 000 O0 0 4 1 I 4 68 0000000000 HRHO LDH G/C3 548510 O0 000 O0 0 4 1 1 4 68 0000000000 HDRH LDH G/C3 548510 O0 000 O0 0 4 1 ! 4 68 0000000000 HDPH LDH PU 548510 O0 000 O0 0 4 1 I 4 68 0000000000 HLL LDH CPS 548510 O0 000 O0 0 4 ! i 4 58 0000000000 HI, U LDH CPS 548510 O0 000 O0 0 4 1 I 4 68 0000000000 HLS LDH CPS 5485t0 O0 000 O0 0 4 1 I 4 68 0000000000 HLIT LDH CPS 548510 O0 000 O0 0 4 ! 1 4 68 0000000000 H,SSi LDH CP,5 548510 O0 000 O0 0 4 ! ! 4 68 0000000000 H8S2 LDH CPS 548510 O0 000 O0 0 4 1 i 4 68 0000000000 HPEF CRC 5485t0 O0 000 O0 0 4 ! 1 4 68 0000000000 HRHO CRC G/C3 5485!0 O0 000 O0 0 4 ! t 4 68 0000000000 NRHO CRC G/C3 548510 O0 000 O0 0 4 1 I 4 68 0000000000 HDRH CRC G/C3 548510 O0 000 O0 0 4 1 1 4 68 0000000000 PFDC ,SAN PU 548510 O0 000 O0 0 4 1 i 4 68 0000000000 PHND SAN PU 5485!0 O0 000 O0 0 4 1 1 4 68 0000000000 '54 DEPT, HRHO, L,D.H HSS , bOH HDRH,CRC DEPT HRHO bDH HbU LDH H,5,52 LDH HDRH CRC DEPT HRHO [,DH HL~ LDH H88 bDH HDRH CRC DEPT,., HRHO,LDH HLU, LDH H$S2,LDH HDRH,CRC 348:270 293,149 0,i14 1080i,000 ' ,423 25 ,493 265,2i7 0,032 ~167 0,019 HPEF LDH HDRH LDH H~$. HPEF CRC PFDC HPEF,bDH HDRH,bDH HbSeLOH HPEF,CRC PFDC,'SAN HPEF~bDH HDRH,bDH HL~,LDH HPEEeCRC PFDC,SAN HPE~ LDH HDR bDH HL$ LDH HPEF CRC PrOC SAN 0 000 0 114 444 362 -99~ 4,741 0,011 2'/8,149 8,?18 .12,165 4,300 0,196 I, 19 ,$04 ,221 11.124 HNRH LDH HDPHibDH 18 HblT bDH 47 HRHO,CRC 2 PBND,$AN 17 HNRH,bDH HDPH,bDH H, LIT,bDH HRHO,CRC PHND,SAN HNRH [,DH HDPH:bDH HLIT LDH HRHO:CRC PHND,,SAN HNRH,bDH HDPH,bDH HLIT,bDH .HRHO,CRC PHNO,SAN 43~ HPHN,bDH 17 HLL,LDH 583 HSSl,I, DH 367 NRHO,CRC ~76 i ,043 ,1 1,309 1486'121 ,903 207',525 2,455 [,~$ Taue Verification [,istlno ,Scl~lumberqer AlasKa Computing Center **** FfhE TRAIt, ER **** FILE NAME : EDIT .004 SERVICE : F~IC VERSION : 001A07 DATE : 92/04/27 MAX REC SIZE ; 8192 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01A07 DATE : 92/04/27 MAX REC SIZE : 8192 FIL~ TYPE : LO LAST FILE 27-APR-1992 08:57 55 , '* FILE - EDIT,O05 * * * cOMPANY NAME: conoco INC, * WELL: BA.DAMI * rlZbP: WI.LDCAT REPEAT PASS RUN #2 HIGH RESOLUTION CNL DATA SAMPLED EVERY -.166667 FEET DATA INCLUDED,- 'TOOt, EXTENSION TOOL TYPE USED NAME CNL ,CNH COMPENSATED NEUTRON bOG CNL 'CRC & ,SAN ENVIRONMENTALLY CORRECTED COMPENSATED NEUTRON Tape Verification btsttnq SChlumberger AlasKa Computtnq Center 27-APR-~992 08:57 PAGE: 56 TYPE t CONS TUN! VALU mm~mmmmmmmmmmmmmmmmmmmeemmmmmeemmmmmmmme~e~mmmmmmmmmmmmmmmmmmmmmmmmmm CN CONOCO INC, FN WILDCAT WN BADAMI #2 APlN 50-029-22230 FL 2900' FNL & 700' SECT 30 TOWN tON RANG 20E COUN NORTH 5LOPE STAT ALASKA NATI USA WITN ME~CER/HAND/POYbA SON 548510 PDAT EPD FT 0 APD EKB FT 37, EDF FT 36, EGL FT TDb. FT BL! FT 11833' TLI FT 445. ' DFT GENERIC #2 DFD G/C3 I 5 DFPH 9 ~00001 DFV $ RMS OHMM 1 85 MST DEGF RMF8 OHMM MFST DEGF R~CS OH~ 2 ~2 MCST DEGF 5 BHT DEGF mm~mM~mmmmmmmmm~mmmmmmmm~mmmMmmmmmNm~mmm ! (m # m mm ~m # # ~M ~)) mm # m ~mm ~1 m ~m mm mm m m mm m ~ m m m m m DEFI Company Name Field Name Well Name API Serial Number Field Location Section Township RanQe County State or Prov~nce Nation Witness Name Service Order Permanent Oat Elevation of boq Measured AboVe ~ermane Elevation Of Elevation of ~levation o~ oral Depth - Total Depth - Bottom Log In Top Log Intel Dr$11tn,~ Flu Drlllin,~ FlU Drllltn,~ FlUi Drillin,~ Flui DrIII. tn,]..FIUi ReSlSti}tty_o Mud. Sam)la Te Mud,.FllCr . Resisttvt o Mud Cake ~Im~ Bottom Hole mmmmmMmmmm~mM Numbe~ um Permanent Datum From t Datum .. rr&cR Floor ~[ll¥1,'Bushlnq ound bevel tiller terval d d viscosity d boss . f Mud'Sample mperature' f MUd Filtrate S Sample Temperatu f Mud Ca~e sampl le. Temperaturem emperac~re,. ,.. TABLE TYPE t CURV RHFT RH, N~ H?N HCNT NPOR epthIGH RESOLUTION RAw FAR ~HERMAb CORRECTED COUNTS H.I~ RESOLUTION RAW ~EAR THERMAL'CORRECTED COUNTS HI~. RESOLUTION THERMAL NEUTRON POROSITY'(ENVIRONMCN?Abb¥ CORR~CT~D) HIGH RESOLUTION CORRECTED NEAR,~H~RMAb COUNTS Neu, t~on Porosity from an Application Program £,~ ?ape Verification bisttnq 27-APR-lgg2 o8~57 ScnlUmberger Alaska Computing Center ' DEF! ....... .... . .... . ....... T PH Thermal eutron Poros t¥ 0 NPH! Neutron Porosity ,e PAGE! DATA FORMAT SPECIFICATION RBCORD ** SET TYPE - 64EB ** TY DE . VAL, U I 66 0 2 66 0 3 73 4O 4 66 1 5 66 ? 65 1~ 66 2O4 12 68 1] 66 0 14 65 FT 15 66 68 16 66 ,0 66 m~mmm#~mmm~mm~m##m#mmm~m~m~mMm *~ SET TYPE - CH~N ** NAME SERV UNIT SERVICE API APl API AP! FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP gBEM CODE (HEX) FT 548510 O0 000 O0 0 5 1 1 4 68 0000000000 000'0000000 DEPT RHFT CNH RHNT CNH HTNP CNH HNPO CNH H{F? CNH HCN~ CNH NPOR SAN TNPH'BAN NPHI 'SAN CPS 548510 O0 CPS 548510 O0 PU 548510 O0 PU 548510 O0 CPS 548510 O0 CPS 548510 O0 PU 5485 0 O0 PU 5485~0 O0 000 O0 .0 5' 1 000 O0 0 5 1 000 O0 0 5 000 O0 0 5 000 O0 0 5 0'00 O0 0 5 000 O0 0 5 ! 000 O0 0 5 68 68 68 68 68 68 68 000000 000 000000~000 0000000000 0000 ~ oooog 0000000 O0 0000000000 PU 54.8510 O0 000 O0 0 5 1 1 4 68 0000000000 mmm~m~m~*~mm~m~mm)mm~mmmmm~mmmmmmmmmmmmmmmMmMmm~Mm*mmmm~mmm~mmmMmmmmmmmmmmm~Mmmmmmmmmmm~NmMMMm DATA 7 bis Tape Verification [,istln SchlUmberger Alaska C, omputin~ Center DEPT. 10961,000 RHET,CNH HNPO,CNH 4t,826 HCFTeCNH TNPH,SAN 43,930 NPHIeSAN DEPT. 10800,000 RHET,¢HH HNPO.CNH 30,123 HCFT,CNH TNPHoSAN 32.167 NPHZ.SAN DEPT. 10600.000 RHET.CNH HNPOeCNH 31.410 HCFT.CNH TNPH.SAN 31.138 NPHZ.SAN ogP~. 10533.334 RHFT.¢NH HNP .CNH 29.504 HCET.CNH TNBHeSAN 31,$62 NPHI.SAN F~bE NAME I EDIT ,005 SERVZCE I rbIC VERSION I OOlA07 DATE I 92/04/27 MAX REC SIZE ~ 8192 FIbE TYPE : bO bAST Elbe : FILE NAME I EDIT ,006 SERVICE : Fb~C VERSION : 001A07 DATE : 92/04/27 MAX REC SIZE I 8192 FILE TYPE : bO bAST FI. bE .: 27-APR-~992 08:57 4~6.242 RHN?:~NH 1927.734 H?NP.CNH 449.604 HCNT NH 1819 098 NPOR SAN 3.930 ' 768,790 RHNT,CNH 2669.239 HTNP.CNH 817.399 HCNT.CNH 2448 516 ~POR SAN 32.~67 ' ' 86~.025 RHNT,CNH 2687,787 HTNP,CNH 905.766 HC~T.CNH 2650 463 NPOR,$AN 3~.138 ' 782.