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Home My WebLink About200-079Project Well History File Co~Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing ldo,,~'~ RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: Well History File Identifier DIGITAL DATA ~ [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL(~WINDY OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Scanning Preparation ~ x 30 = BY: BEVERLY ROBIN VINCENT SHERYL ~~VINDY Production Scanning Stage1 PAGE COUNT FROM SCANNED FILE: / ? / COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES PAGE NO Stage 2 IF NO IN STAGE t, PAGE(S) DISCREPA~,~I~RE FOUND: YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd N0.5035 -_____ t Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 1 i / ~ ~I { ~ '~ ~ - - Company: Alaska Oil & Gas Cons Comm v~' ~ ~`~Li s~r~~ ,~~-01k ~ e ~{~~~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 3F-05 12115003 PRODUCTION PRO 1E-22 12115008 FILE ~ ;;, !r'- ~:~ INJECTION PRO ~ ~~ `^"~ ~ ~ ` 12/20/08 1 3F-12 12115008 FILE ~ , -~ C - ~ u ~~ ~.~;~ ~- ~ l "" ~ , -> INJECTION PRO ' 12/24/08 1 i D-136 12115008 FILE , ;> _a ~ s~ ~- . ;°~~- 3 -_~ _. .1~.~ } _ INJECTION PROF 12/25/08 1 3F-06 AZED-00003 Y ILE ,,, ? _ -~) -, ~., ._ ~ .. ~ ~~z - PRODUCTION ' ` " 12/26/08 1 3J-02 12115008 PROFILE ,~; ; - r!~-~%! ~ ~~ INJECTION PRO ~ 12/27/08 1 2N-332 2N-323 12096514 AZED-00008 FILE ; ^ _ - +,, ~ : .- ,=?~ , ~, C_ fl.~ , SBHP SURVEY "1 . ~ f,. U "}~~` J' - `z ~! 3 SBHP SURVEY ~- % - °~ ' 12/29/08 12/30/08 1 1 2N-342 12096514 - - ~F' ~- j ~ ~-%~~ ~~. SBHP SURV - ' - 12/30/08 1 2N-302 AZED-00007 EY ~) ~ } -.. ~ ~-' - l.l!_I~5 SBHP SURVE ~ ' ' 12/30/08 1 2P-417 2V-03 i R-13 16-02 AZED-00012 12115000 AYS4-00019 AYS4-00020 Y ~ -~ ~ ,.~ l (._. I <- - ::y. <- G. - SBHP SURVEY •f,- ~`;!,,~-'~ -:) ;__!~_ -~-- INJECTION PROFILE t}= % _ ~ -- ~% INJECTION PROFILE `, 1_ a.. 1~' `-l %'" l~'~)(~-! -~^ INJECTION PROFILE ~)'~~~. I"~~ ~ ~ ._-1:=; ' ! ~ ~ ~-I ~~~ 12/30/08 01/02/09 12/17/08 01/03/09 01/04/09 1 1 1 1 1 01 /08/09 i Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Conoc;p.,illips Alaska RECEIVED SEP 1 2 2007 A"'k. Oi' , Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 09,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 . .. D Sr:? 12 1.007 scANNE ¡;:. aoo-D7Cf ~N~ â?>~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, J2:4~ ~. ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft aat 2N-327 207-069 12" n/a 12" n/a 3.5 9/8/2007 2N-329 198-067 24" n/a 24" n/a 6 9/8/2007 2N-331 198-117 26" nla 26" n/a 2 9/8/2007 2N-332 200-079 8" n/a 8" n/a 2 9/8/2007 2N-333 206-025 29" n/a 29" n/a 8.5 9/8/2007 2N-349 200-139 3" n/a 3" n/a 1 9/8/2007 2N-350 201-175 11" n/a 11" n/a 4.5 9/8/2007 2P-438 201-082 4' 10" n/a 4' 10" n/a 2 9/8/2007 Date 9/9/2007 e e FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2N-332 Sundry Number: 306-128 100-'07 O Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission: decision to Superior Court unless rehearing has been requested. DATED thisQday of April, 2006 Encl. 1. Type of Request: Abandon A (;{If 4..f¡..{){P e Ý _ RECE\VED . STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION lL\. APR 0 5 2005 APPLICATION FOR SUNDRY APPROVAL, \, Oìl & Gas Cons. commission 20 MC 25.280 A aSl\a o Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 0 Other 0 o Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 ~.~ &4E.rl éo l;f CA;.'¡"" o Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 _ ,Wlt~) 4. Current Well Class: 5. Permit to Drill Number: '/,1; Exploratory 0 Service 0 Development Stratigraphic o o 200-079 . 6. API Number: Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 153' 50-103-20340-00 9. Well Name and Number: 2N-332 . 