~5 RHNT.CNH 2464 255 H?NPeCNH 31.562 ' PAGEI 58 .826 ,930 31,207 32,110 2~,727 3 .196 30.303 31,562 ,. $ COMPANY NAME: CONOCO INC,. WEbbl BADAM! ~2 FIEbDi WIbDCAT REPEAT PASS RUN #2 Tape Verification Listing $,.hlumberqer Alaska Computin~ Center 27-APR-t992 08=57 PAGEt 59 DATA 8AMPbED EVERY -,5000 FEET DATA ZNCLUDED - TOOL EXTENSION TOOL TYPE USED NAME DITE ,DT2 DITE ,PR2 bSS ,bS2 NGT ,NG2 NGT .K~2 PHASOR DIJAb INDUCTtDN- SFL COMPUTING CENTER PHA$OR PROCESSED DATA LONG SPACED SONIC NATURAL GAMMA SPEC, CtlRVgS COMMON TO AL[j NGT RUN #2 REPEAT DATA ' ' NATURAt GAMMA SPEC,(KA[,MAN FILTER) * NGT ,AL2 NATURAL GAMHA SPEC,(ALPHA FILTER) * AIT ATR ARRAY INDUCTIDN TOOL (6" SAMPLED DATA) TABLE TYPE = CONS TUNI VALU DEFI . CN CONOCO INC, Company Name Field Name FN WILDCAT NN BADAMI #2 APIN 50 0~g-22230 rb 27~0 'FNE & 700' SECT 30 TOWN ON RANG ~0~ COUN NORTH SLOPE STAT ALASKA NAT! USA WXTN ~ERCER/HA'ND/POYbA SON 548510 PDAT EPD FT APO FT 37, EKE FT 37, EOF rT 36, TDD FI TDb FT ELl FT 11833, TLI FT 445~ DFT GENERIC DFD G/C3 DrPH 9.70000! DFV 8 56 DFb F3 4,~ MST DEGF RMF8 OHMM ~ell Name AP! Serial Number Field Location Section Township Range County State or Province Nation witness Name Service order Number Permanent datum ~levation of Permanent Datum bog Measured From Above Permanent Elev~levatt°n of Kell ~b~l°°f glev~lon of Derrlc on of Gro~d. vel Total Depth : Driller Total Depth Logger Bottom Lo~ InterOal Top Log I6terval ' Drillin~ Fluid Type.. Orillinq rlu!d Density Oril~,in~ Fluid Ph .,. Drtllin~ Fluid Viscosity l§ttVity ot Mud.iSample ~ud..aample. Temperatute. Resistivity of Mud Filtrate Tape verification Listinq Schlu.mner,qer Alasl<a Computing Center 27-APR"ir92 0~:57 PAGEi 60 TUN! VA[,U DEF! ,. ~FST DEGF 52 Mud Filtrate Sample Temperatu RMC8 OHM~ 2 ~2 Resistivity of ~ud CaKe Sem~l · ~ud Ce~e Sample Temperature TABLE TYPE = CURV DEPT CIDP IDpH CIMP I~PH CDER IDER C~ER ! ER CDVR IDVR CMVR I~VR CILD I.LD CI~ I~M IDQF IMQF IIRO I'IXD IIX~ SFLU SP CAbS TENS HTEN MRE$ MTEM PT DTb DTLN DTLF G~ CGR URAN THOR POTA SGR DEF! ..... '"'"";"'"'"'""'"'"'" N UCT PHASOR CONDUC IVITY INDUCTION DEEP PHASOR RESISTIVITY INDUCTION MEDIUM PHASOR CONDUCTIVITY INDUCTION MEDIUM PHA$OR RESISTIVITY DEEP INDUCTION ENHANCED RESOLUTION PHASOR CONDUCTIVITY DEEP INDUCTION ENHANCED RESOLUTION PHA$OR RESISTIVITY MEDIUM INDUCTION ENHANCED RESOLUTION PHASOR CONDUCTIVITY MEDIUM INDUCTION ENHANCED RESOLUTION PHASOR RESISTIVITY DEEP INDUCTION VERY'ENHANCED RESOLUTION PHA$OR CONDUCTIVITY DEEP INDUCTION VERY-ENHANCED RE~O~UTION PHA$OR RESISTIVITY MEDIU~ INDUCTION VERY'ENHANCED RESOLUTION PHASOR CONDUCTIVITY ~EDIUM INDUCTION VERY-ENHANCED RESOLUTION PHASOR RESISTIVITY Conductivity IL Deep Standard Processed Deep Induction Standard Progessed Reslst.~vlt¥ Conductivity I5 ~edium Standard.'Processeo Hedium'Induction Standard Proce§s~d Resistivity 'IDGF DEEP INDUCTION GUA~ITY FACTOH "!HGF ~ED INDUCTION OUA5ITY FACTOR_, ,, Deep Induction ~eal ln~ermed!ate ~on~uctivit¥ Deep Induction uuad Ingermedla~e Conductivity Hedlum Induction Real Intermed!ate ~onductlv!ty ~edlum Induction Guad Intermediate Conductivity SF5 Resistivity Unavera~ed ~pontaDeous Potential " Gamma $oni~ Caliper Tension Head Tension ~UD Resistivity Mud, Temperature DELTAoT DELTA"T LONG SPACING DE~TA*T LONG SPACING NEAR DTbF Gamma Ray pectFoscopy Gamma Ray ompgced Gamma R,a¥ Uranium Thorium Potassium Spectroscopy Gamma Ray b'IS Tape Verification 61st~nq ~chlum~e~qet Alaska Computlno Center 27-APR-lgg2 08:57 .DEF! CGR Computed Gamma Ray THOR Thorium URAN Uranium PO?A Potassium WiNG Window 1 (.,150 - ,5 Mev) W2NG Window 2 (,5 - ! 1 Mev) W3NG Window 3 (1.! - ~.6 Mev) WSNG Window 5 (2' 3 Mev) CS Cable Speed TENS Tension HTEN Head Tension MTE~ MUd Temperature ~RES MUD Resistivity GR ~ammp Ray SP spontaneous Potential HTEN Head Tension TENS Tension DATA FORMAT SPBCIFICATIDN RECORD SET TYPE - 64EB ** TYPE REPR CODE V~6UE [ 66 0 2 66 0 3 73 24O 4 66 5 66 6 73 7 '65 B 68 0 5 11 66 1~ 68 1 66 0 14 65 FT !~ 66 68 1,6 66 1 0 66 1 mmm~mmm~mmmmmmmMmmmmMm~mmmmM~m PAGEt 61 Tape Verification btsttno $,chlumberqer AlasEa Computin~ Center 27-APR-1992 08t57 SET TYPE - CHAN ** AME 'SERV NI? SERVICE API AP[ A I AP[ FILE ~ ?. REPR PROC£$S' ID ORDER it bOG TYPE CbASS NOD NUMB SA~P gLEN CODE (HEX) DEPT FT 548510 O0 000 O0 0 6 1 ! 4 68 0000000000 CIDP PH2 IDPH PH2 CIMP PH2 I~P~ PH2 CDER PH2 IDER PH2 C~ER PH2 I~ER PH2 CDVR PH2 IDVR PH2 C~VR PH2 I~VR PH2 C~D D?2 C[b~ DT2 IbM DT2 ID~F DT2 IM~F DT2 IIRD DT2 'IIXD DT1 IIRM DT I)XM DT SFbU DT2 DT2 CAbS D~2. ~ENS D~2 HTEN DT2 ~EES.DT2 PT DThF b52 GE L. S2 SGR KA2 CGR KA U~AN TUOR P~TA KA 8GR Ab2 CGR Ab2 THOR Ab2 URA~ Ab~ POT Ab2 WIN~ NG~ W2N NG2 W{NG NG2 W NG NG2 mmHO 548510 O0 OHMM 5485~0 O0 MMHO 548510 O0 OHMM 548510 O0 MMHO 548510 O0 OHMM 548510 O0 M~HO 548510 O0 OHMM 548510 O0 MMHO 548510 O0 OHMH 548510 O0 MMHO 548510 O0 OHMM 548510 O0 MMHO 548510 O0 OHMM 548510 O0 MMHO 548510 O0 OHMM 548510 O0 548510 O0 548510 O0 MMHO 548510 O0 MMHO 548510 O0 MMHO 548510 O0 MMHO 548510 O0 OHMM 5485i0 O0 MV 548510 O0 GAP! 548510 O0 IN 548510 O0 bB 548510 O0 bB 5485 0 O0 OHMM' ~18510 O0 DEGF.. 8510 O0 us/r 548510 O0 us/r 5485 ~! $4851O O0 PPM 548510 O0 PPM 548510 O0 PU 548510 O0 GAP! 548510 O0 ~P! 548510 O0 ~ 548510 O0 PPM 548510 O0 .PU 548510 O0 0 O0 CPS 548.510 0 CPS 5485 0 CPS 548510 O0 CPS 5485i0 O0 000 O0 0 6 000 O0 0 6 1 000 O0 0 6 1 000 00 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 ! 000 O0 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 1 000 O0 0 6 000 O0 0 6 000 O0 0 6 1 000 O0 0 6 1 000 O0 0 6 000 O0 0 6 1 000 O0 0 6 000 O0 0 6 000 O0 0 6 1 000 O0 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 1 000 0 6 ooo o ooo oo o 000 00 0 6 000 O0 0 6 000 O0 0 6 000 00 0 6 0O0 O0 0 6 000 O0 0 6 ! 000 O0 0 6 000 O0 0 $ 000 O0 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 000 O0 0 6 1 000 O0 0 6 1 000 O0 0 6 000 O0 0 6 ! 000 00 0 6 000 O0 0 6 1 000 O0 0 6 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 ~ 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1, 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 O0 t 4 68 0000000000 O0 000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000. 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 62 ?aoe Ver? cat?on ~Lst/n $,chlUmberger Alaska Computtn~; Center 27-APR-]992 0R:57 PAGE~ 63 N E SERV UNI SERVICE APl AP1 PI FI£,E NU UMB i$IZE REPR PROCESS ID ORDER # bOG TYPE CbASS MOD NUMB SAMP EbEM CODE CHEX) '''''''''''''''''''''''''''''''''''''''''''''''''''''''W NG2 CPS 549510 O0 000 O0 6 1 ....... 1 '''''''''''''''''''''''''4 6 . 000000 F/HR 548510 O0 000 O0 0 6 ! ! 4 68 0000000000 CS ND2 TENS NG2 HTEN NS2 M?EM NG2 NRES NG2 GR ATR SP ATR HTEN ATR 6R 548510 O0 000 O0 68 548510 O0 000 O0 DES? 549510 O0 000 O0 OHMM 548510 O0 000 O0 GAPI 548510 O0 000 O0 MV 5485i0 O0 000 O0 0 6 0 6 0 6 0 6 0 6 0 6 I 1 4 69 0000000000 1 1 4 68 0000000000 1 I 4 65 0000000000 1 ! 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 DATA DEPT IMPH PH2 I~ER PH2 IMVR PH2 IbM DT2 IlXO DT2 SP DT~ HTEN DT '8GR KA2 POTA KA2 URAN Ab2 W3NG GR.ATR DEPT' IMER PH2 IMVR PH2 Ib~ 2 IZXD ~2 SP D~2 H?EN DT2 DTb bS 8GR KA) POTA KA2 URAN Ab2 W3NG NG2 TEN8 NS2 OR ATR DF, P? IMPH;.PH2 .PR2 110O0°0O0 4.708 4.708 4,705 4.663 20.651 000 81 900 ~999 250 '999 25O "999 250 -999 250 -999 250 -999 250 10800 000 9~109 0 9, 1 7 .832 2.654 2,440 46,036 5900,000 60,095 1060~.000 ,327 ,029 9,619 ClDP.PH2 }~.~65 IDPH,PH2 5 CDER.PH2 ..v v, 80 IDER.PH2 5 CDVR.PH2 190,556 IDVR,PH2 5 CZLD,DT2 191.677 II.,D.DT2 5 IDQF.DT2 0.000 IMOF.DT2 0 IIRM,DT2 201,478 IIXM,DT2 14 GR~DT2 1'09.791 CAbS,DT2 ~R~$.DT2 0,614 MTEM.,DT2 16 8 DTbN,bS2 82.900 DTbF,bS2 83 CGR,KA2 '999.250 URAN,KA2 -999 9 POTA, '999:50 W1NG, 2 -999 W4NGeNG2 ~999,~50 WbNG,~G2 -999 HTEN. NG2 -999,.50 MTEM. NG2 -999 SP.ATR -999,250 HTEN,ATR -999 CIDP,PH2 CDER,.PH2 CDVR.P~ CIbD,D~ IDQF.DT GR,DT MRE$,DT~ bS DTLN.KA~ CGR. POT~ A62 Ab2 W4NG NG2 HTEN NS2 SP ATR CIDP PH~ CDER PH CDVR PH2' CIbD iDT2 99.997 IDPH,PH2 100.579 ZDER,PH2 98.965 IDVR.PH2 101.561 IbD.DT2 , 53 IIXM,DT2 ! 8,951 CAbS DT2 0.616 MTE~!DT~ 81.500 DTLF 682 6~.594 URAN KA2 1,! .393 yGR.A62 2.715 W NS,NS2 .207 W5NG,NG2 500 .147 ~TEM,.NG2 -22,813 HTEN,.ATR 9).5~5' IDPH,PH2 1~ ..136 IDER.PH2 19~.216 IDVR,PH2 .243 II..D,DT2 72 CIMP.PH2 ~61 CMER.PH2 PH CIbM. 00 IIRD,DT2 ~94 SFbU.DT2' 0 DT,b$2 300 _ GR',b$2 250 THOReKA2 50 W2NG, 2 50 MRE$.NG 250 T£N$,AT 10 '~ CiRP,PH2 g: CMER,PH2 0.105 C~VR,PH2 19.846 CIbM.DT2 0.000 IIRD DT2 , 7:393 SFbU:DT2 15 168:~13 TENS.DT~ 05 DT,~$ 81 800 _ GR,552 21 19 99 469 TH ,NS2 23~ 202 W2~''Ab2 696 ,.NG~ 170 158 MR~.NG2 1~.470 ClMP,PH2' 9,696 CMER,PH2 i0,241 CMVR,PH2 .390 CZbM.DT2 21 3 21~ 554 21 458 -99' $0 -99' ~$0 -99 250' 1 697 88 84. 649 0 83 100 8 951 59 586 25 9 6795 0 0 11 2,5. bt's Taue Verification btstlnq schlumberqeg Alaslca ¢omputtnq Cente~ IbM.DT2 ZIXD,DT2 SP.DT2 HTEN,DT2 DTt.,bS2 SGR.KA2 POTA.KA2 URAN.Ab2 W3NG.NG2 TENS,NG2 GE,ATE DEPT IbM IIXO SP H?EN OTb SGR POTA URAN W3NG 27-APR-1992 08557 ~H2 PH2 PH2 D?2 DT2 DT2 DT2 b$2 KA2 KA2 TENS.NG2 GE.ATE ~MpH IMVR H?EN POTA U~AN W NG TENS GR ,'PH2 PH2 PH2 AIR ? IM~ PH2 ITXD SP HTEN .DTb POTA DT2 KA2 64 ~.~55 IDOF.DT2 10~,~I0 IMOF.OT2 ~,000 IIRD,DT2 . 83 IIRMeDT2 , ~ ITXM,DT2 798 SrbU.OT2 -~,125 GR.DT2 5~.~0 CAbS,DT2 13'750 TENS DT2 6620 932o662 MRES.DT2 0 62. ~67'404 ' .449 55.~ 9 DTbr,bS2 8 ,600 GR,LS2 5 URAN,KA2 5~9 ?HOR,KA2 ~,236 SGR.Ab2 105.~ ¢GR.Ab2 81:031 THOR.Ab2 . WSNG.NG2 13.807 .000 HTEN.NG2 4910. ? MT~M..~G2 169 020 MRE$.NG2 58.355 SP..ATR -23.43~ HTEN,ATR 694:573 TENS.ATE 43 oo 627 6215 000 10400.000 6,285 6,263 206 15.880 '2i.688 927 296 83 200 -999 250 -999 250 -999 25O -999 250 -999 250 -999 250 CiDP. PH2 ¢DER. PH2 CDVRiPH2 CIbD. DT2 IDOF. DT2 IIRM DT2 GR DT2 MRES DT2 DTbN b82 CGR.KA2 SGR.Ab2 POTA..Ab2 W4NG,NG2 HTEN,NG2 SP.ATR 152 390 154 ! 151 92 66 0,626 83.100 .250 -999.250 -999,250 -999.250 .-999,250 [DPH.PH2 IDER.PH2 IDVR.P~2 ILD DT2 IMQF:DT2 IIXM.DT2 CAbS.DT2 MTEM.DT2 DTbF.b$2 URAN.KA2 CGR.Ab2 WlNG,NG2 WSNG.NG2 MTE~ NG2 MTE~AT~ 6.562 CI~P.PH2 6.474 CMER.PH2 6.399 CMVR.PH2 449 CILM.DT2 ~ 000 IXRD,DT2 t 888 SFLU.DT2 648 TENSeDT2 DT.LS2 G~,b$2 THO ,KA2 -999 -999 999 -999 -999 704 700 250 250 THOR.Ab2 250 W2NG.NG2 250 CS.NG2 250 MRESeNG2 250 TENS,ATE 159 6 64O0 66 '999 -999 -999 -99~ "999 t0! 668 285 288 000 25O 250 2..$O 10200,000 .992 .121 7,199 6,904 1~,.719 1~1 ,250 36,450 82.800 -~99,250 - 9~250 -999,250 -999,250 -999,250 "999,250 ClDP.PH2 CDER PH2 CDVR PH2 ClLD DT2 IDOF DT2 IIRM DT2 GR DT2 MRES DT2 DTLN bS2 CGR,KA2 SGR.AL2 POTA. Ab2 HTEN.NG2 $P,ATR 142 361 352 144 354 3~ 000 7~6 166 614 0 634 81 600 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 IDPH,PH2 IDER.PH2 IDVR.PH2 IbD.DT2 IMOF.DT2 IIXM DT2 CAbS:DT2 MTE~.DT2 DTLF,LS2 URAN.KA2 CGR.AL2 WING.NG2 W5NG.NG2 MTEM,NG2 HTENeATR 7 024 CIMP.PH2 7 338 CMER.PH2 7 '388 CMVR,PH2 927 ClbM DX2 ~ 000 IIRD DT2 11 .731 SFLU DT2 i3 :138 TENS DT2 164 153 DT bS2 82 300 GR bS2 -999 .250 THOR KA2 -999 250 THOR Ab = 250 C8,NG2 -999 250 MRES,NG2 -999 250 TENS.ATR 43,022 0~427 ,843 ! 7i282 6 2o.ooo 82 6OO 66 614 !0000 000 08 66 08~ 6 006 5 962 i88 898 743 82 400 '999,250 '999,250 "CIDP.PH2 CDER PH2 CDVR 'PH2 CXLD DT2 IDQF DT2 IIRM DT.2 GR DT2 MRE$ DT DTLN DSt CGR KA2' SGR AL2 61.859 59.870 162.097 164,181 0 000 158 O8O 65 797 8~ 647 20O '999 250 "999 250 IDPH.PH2 IDER,PH2 IDVR.PH2 ILD,DT2 IMQF.DT2 IIXM,.OT2 CALS,DT2 MTE~,.DT2 DTL ,LS2 URAN.KA2 CGR.Ab2 6 178 ClMP PH2 6 255 CMER PH2 6 169 CMVR PH2 6 0 12 13 ~8 -999 -999 091 ClLM 000 I RD 345 S~LU 046 TENS 856 PT 000 GR 250' THOR 250 THOR DT2 DT2 DT2 164 164 166 167 ,143 , 5 6350 '82 · 65 '999 489 000 Tape vertttcation btsting SchlUmeetqet Alaska Computing Center URRN,Ab2 W3NGeNG2 TENS.NG2 GReATR IMPH PH2 ZMER PH2 IMYR PH2 !bM DT2 IIXD DT2 SP DT2 HT£N DT2 D~b b$2 SGR KR2 POTA KA2 URAN Ab2 W3NG NS2 T£N8 NG2 GR ATR DBP?, ZMPH,PH2 I~ER~PH~ ZMVR~PH IbMeD~2 ~IXD.DT2 SP DT2 HTEN .D?b SGR KA2 PO?A KA2 URAN Ab2 W3NG ~G2 TENS G2 GR ATR D£PT I~PH PH2 I~ER PH2 I~¥R PH2 I~X.D gT2T2 SP PT2 HT~N DT2 DTL SGR KA PO?A KA2 U~RN Ab2 ~3NG NG2 TEN8 NG2 GR ATR ,250 POTA.Ab2 -999,250 HTEN.NG2 -999o250 SPeATR 5, CDE~'PH ,PH2 5.682 CDVRePH2 5.641 CILD.DT2 5,5~4 IDQF.DT2 ~9.0 7 IIR~.DT2 '27.063 GR.DT2 922,101 ~.RE$.DT2 83.700 DTbN.L&2 -999.250 CGReKA2 '999,250 SGR.AI.,) '999,250 POTA,A5 -999.250 W4NG,NG2 -999,250 HTEN.NG2 -999.250 SP.ATR 9600 000 5 918 5 735 5 582 5 ~55 18 59 -29 688 911 ~40 83 400 -999 250 '999 250 -999 250 -999 250 -999.250 '999.250 9400,000 5,564 5 5 401 19 180 -29 813 883,,588 , 84,700 999,250 '-9991250 -999~250 -999.,250 '999,250 "999,250 ClDP,PH2 CDER.PH2 CDVR, PH2 CILD, DT2 IDOF, DT2 IIRN. DT2 OR DT2 MRE$ DT2 DTLN LS2 CGR KA2 SGR AL2 POTA AL2 W4NG NG2 HTEN'NG2 SP:ATR ClDP.PH2 CDER.PH2 CDVR.PH2 ClLD DT2 IDOF:DT2 ~IRM,DT2 GR.DT2 MRES.DT2 DTLN,L82 CGR.KA2 SGR,A~2 POTA.Ab2 W4NG,NG2 HTEN.NG2 SP,ATR 27-APR-1992 08~57 -999.250 WlNG.NG2 -99~,250 W5NG.NG2 -99 ,250 NTEN.NG2 -999.250 HT£~.ATR 17~.972 IDPH.PH2 16 .580 IDER.PH2 169.741 IDVR,PH2 173.032 ILD.DT2 0.000 I~GF.DT2 170,750 IIX~.DT2 77,206 CAtS,DT2 0.658 ~TEM.OT2 8~.800 DTbF.LS2 '99 .250 URa~.KA2 '99~.250 CGR.Ab2 '99 .250 W1NG.NG2 '999.250 W5NG.NG2 -999.250 MTEM.,NG2 '999.250 HTEN.ATR 156.317 165.685 170.998 157,.~43 0.000 .~58. 0 669 8t 100 '999 250 -999 250 '999 250 '999 50 '999 ~50 ~"999250 76 817 °o '999. 0 '~999. 0 -999.250 IDPH,PH2 IDER,PH2 IDVR,PH2 IbD.DT2 IHQF.DT2 IIX~.DT2 CALS.DT2 ~TE~,DT2 DTLF,LS2 URAN.KA2 CGR.AL2 W1NG.NG2 W5NG,NG2 MTEM,NG2 MTEN,ATR IDPH.PH ~ IDER,PH IDVR.PH2 ILD.DT2 IgQF.DT~ IIXM,DT CALS,DT2 MTEM,DT2 DTLF,LS2 URAN,KA2 CGR,Ab2 WiNG,NS2 WSNG.NG2 MTEM.NG2 HTEN,ATR -999,250 W2NG.NG2 -999.250 CS,NS2 -gg9.250 MRES.NG2 -999.250 TEN$.ATR . CMERoPH 5,891 CMVR,PH2 5.779 CILM.DT2 0,000 IlRD.DT2 13.676 SFLU.DT2 13.821 TENS.DT2 159.842 DT.L$2 82,700 _ GR,LS2 -999,250 THORoKA2 -999.250 THOR.Ab2 :999.250 ~2NG.NG2 999.250 C$.NG2 -999.250 MRES,NG2 -999.250 TEN$,ATR 6.397 6.036 364 CIHP PH2 CNER PH2 CMVR PH ClbH DT~ : 000 IIRD 1 971 SFLU 14,i03 TENS 157.364 OT 5O -999.250 -999,250 -999.250 -999.250 5 5 0 12 13 155 -99 -99~ -999 656 CMVR 914 ClbM 000 IIRD TENS 228 DT 600 GR 250 THOR 250 THOR 250 W2NG DT2 DT2 DT2 L$2 GR LS THOR KA~ THOR AL2 W2NG ~ N 2 CS,N 2 MRgS,NG2 TEN$.ATR PH2 250 MRES NS2 250 TENS.ATR -999.250 -999,250 -999,250 -999,250 176 ~68 175 79 177 173 181 47 75 6205 §00 85 O0 77 ~06 -999 50 '999 250 -999 250 '999250 '999 250 -999 250 168 79 174 178 179 50 138 Im 6oi) 8O0 69 82' '999 ~SO -999 250 -999 250 '999 -999 250 185 148 459 99 ,,71 164 -999 50 -999 250 -999 250 -999 50 '999 ~50 '999 250 Tape Ver:[A~ication blstlnq hlum~erger las~:a Computinq Center 27-APR-1992 0H157 D£PT IMPH PH2 IMER PH2 IMVR PH2 IbM DT2 IZXD D?2 8P DT2 H?EN D?2 DTL bS2 8GA KA2 POTA KA2 [IRAN Ab2 W3NG ?£NS NG2 GR ATR D£PT IMPH PH2 I:ER PH2 VR PH2 IIb~ DT2 IIXD DT2 SP DT2 HTEN DT2 DTb b82 SGR KA) POTA KA URRN Ab2' W3NG NG2 TENS NG2 GR ATR DEPT. IMPH,PH2 ~MER,PH2 IMVR PH2 IbM DT2 IIXD DT SP HTEN D?2 DTb EGR KA POTA KAl NG2 TENS NG2 GR ATR IMER PH2 [XXD DT.2 EP DT2 9200.000 5.093 5.091 5.163 5L098 20.378 -32.125 900,516 86,500 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 9000,000 5,085 5.105 5,170 5,005 198894 ,236 ~999,.250 999;250 "999,250 ~999,250 "999,250 "999,250 ,000 880~,924 6,909 6.862 6,669 15,'784 -42~'188 889 934 87 200 '-999 250 -999 250 -999 250 -999 250 -999 250 '-999 250 8600,000 5.419 5 351 5 .248 5 386 -33 8 CIDP.PH2 182,394 IDPH,PH2 5.483 CIMP,PH2 CDER,PH2 183,001 IDER.PH2 5.464 CMER,PH2 CDVR.PH2 181.t00 IDVR.PH2 5.522 CMVR.PH2 CILD,DT2 184,916 ILD.DT2 5,408 CILM.DT2 IDOF,DT2 ~.000 IMOF.DT2 0.000 IIRD,DT2 IIRM.DT2 18 ,523 IIX~.DT2 ~.~ SFLU.DT2 GR.DT2 6~.920 CALSoDT2 ~ o~. TENEeDT2 MR£S,DT2 .696 MTE~.DT2 1~.~ DT,LS2 DTbN,bS2 88.300 D?LF,b$2 o~ ow. GR,bS2 EGR,Ab2 99.250 GA.Ab2 - THOR,Ab2 . POTA,Ab2 -999.250 WINGeNG2 -999,250 N2NG,NG2 W4NG.NG2 '999.250 W5NG.NG2 -999,250 g§,NG2 HT£N.NG2 -999.250 MT£M.NG2 -999.250 MR~=,NG2 SP.ATR -999.250 HTEN.ATR -999.250 TEN$.ATR CIDP.PH2 ClLD DT2 IDGr D?2 IIRHD?2 GR DT2 MRE$.DT2 DTLN CGR KA2 8GR Ab2 .POTA Ab2 W4NG NG2 H~EN NG2 EP 204 181 I 541 186 576 0 000 87 891 1'63 786 8~ 706 700 -999 2~0 "999 2.0 "999 250 '999 250 -99~ 250 -99 250 IDPH,PH2 IDER,PH2 IDVR,PH2 IbD,DT2 IMGF,DT2 IIXM,DT2 CALSeDT2 MTEM.DTt DTLF,LS URA~,KA2 CGR,AL2 WING,NG2 W5NG,NG2 M?EM,NG2 5. CMER PH2 5,508 CMVR PH2 5,360 CIbM DT2 0,000 IIRD DT2 13,674 SFLU DT2 14 150 86 -999 -999 -999 -999 -999 -999 20 TENS DT2 07 DT bS2 400 C$~NI2 250 ~RES,NG2 250 TENS.ATR C'IDP.PH2 CDERePH2 CDVR.PH2 CILD.DT~ IDQF,D~ IIRM,DT2 GR,D?2 MRE$ DT DTLN CGR KA2 8GR Ab2 POTA A62 W4NG NG2 H~N NG2 EP ATR [I0.653 141 '441 .357 14~.231 ,000 141.538 55,827 0 72O 8~ 500 -99 250 e999 250 -99~ 250 -99 250 -999 250 -999 250. IDPH,PH2 DER,PH2 '~DVR,PH2 ILD DT2 IMGF DT2 IIXM DT2 CAbS DT2 MTEM DT2 DTbF bS2 URAN,KA2 CGR.Ab2 W1NG.NG2 W5NG,NG2 MTEM,NG2 HTEN,ATR 7,.110 i070 ,025 6 0 10 13 148 83 -999 -999 -999 -999 CIMP,PH2 CMER,PH2 CMVR.PH2 33CI 2 O0 II~ DT DT2 770 D~2 655 DT LS2 400 GR bE1 250 THOR KA 250 THOR Ab 250 W2NG,NG2 250 C$,NG2 250 NRES,NG2 250 TENS,ATR CIDP CDER CDVR CILD IDOr GR PH2 PH2 PH2 DT2 DT2 DT2 DT2 172 1.76 179 172 0 65 129 039 614 988 000 780 783 IDPH,Ptt2 IDER.PH2 IDVR,PH2 IbO.DT2 INOF.DT2 IIXM.DT2 CALS,DT2 5 5 5 5 0 ! 810 CIMP,PH2 681 .PH2 781 CILM.DT2 ooo IZeO:OT2 843 &FbU.DT2 651 TEN$,DT2 PAGEI 66 196,344 196,412 193,683 196,170 16ii351 607~ 213 000 88 900 67 920 -999 250 -999 250 -999 250 -999250 -999,250 -999 250 196644 195 891 193 431 87 786 , 63, -999 250 -999 250 -999 25 -999 25~ -999 50 '"999 5941~ 2 i000 'i I°° .5 27 -9 - ~0 -99 -999 250 · -999 250 '19~ 6 15~ 4 5 _bis Taoe Vertticatlo~ rulsttnq ~'c~lumberoer AlasRa Compu~ln.a. Cen~er 27-APR-1992 08:57 HTEN.DT2 DT5,552 SGR.KA2 POTAoKA2 URAN,A52 W3NG,NG2 TEN$,NG2 GR.ATR DEPT, ZMER PH2 IMVR PH2 IbM DT2 IIXD 0T2 SP DT2 HTEN DT2 DTL SGR KA2 POTA KA2 U~AN g NG NG2 TENS NG2 GR.ATR I~ER PH2 VR PH2 /IbM DT IIXO DT~. SP DT2 HTEN DT'2 TLLS GR KA~ POTA KA2 U~AN AL2 TENS GR,ATR II~ DT2 DT2 SP.D~2 HTEN,DT2 DTL~b$~ SGR,KA2 POTA,KA2 URAN.Ab2 W3NG,NG2 TENS.NG2 878.~ MRES.DT~ ~.72~ MT£~.DT2 146.807 ~[.b82 87, DTLN,~S 8 .90 DTLF.L$2 87,500 ,LS2 -999.~ CGR.KA2 -999.250 U~AN.K~2 -999.250 ~.KA2 -999. SGRoA~2 -999o250 CGR,Ab2 -999.250 ,A~2 -999,2~0 POTA,Ab2 -999,250 WlNG.NG2 -999.250 W2NG.NG2 -999,250 W4NGoNG2 -999.250 W5NG,NG2 -999.250 C$,NG2 -999.250 HTEN.NG2 -999,250 MTEM,NG2 -999.250 MRES.NG2 -999,250 ATR -999.250 HTEN.ATR -999.250 TEN$,ATR 8400.000 4.035 4.108 4.206 3,927 28.410 '34,750 889,959 91,000 -999,250 :999 250 999:250 :999,250 999,250 -999,250 8200.000 3,153 3 O85 3 096 3 249 33 614 "42,875 866,537 91,800 -999,250 "999,250 '999,250 -999~250 "9994250 "999.250 8009,000 ,'.190 ,297 ' ~,472 6.93~ 18 60 -63~688 866,91! 84.200 -999,250 -999,250 -999,250 -999,250 -999,250 SP. CIDP CDER CDVR CILD IDOF IIRM GR DTbN CGR SGR, POTA, W4NG. HTEN, CIDP, CDER, CDV CIb~ IDQF IIRM MRES DTbN CGR POT~ W4NG HTEN CIDP CDER CDVR CILD IDOF IIRM GR DTbN POTA W4NG HTEN PH2 240.003 IDPH.PH2 4,167 CIMP.PH2 PH2 236.823 IDER,PH2 4.223 CMER,PH2 PH2 230.759 IDVR.PH2 4.334 CMVR,PH2 DT2 243.487 ILD.DT2 4.107 CILM.DT2 DT2 0.000 IMOF.DT2 0.000 [IRD.DT2 DT2 238.563 IIXM.DT2 17.723 SFLU,DT2 DT2 56.990 CAbS,DT2 12.890 TENS.PT2 DT2 0.739 MTEM.DT2 144.963 DT,LS2 bS2 90.700 DTbF,LS2 91.800 GR.bS2 KA2 :999,250 URAN,KA2 -999.250 THOR.KA2 Ab2 999.250 CGR.Ab2 999 250 THOR,AL2 Ab2 -9~9,250 W1NG.NG2 :999~250 W2NG.NG2 PH2 PH2 DT2 D?2 DT2 DT2 DT2 DT2 bS2 KA2 Ab2 Ab2 NO2 N~.2 .541 $ o 8 0,~00 287, 81 89 ~00 "999 250 '9 '9 250 '999,250 56,699 65,)09 53, , .ooo .0~6 1.196 -99 , 50 ,250 '999.250 '999.250 DPH PH2 IDVR PH2 ILD[DT2 IMQF DT2 IXM DT2 CAb$,OT2 MTEM,DT2 DT5F~[JS2 URAN.KA2 CGR,Ab2 W1NG,NG2 W5NG~NG2 MTEM,NG2 HTEN.ATR IDPH IDER IDVR IL, D IMOF IIXM CABS MTEM DTLF bRAN CGR WING ,PH2 .PH2 .PH2 .DT2 .DT2 .DT2 .DT2 ,DT2 ,1,52 .KA2 ,Ab2 ,NG2 ,NG2 ,NG2 3 0 000 17 867 14 88 0 -999 250 -999 250 -999 0 -999,~50 6 0 000 9 ~30 12 S4 O0 -999 ~5 -999 ~ -999 250 -999 250 C[MP.PH CMER.PH~ CMVR,PH CILM,DT IIRD,DT SFLU.DT TEN$.DT2 DT,L$2 _ GR,L$2 THOR.Ab THOR. W2NG,NG2 C$~NG2 MRB$,NG2 TEN$,ATR CIMP,PH2 CMER.PH2 CMVR*DT) CiLM.PH IIRD,D?2 $FLU.DT2 TEN$:DT2 DT,L$2 GR.LS2 THOR,KA2 THOR.Ab2 W2NG,NG2 C$.NG2 MRES.NG2 88.500 65,783 i999,250 999,250 .999~250 '999~250 ~999,250 '999,250 247,849 243,424 208~ 6 3 921 92 0 90 -999 0 -999 250 3 4,1 9~ 50 -999,2.50 139~ 133, 144,~ .13, '999,250 '999, 67 LIS Tape Verification blstinq Schlumoerqer Alaska Computtn.q Center DEPT ZMPH PH2 I~ER PH2 I~VR PH2 Ib~ DT2 IIXD DT2 SP DT2 HTEN DT2 DTL 582 SGR KA2 PDTA KA2 URAN Ab2 W3NG NG2 TENS,NG2 GR.ATR DEPT IMER PH2 IMVR PH2 Ib~ DT2 IIXD DT2 8P DT2 KA SGR KA~ POTR UR N Ab2 W3~G NG2 TEN8 NG2 D~PT ZMPH PH2 IMER PH2 Z~V~ PH IbM DT~ IIXD DT2 $~ DT DTL bS2 '$GR KA2 ~OTA KA2 'URAN Ab W3NG NG) TEN8 NO2 GR A~R I~.ER Ih DT2 '999,250 8P,ATR 7800,000 CIDP,PH2 5,021 CDER,PH2 4,191.3 CDVR,PH2 4,843 CIbD,DT2 4,970 IDOF.DT2 27,913 IIRM.DT2 -60,938 GRoDT2 61.548 MRE$,DT2 895.200 DTLN,L82 '999,1250 CGR,KA2 '999,250 SGR,Ab2 -999 50 W4NG,NG2 -999,2~0 H?~NeNG2 -999,250 SP,ATR 7600.000 4.292 4,302 ,131 ~..114 28,822 ~47,063 6~,976 9 .400 -999 50 -9 250 -999 250 -999~-250 74O0 000 4 7 4 42 301 -50 875 874 590 92 800 '999 ~50 '999 250 '99~ 250 -99 250 "999 250 '999 250 7200 000 5 099 '5 ,,tSO 5 210 4 979 ClDP,PH2 CD£R PH2 CDVR PH2 CIbDiDoF DTDT~ IlRM DT2 GR DT2 MRES.DT2 DTLN,b$2 CGR,KA2 SGR,Ab2 POTAeAb2 W4NGeNG2 HTEN~NG2 SP,ATR CIDP PH2 .CDER PH2 CDVR PH2 CILD DT2 IDQF DT2 IIRM DT2 GR DT2 MRE8 DT2 DTLN:LS2 CGR,KA2 SGR,.AL2 POTAeAb2 W4NG,NG2 HT~N,NG2 P,ATR CIDP PH2 DER PH2 DVR PH2 ClLD DT2 IDQF DT2 27-APR-~992 08:57 -999,250 HTEN.ATR 224.448 226,7B0 229.401 224.179 0.0~0 . 4 0 :Igo 99950 999 ~50 999 )50 999 50 '999 250 -999 250 .257 47,001 24~,123 ,000 227,~15 60. 56 0 782 es:?oo '999.250 '999.2~0 '999, 0 '999,)50 '999. 0 259 220 523 456 5~ 794 94 50O -999 250 -999 250 .-999 25~ '999 25 "~99 250 ' 99 250 .200, ' Oo :o oOoO IDPH.PH2 IDERoPH2 IDVR,PH2 ILO.DT2 IMOF,DT2 IIXM.DT2 CALS,DT2 MTEM,DT2 URAN.KA2 CGR,Ab2 W~NG,NG2 W NG,NG2 MTEM.NG2 HTEN,ATR IDPH.PH2 IDER,PH2 IDVR,PH2 DT2 IIXM,DT2 CAL$.DT2 MTEM.DT2 DTLF,L$2 URAN.KA2 CGR Ab2 W1NG:NG2 W5NG,NG2 MTEM,NG2 HTEN.ATR IDPH.PH2 I[)£R,PH2 IDVR,PH2 ILD.DT2 IMQF,DT2 IIXM DT2 CALS~DT2 MTg~,DT2 DTLF,LS2 URAN.KA2 CGR,Ab2 WING,NG2 WSNG,NG2 MTEM,NG2 HTEN.ATR I. DPH,PH2 IDER,PH2 'IDVR.PH2 ILD,DT2 IMQF,DT2 -999.250 TENS.ATR 4,455 CIMP.PH2 4.410 CMER.PH2 4.359 CMVR,PH2 4 461 CILM.DT2 0 000 IIRD DT2 14 12 139 93 -999 -999 -999 -999 -999 -999 140 SFLU DT2 317 TENS DT2 194 DT L$2 900 GR bS2 250 THOR KA2 250 THOR Ab2 250 W2NG NG2 250 ¢8 NG2 250 MR£$,NG2 250 TENS,ATR 4.159 CIMP,PH2. 4,~ CMER,.PH2 CMVR,PH2 4'130 CILM,DT2 ~*000 IIRD DT2 · · 15 136 992 DT 93 800 GR -999 THOR -999 250 W2NG -999 25O CS -999.250 MR~S -999,250 TENS DT2 DT2 bS2 bS2 KA2 Ab2 NG2 NG2 NG2 ATR 3 859 CI~P PH2 3 4 3 0 12 -999 -999 CMER PH2 864 CILMDT2 000 IIRD,DT2 564 5FLU.DT2' 436 DT,b$2 250 THO ..KA2 .250 TH ~,A~2 25O .NG2 250 ¢I,NG2 50 T~NS,ATR 994 .CIM~ 097 CME 148 CMVR 947 CIbM 000 IlRD .PH2 DT2 .DT2 PAGEI 68 '999,250 199 158 03 538 06 473 20~ 204 193 148 6 036 5395 000 95 100 48 i34 -999 250 -999 25O -99 25 -999 250 -999 250 232 989 32 464 4. .24] 087 207 896 4 60 6 -99~ 250 -99 250 -999 250 -999i~50 '999i 50 '999,250 O0 -999 ~50 ' 50 -999 dj, fit, bis Tape Verification bis,tn Schlumberger Alaska Computt. n~ Center .DT2 D?b 8GE KA2 PO?A KA2 W3NG NG2 ?ENS NG2 GE ATE 23.315 IIRM.DT2 '55.000 GRtDT2 879,409 MRE$.DT2 970000 DTLN.b$2 -999,250 CGR.KA2 -999,250 SGR,AL2 -999,250 POTA,Ab2 -9990250 W4NG.NG2 '999,250 HTEN.NG2 '999.250 SPeATR D£PT IMVR,PH2 ILH.DT2 IZXD.DT2 SP.DT2 HTEN.DT2 DTb $GR KA2 POTA KA2 URAN TENS GR ATR 7000.000 CIDP,PH2 4.231 CD£R,PH2 4.199 CDVR,PH2 4,155 CXLD,DT2 4,222 IDQF.DT2 20,530 IIRMoDT2 -45,625 GR,DT2 884,038 MRES.DT2 1030100 DTLN,L$2 '9990250 CGR,KA2 '9990250 SGR AL2 -999o250 POTA~AL2 -999.~50 w4NG,.NG2 -999, 50 HTEN,NG2 -999,250 .$P,ATR DEPT.,: XMPH,PH2 XMER,PH2 IMVRePH2 'ILM,.DT~ IIXD.DT2 SP,DT~ HTEN.DT2 DTL,L$2 SGR.KA2 POTA;KA~ GR,ATR 0 0 6 .'766 -7 250 88~ 717 94 200 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 CIDP CDVR PH2 CZLD DT2 'IDQF DT2 IIEM DT2 GR. DT2 MRE$.DT2 DTLN bS2 CGR K~2 SGR.~b2 POTA b2 W4NG NG2 HT£N NG2 SP ATR DEPT 11XD 8P HTEN PTb POTA IJRAN PH2' PH2 PH2 DT2 DT2 DT2 DT2 6600,000 6,724 6,745 6,714 6,590 13,656 '67,563 905,923 94,'100 '999'.250 -999,'250 -999,.250 CIDP.PH2 CDER,PH2 CDVR,PH2 CI5D DT2 DOF DT2 IIRM DT2 GR DT2 HERS DT2 DTLN,bS2 CGR,KA2 SGR,AL2 POTA,Ab2 27-APR-1992 08:57 188.873 IIXM.DT2 72.451 CALS,DT2 0.808 MTE~.DT2 94.600 DTLF.~S2 -999,250 UR~N.KA2 -999,250 CGR,Ab2 -999.250 WlNG.NG2 -999,250 W5NG,NG2 -999.250 MTE~,NG2 '999.250 HTEN,'ATR 208,401 IDPH,PH2 211.878 IDER.PH2 214.865 IDVR.PH2 210.467 [LD,DT2 0,000 I~OF,DT2 222,174 I~X~.DT2 75.428 CAL,$,DT2 0.821 ~TE~,DT2 103.300 DTLF.bS2 -999,250 URAN,KA2 '9~9.250 CGR,AL2 -999.250 W1NG.NG2 · ~TE~.NG2 -999,250 HTEN,ATR 94 900 ~999 250 -999 250 -999 250 -999 250 '999 250 '999 250 147,337 144.868 145,831 149,446 14~ '000 .1.61 68,~72 O. 46 94,300 -999.250 -99~.250 -99 .250 IDPH,PH2 DER.PH2 IDVR,PH2 .lbD,DT2 ZNOF,DT2 IIX~.DT2 CALS,DT2 HTEM.DT2 DTLF,bS2 URAN,KA2 CGR,AL2 W1NG.NG2 WSNG NG2 MTE~NG2 HTEN.ATR IDPH PH2 IDER:PH2 IDVR.PH2 ILD,DT2 IMOF,DT2 IIXM,DT2 CALS,DT2 MTE~,.DT2 DTLF,I~$2 URAN,KA2 CGR..AL2 W1NG.NG2 33.4i3 SFbU.DT2 12 655 TEN$,DT2 132~750 DT.L$2 96.600 GR,bS2 -999.250 THOR,KA2 -999,250 THOR,A~2 -999.250 W2NG.NG2 -999.250 C$,NG2 -999,250 ~RES,NG2 -999.250 TENS.ATR 4.798 ClMP.PH2 4.720 CMER.PH2 4.654 CMVR.PH2 4.751 CILM,DT2 0,000 33.795 Z[RD.D?2 SFLU,DT2 131. 3 DT,L$2 104,800 GR.bS2 -999 250 THOR,KA2 -999:250 THORoAb2 -999.250 ~2NG,NG2 =999.250 C8,NG2 -999.250 MRES.NG2 -999,250 TENS,ATR 66 251 CIMP PH2PH2 CMVR PH2 6 15 CIbM DT2 0 000 IIRD D?22 3 065 '$FbU , DT 5S2 95,400 GE L$2 -999,250 THOR -999 250 THOR AL2 6 787 6 6 6 0 20 13 126 -999 -999 CZMP,PH2 903 CMER'.PH2 857 CMVR,PH2 691 CILH.DT2 000 IIRD.DT2 412 SFLU,DT2 747 TEN$,DT~ 975 DToL$ 700 8~,L52' 250 TH ,.KA2 250 THOR'Ab2 250 500~ 117 000 95 600 'ggg 250 -99~,250 -99 ,250 '999,250 236 337 238 168 240 680 236 843 iBl 628 4 192 5010 000 106 2OO .75 426 -999 250 -999 250 -999 250 -999 -999 250 147,~ 146, -999 250 -999 250 99 250 -999 250 4825 0i~0 gl 600 -999 -9 250 ~chlumberoer AlasRe Comput!nq Center W3NG NG2 TENSiNg2 GE.ATE ~MER PH2 Zb~ DT2 I/XD DT2 SP DT2 HTEN DT2 DT~ ~$2 SGR.KA2 POTAoKA2 URAN.A~2 W3NG,NG2 TENS.NG2 GE.ATE D£~? IMER,PH.2 IM.V~.'PH2 .~L .D~2 IIX~.,DT2 $ .D~2 HT~N,D 2 8GR,KA2 PO?A,KA2' URAN.Ab WING..NG~ ~gN$.NG2 GR,'ATE D~PT Z~PH ~H IMER I~VR PH2 I~ DT2 IIXD DT2 SP. DT2 HTEN DT2 SGR KA. POTA KA) URAN;A 2 W3NG,N~2 ~NS~NG.2 GR,A?R -999,250 W4NG,NG2 -999,250 HTEN,NG2 -999.250 SP.ATR 6400.000 CIDP,PH2 5.364 CD~R.PH2 5.415 CDVR,PH2 5.451 CZbD,DT2 .DT2 GR,DT2 29,488 95,8~3 ~96.198 98.000 DTb b82 '999,250 CGR,KA2 -999,250 SGR.Ab2 -9'9~'~50 POTA,Ab2 . 50 W4NG.NG2 -999.250 XT£N.,NG2 -999.250 SPoA?R 6200.000 5.319 5.263 5.270 5 099 6~ 596 - 750 2 -999 250 -999 250 -999 250 ~999 250 ~999 250 ~999 250 6OOO.OO0 2. ,410 .446 - .313 88~,082 11 ,000 '999.250 -999,250 -999,250 0 '999,.250 CiDP,PH2 CDER.PH2 CDVR.PH2 CZ~D~D? ~DQF IIRM DT2 GR DT2 MRES DT2 DTLN b82 CGR KA2 8GE Ab2 HT~N..NG2 '$P ATE CIDP..PH2 CDBR,PH2 CDVR,PH2 C]~D DT IDOF. DT~ Z.IRM. DT GR DT~ .MRE$ DT2 DTLN bS2 CGR 2 POTA b2 W4NG ~G2 HT~N NG2 SP ATE 27'APR-1992 08157 -999.250 WSNG,NG2 2 .449 IDER.PH2 225.364 IDVR.PH2 233,333 ILD.DT2 0,000 IHOF,D?2 179,341 ZZX~I.DT2 51.061 CAbS.DT2 0,867 MTEM.DT2 99,100 DTLF.LS2 '99 ,250 ,NG2 -99~.250 MTEM,NG2 -99 ,250 HTEN.ATR 182.365 [DPH.PH2 82. 5 IDVR,PH2 179.~85 ILD.DT2 O, O0 .IMQF,DT2 1~4,479 IIXM,DT2 8 9 MTEH,DT2 99,500 DTLF,LS2 '-999, 0 CGR,Ab2 W1NG.NG2 ,-999, '999,)~ MTE~ NG2 HTEN .ATE 384 779 389 0 ',999, 0 '999o. 50 '999, 50 ,999~) 50 'IDPH,PH2 IDER.PH2 IDVR.PH2 lbD,DT2 IMOF.DT2 I~X~ DT2 CAb$:DT2 MTEM.DT2 DTLF,b$2 U~AN,KA2 CGR,AL2 WlNG.NG2 W5NG,NG2 MTEM,NG2 HTEN,ATR '999.250 C8.NG2 '999.92~00 MRES.NG2 '999. TENS,ATR 4.324 CIMP.PH2 4.416 CM£R.PH2 4,437 CHVR.PH2 4.286 CILM.DT2 0,000 IIRD.DT2 12,150 SFLU.DT2 11.890 TENS.DT2 124.789 DT.L$2 98.000 GR.bS2 -999.250 THOR.KA2 '999.250 THOR,Ab2 '999.250 W2NG.NG) 5 48~ CIMPePH2 5 35 CMER,PH2 5 466 CMVR,PH2 5 559 CILN,DT2 0 000 IZRD.D?2 13 TEN$,DT2 9 DT,h$2 -999 250 THOR Ab22 -999 250 THOR, -999 250 W2NG,NG2 -999 250 C$,NG2 -999 250 HRE$,NG2 -999 250 TENS,ATE 2 599 CZMP,PH2 2 566 CM~R,PHt 2 542 CHVR.PH 2 553 ClEM,D?2 0 000 IIRD,DT2 16 306 120,978 .1~4,.700 -999,25~ -999 25 -999 250 -999 250 -999 SFbU,DT2 TENS,D?2 DT OR THOR KA2 THOR A~2 W2NG NG2 C$ NG2 ~RES. PAG£1 70 -999.250 -999,250 -999,250 186 433 184 678 183 466 190 590 =oo 454~ 000 97 900 51 061 -999 250 -999 250 -999 250 999 0 -999 250 189 89 -999 50 ~999 '50 ~999~.250 '-999')~0 o .9 .250 4 ~ 21 32i 156 445 ~999 25 "999 25~ "999 250 250 o LIs Tape verification Listing Schlumberger Alaska Computing Center DEPT I~PH IMER IIXD SP SGR, POTA. U~AN, W3NG, TENS, DEPT. IMPH, IM~R. IMVR IIXD SP HTEN POTA URAN W3NG .GE 5800,000 CIDP.PH2 PH2 S950.000 CDE:R.PH2 PH2 t950.000 CDVR.PH2 PH2 1950,000 CILD,DT2 DT2 1950,000 fDQF,DT2 DT2 '479.717 IRM,DT2 DT2 '73,938 GR.DT2 DT2 908,927 MRESeDT2 LS2 88,000 DTLNeLS2 KA2 '999,250 CGR,KA2 KA2 -999,250 SGR,A~2 Ab2 -999.250 POTA.Ab2 NG2 -999,250 W4NG,NG2 NO2 -999.250 HTEN.NG2 ATR -999.250 SP,ATR 5738.500 PH2 1950,000 PH2 1950,000 PH2 1950.000 DT2 '999,250 DT~ -999,250 D~ -999.250 DT2 999,250 582 ~999,250 KA2 999',250 KA2 ~999.250 Ab'2 '999,250 NG2. -999,250 NG2 -999,250 ATR' '999,250 CIDP.PH2 CDER,.PH2 CDVR,PH2 CILD DT2 IDQF DT2 IIRM DT2 GR DT2 D? DTLN 1,8 C R AL2 S~R KA2 POTA Ab2 W4NG NG2 HTEN;NG2 SP,ATR END OF DATA FIi, E NAME I EDIT ,006 SERVICE { rblC VER&IDN I OO1A07 DATE = 92/04/27 MAX EEC $I[E = 8192 FILE TYPE LAST FILE 27'APR-1992 01{:57 ?11].709 IDPH.PH2 9 ,890 IDER.PH2 916.435 IDVR,PH2 -152.175 ILDoDT2 0.000 IMOF,DT2 '90g,406 IIXM,DT2 31.668 CALS.DT2 0.913 MTEM,DT2 85.000 DTLF.LS2 :999,250 URA~.KA2 999.250 CGR.AL2 -999,250 WlNG.NG2 -999,250 WLNG.NG2 -999.250 MTEM.NG2 -999.250 HTEN,ATR 014 845 1194.983 -99~.250 -99~.250 -999,250 -999.250 -999,250 -999,250 -999,250 ~999,250 ~999,250 -999.250 -999,250 -999,250 IDPH.PH2 IDER.PH2 IDVR,PH2 I[,D.DT2 IMOF.DT2 I!XM,DT2 CAI, S,DT2 MTE~.DT2 DTLF,LS2 URAN,KA2 CGR,AL2 WlNG,NG2 W5NG.NG2 MTEM,NG2 HTEN,ATR 19 19 19 19 -7 1 -9 -9 -9 -9 -9 -9 19 19 19 -9 -9 -9 -9 -9 -9 -9 -9 -9 -9 -9 -9 50 50 50 50 0 87 12 19 96 99 99 99 99 99 99 5O 5O 50 99 9 99 99 99 99 99 99 99 99 99 000 .000 ,000 .000 .000 ,095 .547 .284 .800 .250 .250 .250 .250 .250 .250 .000 .000 .000 250 250 250 250 25O 250 250 250 250 25O .50 CIMP.PH2 CMER.PH2 CMVR.PH2 ClLM.DT2 IIRD.DT2 SFLU.DT2 TEN$.DT2 DT.L$2 GR.L82 THOR.KA2 THOR.Ab2 W2NG,NG2 CS,NG2 MRES,NG2 TENS,ATE CIMP.PH2 CMER,PH2 CMVR.PH2 CILM,DT2 XIRD.DT2 SFLU.DT2 TENS,DT2 DT.L$2 GR.,LS2 THO~,KA2 THO ,Ab~ W2NG,NG2 CS.NG2 ~RES.NG2 TENS.ATE PAGE: 71 -I187 175 =1408 374 -1376 243 -893 130 -95 199 0 1.07 4365 000 96 900 '31 668 -999 250 -999 250 -999 250 -999 250 --999 250 -999 250 -868 046 -1134 691 -1177 489 -999 250 -999 250 - 250 -999 25~ -999 25 -99 -999 250 -999 250 IS TaPe Verl[ication [,tst~nq SChlumeer,qer Alasl~a Computing Center **** FILE HEADER FILE NAME ~ EDIT .007 SERVICE : FLIC VERSION ~ OO1AO? DATE : 92/04/27 NAX REC SIZE ~ 8192 F~LE TYPE ~ LAST FILE 27-APR-1992 0R:57 PAGEI FILE - ED~T.O07 COMPANY NAME'~ CONOCO INC. HEbb~ BADAMI #2 F'IEbD~ WILDCAT REPEAT PASS RUN #2 DATA SANPLED EVERY -.25 FEET DATA INCLUDED TOOEL EXTENSION TYP USED AlT ,ATR NAME ARRAY INDUCTION TOO[~ .(COMPUTING CENTER PROCESSED AND ENVIRONMENTALLY CORRECTED DATA) TABLE. TYPE ~ CONS · TUNI VALU DEFI ..... CN CONOCO INC. Company Name FN WILDCAT Field Name WN B~D.A~I #2 Well Name.. 50-029-22230 kPI Serial Number APIN FL. ~?00' FNL & 700* FWb ~ieldlbOCa~on S~CT 30 Section TOWN tON Township RANG, .20E Range, COU~ NORTH SLOPE County STAT ALASKA State or' Prov~nce NATI USA Nation TaPe Verification Listing Sc.~lumberger AlasKa ComputtnC[ Center 27-APR-lgg2 0f~:57 PAGEI 73 TUNI VA~U DEFI WITN MERC£R/HAN / OYI.,A Witness Name 548510 Service Order Number SON PDAT APD FT 3~, EKB rr 3 , EOF FT 36, EGb FT 3 TDD FT 1~860 Bb! FT 11833, Th! FT 445, DFT GENERIC DFD G/C3' il.5 DFPH 9.30000! DFV S 56 orb. r3 R~S OH~ 1.85 MST DEGF 55 RHF8 OHHM 1.~9 MFST DEGF 52 ~CS OH.~ ~CST DEGF 56 BHT DEGF .17~,. Permanent datom Elevation of Permanent Datum bog Measured From Above Permanent Datum £ievat[on ot Kelly Bushing Elevat on of Derrick Fi or Elevation of Ground bevel Total DePth - Driller Total Depth:- bogger Bottom bog Interval. Top bog Interval Drilling Fluid Type .... Drilltn~ Fluid Density Dr~llin~ Fluid Ph ., Orllltn~ Fluid Viscosity Drillln~.Fluid boss . ResistiVity of Mud. Sample Mud-Sample Tempera:ute Resistivity of ~Ud Filtrate Mud Filtrate Sample Te~perat~ Resistiv~ty of M~d CaKe '$amol Mud CaKe Sample Temperature Bottom Hole Temperature .... T~BLE TYPE :'CURV DEP? Depth A010 A920 Afl00 ATtO AT20 AT30 AT60 ATg0 ATRX ATRT ' [,IS ?a~e Veri~ication Listi~..q , $ch, lumberger Alaska C'omput[nq Center 27-APR-1992 08:57 PAGE! DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE R~PR CODE VABUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 g 68 0.25 9 65 FT 1~ 66 ~57 12 68 13 66 0 14 65 FT 15 66 68 16 66 ! 0 66 1 '** SET.TYPE -' CHAN ** mm~m~m~Mmm~mm~m~mm~mmmmm~mmmmmmmmm~mmmmmmmmmmmmm~mmmmmmmmmmm~mm~mm~mmmm~m~m~m~ NAME BERV' UNIT SERVICE AP1 AP! APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE,.CbASS MOD NUMB SAMP EbEM CODE (HEX) mm)~)~)mW~mMM~mNmmmmmmMm~mmmm~Mmmmmmmm~m~mmmmmm*mmmmmmmmmmmmmmmmm*mmmmmmmMmmmmm~mm~ 0~, '~ ~,~o oo ooo oo o ~ ~ ~ ~ ~ oooooooooo ~0~0 ,~, 0,~ ~,~0 oo 000 oo 0 ~ ~ ~ ~ ~ 0000000000 ~0~0 A~,. 0,~, ~~0 oo 000 oo 0 ~ ~ ~ 4 6, 0000000000 ~0~0 ~, ~,.. ~4,5~o oo ooo oo o ~ ,. ~ 4 ~, oooooooooo ~0~0 A~. o... ~4,sio oo 000 oo 0 ~ ~ ~ ~ ~, 0000000000 ~0~0 ~.. 0,.. s~s 0 oo 000 oo 0 ~ ~ ~ ~ ~ 0000000000 ~,~0 ~. 0... S~s~o oo 000 oo 0 ~ '~ ~ ~ ~, 0000000000 ~,~0 ~, 0... ~~0 oo 000 oo 0 ~ ~ ~ ~ ~ 0000000000 ~0 ~.. 0.,. s~,~[o oo 000 oo o.~ : ~ ~ ~ 0000000080 ~0 ~.0... ~ 0 oo 000 oo 0 ~ ~ ~ 4 ~ 00000000 0 ~0 ~.0... ~4~0 oo 080 oo 0~ ~ ~.4 ~, 0000000000 ~.x ~. 0..~ ~4,~0 oo 0 0 oo 0~ ~ ~ ~ ~ 0000000000 ~.T A~.. 0... ~4~,0 O0 000 O0 0~ , ~ 4 ~ oooooooooo m~~~m~mmm~mmm~mmm~I~mm~mmmmm~m~m~m~mmmmm~m~m~mt~m~m~mmI~m~~mm~mmm~ DEPT,ATR 10900[000 A060, 5 453 ATSO,RTR 6 601. ATRT,ATR 5.106 AO10,ATR 15 735 AO20.ATR 7.~34 AO30.ATR Aog0.ATR 5:062 AT10.ATR 15. 35 AT20,ATR AT60,ATR 5.452 ATg0,.ATR 5.065 ATRX,ATR 7~ 25,,514 74 [,I~ TaPe Verification b~stln.~ $chlUmberqer Alaska Computin~ Center DEPT 10800,000 AOIO.ATR AO60:ATR 7.781 ADgO.ATR AT30~ATR ]Io437 AT60.ATR ATRT~ATR 8.894 DEPT. 10600.000 AO]0,A?R AO60.ATR 10.140 AO90.ATR AT30.ATR ]2,986 AT60.ATR ATRT.RTR 9,552 DEPT, 10430,000 AO10oATR AO60.ATR 7.340 AOg0.ATR AT30.ATR 8.~40 AT60.ATR ATRT.ATR 6.369 END Or DATA **** FILE TRAILER **** r~bE NAME g EDIT .007 SERVICE : FLIC VERSION : O01A07 DATE I 92/04/27 FIMA~ERT 8192 EC SIZE I YPE : [,0 LAST FILE g FILE NAME I EDIT ,008 SERVICE ~ FblC V~RSION g 001A07 DA?£ ) q2/04/27 MAX REC SIZE g 8192 FIL~ TYPE: g LO bAST rIb~ 27'APR-J992 08:57 1950.O00 AC)20.ATR 18.070 AO30.ATR 7.028 AT]0.ATR 1950.000 AT20.ATR 9.491 ATg0.ATR 8.422 ATRX.ATR 1950.0000 AO20.ATR I09.524 AO30.ATR 9. 22 AT10.ATR 19 ,000 AT20,ATR 10,586 AT90.ATR 9,425 ATRX.ATR 101.536 AO20.ATR 11.626 AO30.ATR 6,948 AT10.ATR 76.321 AT20.ATR 6.767 AT90.ATR 6.428 ATRX.ATR PAGE! t2,286 14,666 1950,000 13.99i 17.32 19.50.000 8,904 10,260 419,920 75 FILE ' EDIT,OO8 COMPANY NAMEI CONOCO INC, WELL:. BADAMI #2 FIELD: WIbOCAT ' ~zs ?a~.e verification Llsting Sch, 1,;m erqer Alaska Computino Center 27-APR-1992 08:57 REPEAT PASS RUN #2 DATA SAMPLED EVERY -.1667 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME MSF[~ .MS2 MICRO SPHERICALLY FOCUSED ****************************************************************************** TABLE TYPE : CONS TUNI VAbU DEFI . . .. CN CONOCO INC. FN WIbDCAT WN BADAMI #2 APIN 50'029'22230 rb 2700' FNb & 700' FWb $~¢T 30 TOWN ION RANG 20E COUN NORTH SLOPE STAT AbASKA ' N~T! USA WITN MERCER/HAND/POYbA SON 548510 PDAT MSb ~PD FT APD F1 37, EKB FT 37, EDF FT 36, EGb FT TDD FT TD5 FT B~! r~ 11833 Th! FT 4.45. , DrT G£N~RIC.#2 PrO G/C3' ~t,5 D[P.H 9.700001 DFV $ 56 DF5 F~ R~S OH~M 1.85 HST. DEGF R.~FS OH.. MFST DEGF 52 R"CS OH~M' 2...I2 MCS? DEGF 56. BHT DEGF Compan~ Name r~eld ame We~l ~ame AP1 Serial Number Field Location Section Township Range County State or Prov~nce Nation Witness Name Service order Number Permanent datum Elevation ot Permanent Datum bog Measured From Above Permanent~Datum[~ glevat, ton o£ De ~ Floor S~evation ot. Gro bevel otalDepth Driller' ' otal Depths: bogg~r Bottom bbg Inte~v&z Top bog Interva~ Or%lling Fluid Type~, Drilling Fluid Density Drillin~ FlUid Ph, ,, . Drilling Fluid Viscosity @ri~lin~.Flui~ bOSS mi ~eststigity'o~..Mud.:$amp~e Mud,,Sa~ple. ~emperatU~e ResistivitY.Of,~d riP,rate S MUdl. riltra~e..sample Tempgratu ResistivitY'O~,Mud.'Ca&e:,Samol Mud Ca~e Sample Temperature Bottom Hole .Temperature.' ! · LIS Tape Verification [,istina 27-APR-1992 08:5? PAGEg 77 Schlumberger Alaska Computtno Center ' ! DEFI DEPT Depth MSFL MSF~ Reslstlvt~ SMIN Syn~ettc ~icr Inverse Resis~iytty 8MNO Synthetic ~lcro-~orma! Resistivity DATA FORMAT SPECIFICATfON RECORD ** SET TYPE - 64E8 ** ''''''''''''''''''''''''''''''REPR VALUE ! 66 0 2 66 0 3 73 16 4 66 5 6 7 65 1 6 0 13 66 0 14 65 FT 15 66 68 16 66 ! .0 ~6 1 mN~mm~Nmmmwm~m~mmmmmmmmm~mmm ** SET TYPE = CHAN ** NAME SERV UNIT SERVICE APl AP! API AP1 F,IbE NUMB NUmB SIZE REP,R PROCESS ID ORDER # LOG TYPE C~AS8 MOD Nt, I~B SAMP ELEM CODE (HEX) .~ .~ .o... ~s~o oo ooo oo o ~ , ~ ~ ~ oooo~~ SMINMS2 0HMM54851000 000 00 0 8 1 I 4 68 0000000000 mm~mm~-~mmmmmm~mmm~-~m~mm~m~mmmm~m~mm~mmmmmm~mmm~mmm~m~mmmm~mmmmmmmm~m~me~m *,* DATA ** I I I t I i I I ~S ?a~e Veri~icatton ~istin~ ' $c,hlumber~er ~las~a Computin5 Center DEPT. DEPT. DEPT. DEPT. DEPT. DEPT. DEPT. DEPT. DEPT. D~PT. DFPT. DEPT. DEPT. DEPT, DEPT. DEPT. DEPT, DEPT. DEPT. DEPT. DEPT, DEPT, DEPT, DEPT, DEPT, DEP?. )1000.334 MSFb. H$2 11000.000 {0800.000 10600,000 10400.000 ~SFL.MS2 10200.000 MSF~.M$2 10000.000 ~8Fb.~S2 9800.000 ~SFb,M$2 9600,000 ~SFL.~$2 9400,000 ~SFL,MS2 9200,000 ~SFL.M$2 9000.000 MSFL.MS2 8800.000 ~SFL.~S2 8600,000 ~SFL..M$2 8400,000 ~SFb,MS2 8200,000 MSFL.MS2 8000,'000 ~$FL,M$2' 7800,000 ~SFL,~$2 7600.000 ~8FL.~S2 7400,000 ~SFL.MS2 7200.000 7000.000 6800,000 6600,000 ~SFL.M$2 6400,000 MSFL.~S2 6200,000 ~SFL,~$2 27-APR-1992 08:57 -999.250 SMIN.~S2 t.470 SMI~.MS2 2.161 $~IN.MS2 1.973 S~I~.~S2 2.307 2.04~ S~]N.MS2 1.676 1.520 S~IN.~S2 1.669 S~IN.aS2 1.510 1.261 2,618 $~1N.~$2 1,612 1.704 $~IN.M82 3,590 2.546 SMIN.M$2 2.344 2,649 SMIN.MS2 2..120 SMIN.N$? 2.55~ 2,{16 S~IN,a$2 2.705 -999.250 1.270 0.576 0.580 0.912 1.005 0.957 1.266 0.849 O.824 1.147 1.593 1.539 1.003 1,699 0,991 1.404 1.387 1.254 1.736 1.818 1.,846 1.089 1.532 ].118 1.408 SMNO.M$2 SMNO.M$2 SMNO.M$2 SMNO.M$2 $MNO.MS2 S~NO.M$2 8~NO.M$2 $MN0.~$2 SMNO.MS2 SMNO.MS2 S~NO.~S2 SMNO.MS2 SMNO,M$2 $MNO.M$2 S~NO.MS2 $~NO.~$2 5~NO,M$2 SMNO,M$2 SMNO,MS2 SMNO,M$2 S~NO.~S2 PAGEt 78 '999,250 0,258 0,298 0,263 0,455 0,407 0,289 0,443 0,223 0,262 0.261 0,~98 0,678 0.277 0,380 0,071 0,913 0,630 0'545 0,545' 0,245 0,594 0,657 .0,452 0,680 Tame Verification Listin schlumberger Alaska Computin~ Center DEPT, 6000,000 DEPT. 5738,500 END OF DATA *~*~ FILE TRAILER ~* FILE NAME : EDIT ,008 SERVICE : FLIC VERSION : 00i~07 DATE : 92/04/27 ~AX REC SIZE : 8192 FILE TYPE ~ LO LAST FILE : **~$ FILE HEADER f~* FIL£ NAME : EDIT ,009 SERVICE ~ FLIC VERSION { OO1AO? D~TE : 92/04/27 M~X EEC SIZE : 8192 FI~E TYPE t bO 27-APR-rE92 08:57 0.925 SMIN.MS2 '999.250 SNIN.MS2 1.454 SMNO,M$2 -999.250 GMNO.MS2 PAGE~ 79 0,050 -999,250 FILE.- EDIT,O09 COMPANY NAME: CONOCO INC, WELL: B~DAMI FIELD: WILDCAT REPEAT PASS RUN #1 DATA SAmPlED EVERY -,5000 FEET DATA INCbtlDED - TOOL EXTENSION TOO[, TYPE USED NA~E DITE ..DT1 PHASOR ~UAL,I~DUCTION - Tape Verification bistinq $,chlumberger Alaska Computing Center 27-APR-1992 08=57 PAGEi ilo TABLE TYPE i CONS TUNI VALU DEF! FN WILDCAT Field~ame WN BADAMI #2 Well Name APIN 50-0~9-222]0 AP1 Serial Number FL 2700 FNb & 700' FWL Field Location SECT 30 Section TOWN 1ON Township RANG 20g Ran COUN NORTH SLOPE Cou~e ty STAT ALASKA State or Province NAT! USA Nation WITN MEECER/HAND/POYbA Witness Name SON 548510 Service Order Number PPA? MSL Perman nt datum EPD FT Elevation oZ Permanent Datum bog Measured From APD FT 37, Above Permanent Datum ~B FT 37, Elevation oZ'Kell¥ E r FT 36, Elevation of'Oerrlc~ Floor EGL FT ~ Elevation oZ'Gro~nd Level TOD FT 1{860, Total Depth - Oril2er TDL FT 11867 Total Depth - BLI FT .~1833' Bottom ~oo Interval DFT GENERIC #2 UrilliSg rlu%~ DFD G/C~ ~ 5 Drilling Flusd DFPH § %0o00~ Drlllln~ F.lU~ 'Ph DFV S 5~' Drillin~ FlU$~ Viscosity DFL F~ 4,~ Drillin~Fluld Loss R~S OH~M ! 85 ResistivitY_OZ..MUd Sample ~ST DEGF 5~, Mud. Sample Temperature ' RMFS OHMM X.49 Resistivity of MUd Filtrate S MFST DEGF 52 Mud...rtltrate Sample T~mperatu R~C8 OH~M 2.[2 Resistivity o£,Mud CaKe.Sampl Mcat DEGF 56 MUd Ca~e Sa. mple Temperature BHT ..DEGF 17~. ~ottom Hole Temperature TABLE TYPE ,' CURV DEFI ,, ~mNm~m~mmmmmM~mmM.m~mmmmmmmmmmmmmmm~m~mmmmmmmmmmmmmmmmmmm DEPT CIDP ,IDp~ CI.MP IMPH CDE~ I~ER C ~R Deu_th INDUCTION DEEP PHA$OR CONDUCTIVITY INDUCTION DEEP PHASOR RESISTIVITY INDUCTION MEDIUM PHASOR CONDUCTIVITY INDUCTION MEDIUM PHASOR RESISTIVITY , DEEP INDUCTION ENHANCED RESOLUTION PHASOR CONDUCTIVITY DEEP INDUCTION ENHANCED RESOLUTION PHASOR RESISTIVITY MEDIUM INDUCTION ENHANCED RESOLUTION PHASOR CONDUCTIVITY ~IS ?ape Verification Listinq Schlumberger AlasKa Computing Center 27-APR-1992 0a:57 DEFI INER NEDIUH INDUCTION ENHANCED RESOLUTION PHASOR RESISTIVITY CDVR DEEP INDUCTION VERY-ENHANCED RESOLUTION PHA$OR CONDUCTIVITY IDVR DEEP INDUCTION VERY-ENHANCED RESOLUTION PHA$OR RESISTIVITY CNVR NEDIUN INDUCTION VERY-ENHANCED ~E$OI, UTION PHA$[)R CONDUCTIVITY INVR ~EDIIIN INDUCTION VERY-ENHANCEDRESOLUTION PHA$OR RESISTIVITY lbo Conductivity IL Deep Standard Processed '~. Conductlvi~y_l~ Medium Standard Processed Deep Induction Standard Processed Reslstlvt~y ~ Hedium Induction $~andard Processed Resistivity IDQF IDQ~ DEEP INDUCTION QUALITY ~ACTOR I~QF IMOF NED INDUCTION QUALITY FACTOR IIRD Deep Induction Real Intermediate Conductivity IZXD Deep Induction Quad Intermediate Conductivitv IIRN Nedium Induction Real Intermediate ConducttV!t¥ [IXN ~edium Induction Quad ~ntermed~ate Conductivity SFEU SFE Resistivity Unaveraged SP Spontaneous Potential GR Gamma Ray TENS Tension HTEN Head Tension MRES MUD Resistivity MTEM Mud T~mperature DT DBLTA T DTL DELTA-T LONG SPACING DTLN DEbTA-T bONG SPACING NEAR DTbF OTbF GRi Gamma Ray DATA FORMAT SPECIFICATION RECORD SET TYPE - 64E8 ** mmmNmmmmmmm~mmm~mmmmmm~mm--mmmm TYPE REPR,.CODE VALUE I 66 0 4 66 5 66 6 73 7 65 11. 66 58 12 68 13 66 0 14 65 FT 15 6~ 68 16 66 ! PAGE~ 81 ,O ~'blS'Tave Veriflcatlon blstlnq ,~chlumberqer Alaska Computinq Center 2?-APR-1992 08:57 PAGE: TYPE REPR CODE VALUE mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 0 66 1 ** SET TYPE - CHAN ** -,...--..-,.-.-.------,-......-..,,......-..--............,., ..... ..................... AME SER UNIT SERV CE APl A RPI AP1 FILE NUMB U B SIZE REPR PROCESS ID ~RDER # bOG TYPE CLASS MOD NUMB SAMP EbEM COD~ CHEX) DEPT FT 548510 O0 000 O0 0 g 1 ! 4 68 C~DP PHI ~MHO 548510 O0 000 O0 0 9 1 1 4 68 IDPH PHI OHMM 548510 O0 000 O0 0 9 CIMp P.l MM.O 548510 O0 000 O0 0 g IMPH PHI OHM. 548510 O0 000 O0 0 9 CDER PHI MMHO 548510 00 000 00 0 9 IDER PH1 OHM. 548510 O0 000 O0 0 9 CMER PH, MMHO 548510 O0 000 O0 0 9 IMER P.l 0... 5485i0 O0 000 O0 0 9 CDVR P.l ..HO 548510 O0 000 O0 0 9 ZDVR PHi OHM. 548510 O0 000 O0 0 9 CMVR P.I MMHO 548510 O0 000 O0 0 9 IMVR PHI OHM. 548510 O0 000 O0 0 9 CIED OT1 MMHD 548510 O0 000 O0 0 9 IbD DTI OHMM 548510 O0 000 O0 0 9 Clb. DT, M.HO 548510 O0 000 O0 0 g IbM OT1 OHMM 548510 O0 000 O0 0 9 IDQF DT1 548510 O0 000 O0 0 9 ~ D?I 5485~0 O0 000 O0 0 ~ ,,~ ~ ,..o ~4~o oo ooo oo o ~ :z.. o~ ,.,o ~4e~o oo ooo oo o ~ zzx. ~...o ~4~o oo ooo oo o ~ oo ooo oo o ·8510 O0 000 O0 0 9 TENS DT1 bB 548510 O0 000 O0 0 9 .TEN DT1 bB 548510 O0 000 O0 0 9 .RES DT1 OHMM 548510 O0 000 O0 0 9 MTEM DT1 DEGr 548510 O0 000 O0 0 9 DT b51 US/F 548510 O0 000 O0 0 9 DTb LB1 'US/F 548510 O0 000 O0 0 9 DT'b" b$ U$/F 5485 0 O0 0 9 DTbFbSt F 851~ 00 0 0 US/ 54 O0 000 O0 0 9 00000000 00000000 I I 4 68 0000000000 1. t 4 68 0000000000 I ! 4 68 0000000000 I I 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 ,. I 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 t 4 68 0000000000 1. I 4 68 0000000000 I I 4 68 0000000000 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 i 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 GR b81 .... GAPI 548510 O0 000 O0 0 9 1 1 4 68 0000000000 DATA ** DEPT.~flt 5808,500 CIDP.PHI 957.849 IDPH,PHt 1.0044 CIMP,PH! IMPH. 1.221 CDER.PH1 981,,,~566 IDER.PH1 1,. 40 CMER.PHi ,,ER.PHI 1,~21 Cove. PHI 963.~91 IDVR.PHI 1,Q3~ CMVR,PH1 lMVR.PH1 l.z21 CIbD,DT1 968.500 ILD.DTI 1.032 CI. bM.OT1 14.500 82 .m 'iLlS ?ape Verification Listino ~chlUmberger Alaska Computtn~ Center IL~.DT1 IIXD.DT1 SP.DT1 ~RES.DT1 DT~N.LS1 DEP?~ IM£~PH1 IMVR.PHi ILM,DT1 IIXD.DT1 ~P,D?I MRES.D?I D?LN.~I DEPT IMPH PH1 IMER PH1 IMVR PHi ILM DT1 IIXD D?I 6P. DT1 MRES DTLN 1.~27 IDOF,DT1 197. 50 IIRM,DT1 =371,000 GR.DTI' 2,303 MTEM.DT1 0,000 DTbF,b$1 5800,000 ,221 ~.221 1. 197 750 -371 000 2 303 107 400 5632.500 1,225 1,224 1,224 1,229 150,500 -483,000 , 406 10 ,000 CIDP,PH1 CDER,PH1 CDVR,PH1 CIbD,DT1 IDOF.DT1 IIRM,DT1 GR.DT1 MTEM,DT1 DTLF.LS1 CIDP.PH1 CDER.PH1 CPVR.PH1 CIbD.DT1 IDOF,DT1 IIRM,DTI GR,DT1 MTEM.DT1 DTLF.L$! END OF DATA 27-APR-1992 08:57 i. O00 IMOF.OT1 7~ .000 IIX~.DT1 7,969 TENS.DT1 84.938 DT.LS1 0,000 GR,LS1 957,572 956,233 958,038 968,500 3 000 736 000 27 969 84 938 104 200 888,935 884 5 967,000 0.000 734,500 30,313 84.875 104.500 IDPH,PHI IDER.PH1 IDVR.PH1 ILD,DTI IMOF,DT! IIXM.DT1 TEN$.DT1 DT.bS1 GR,LSl IDPH.PH! IDER.,PH1 IDVR,PH1 IbD.DT1 IMOF,DT1 IIXN,DT! TEN$,DT1 DT.hSl OR.bSl 2.000 IIRD.DT1 88.250 SFSU.DTI 3885,000 HTEN,DTi 0.000 DTb,LS1 27.969 1.044 CIMP.PH1 1.046 CMER.PH1 1.044 CMVR,PH1 1.032 CIbM.DT1 0.000 IIRD.DT1 88.250 SFLU.DTI 3740,000 HTEN.DT1 106 000 DTb.b81. 27~.969 1.125 CIMP.PH1 0 1. ,PHi 1.033 CISM,DT1 0.000 IIRD,DTI 67,438 SFLU.DT1 3585..000 HTEN,DTI 108,100 OTb. L$1 30.313 PAGEI 83 70t,000 3,412 609,000 0,000 818,886 818,797 818,8i4 814,500 oi:ooo 4i2 615,500 104,600 816,618 816,855 816,893 81 000 {:ooo 64B, :107~700 **** FII{E TRAILER **** FXbE NAME : EDIT ,009 SERVICE : FLIC VERSION : 00lA07 DATE : 92/04/27 MAX REC SIZE : 8192 FILE TYPE : bO LAST FILE : $*** TAPE TRAILER SERVICE NAME : EDIT DATE : 92/04/27 ORIGIN :rbi¢ TAPE NAME : 02210 CONTINUATION # : i PREVIOUS TAPE COMMENT ~ CONOCO INC,,WILDCAT,BADAMf #2, 50-029-22230 tis Tape verification Listing SoblumberqerAlaska Computina Center 27-~PR-]992 08~57 **** REEl, TRAI[jER **** SERVICE NAME ~ EDIT DATE ~ 92/04/27 ORIGIN ~ FbIC REE~ ~ANE ~ 92210 CONTINUATION # ~ PREVIOUS RE~b ~ COMMENT ~ CONOCO INC,,WIbDCA?,BADA)! #2, 50-0~g-~2230 PAGE~ 84