10. Field/Pool(s): Kuparuk River Field 1 Tarn Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5167 MD TVD Burst 113' 113 Collapse 8. Property Des}gnation: ADL 375108,380054,375074 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 12026' 5250' 11889 Casing Length Size CONDUCTOR 113' 16" SURF CASING 3754' 7-5/8" PROD CASING 11127' 5-1/2" LINER 734' 3-1/2" 3907' 11280' 12014' 2311 4852 5243 Perforation Depth MD (ft): 11600-11630 Packers and SSSV Type: no packer SSSV= NIP Perforation Depth TVD (ft): 5009-5025 Tubing Size: 3-1/2" Tubing Grade: L-80 Tubing MD (ft): 11307' Packers and SSSV MD (ft) SSSV= 510' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ert D. C istensen 04/14/06 Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0;, GINJ 0 Service 0 ' Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Signature Contact: Title: Robert D. Christensen Phone 659-7535 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Other: ,,,.Ù'~~~MÇSL~~~~ ~~ ~~\ò\'\<-<:~I ~-\ot:~1:"'~~~r-'.~-~~~ \'Vv~i' : Form 10-403 Revised 07/2005 RBDMS 8Ft APR 1 .i 2006 Approved by: APPROVED BY THE COMMISSION Date: L e 2N-332 DESCRIPTION SUMMARY OF PROPOSAL e ConocoPhillips Alaska Inc. requests approval to change the approved program for Tarn well 2N-332 from Oil production to Water Alternating Gas (MI) injection service. This conversion to /' injection service is required to provide support to the offset producers. The 7-5/8" Surface casing (3907' md 12311' tvd) was cemented with 385 sx AS III Lite followed by 240 sx Class G. The 5-1/2" Production casing (11311' md I 4866' tvd) & 3-1/2" Liner (12015' md I 5243' tvd) was cemented with 255 sx Class G & 420 sx Class G. The top of Tarn Bermuda T3 sand is located at 11396'md (4907' tvd). The top of the Bermuda T2 is located at 11694' md (5058' tvd). A Cement Bond log (SCMT) was completed on 04/01/06 indicating good bond from 11294' md to 11498' md (4858' tvd to 4957' tvd). An informal MITIA was performed on 03/27/06; CLOSE eMU WI 2.81" 42 BO @ 11074' WLM, MIT TBG AND MIT lA, BOTH PASS. PULL 2.75" CA-2 PLUG AND PRONG FROM 11282' RKB. JOB COMPLETE. Ready for injection. MITT details: Pre T/I/O: 0/600/260; Pressured up tbg to 2500; Initial T/I/O: 2500/600/260; 15 min TIIIO: 2400/600/260; 30 min T/I/O: 2375/600/260 PASS MITIA details: Pre T/I/O: 010/260; Pressured up IA to 2375; Initial T/I/O: 0/2375/260; 15 min T/I/O:0/2350/260; 30 min T/I/O: 0/23501260 PASS e e ConocoPhUUps AlaskaJ tne. KRU 2N-332 ~ 2N~332:);;:;;";;;----_· - API: 501032034000 Well Tvpe: PROD AnQle @ TS: deQ@ SSSV Type: NIPPLE Orig 7/6/2000 Angle @ TO: 52 deg @ 12026 Completion: NIP (510-511, Annular Fluid: LastW/O: Rev Reason: PULL PLUG, 00:4.500) CLOSE CMU TUBING Reference LOQ: Ref Log Date: Last Update: 3/29/2006 (0-11307, Last TaQ: 11074 TO: 12026 ftKB OD:3.500, ID:2.992) Last T aQ Date: 1/15/2006 Max Hole AnQle: 76 deQ @ 4218 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 113 113 62.58 H-40 WELDED SURF CASING 7.625 0 3907 2311 29.70 L-80 BTCM Gas Lift PROD CASING 5.500 0 11280 4852 15.50 L-80 LTCM mdrellDummy LINER 3.500 11280 12014 5243 9.30 L-80 EUE 8RD Valve 1 (3410-3411, Size Top I Bottom I TVD I Wt I Grade I Thread OD:4.725) 3.500 0 I 11307 I 4865 I 9.30 I L-80 I EUE 8RD -perfui'âtíõíísSummåiV:.;.:.:::.::::::;;;:-;-; - Interval I TVD I Zone I Status I Ft I SPF I Date I Tvoe I Comment 11600 - 11630 5009 - 5025 I I I 30 I 4 17/12/2000 IPERF 12.5" HC, BH, 60 deg I phasina GâS'LiftMåridrêlSlVálveŠ -- St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Gas Lift Mfr , Run Cmnt mdrellDummy 1 3410 2154 CAMCO KBG29 CAMCO DMY 1.0 INT 0.000 0 3/23/2001 Valve 2 2 7208 3362 CAMCO KBG29 CAMCO DMY 1.0 INT 0.000 0 3/23/2001 (7208-7209, OD:4.725) 3 9905 4297 CAMCO KBG29 CAMCO DMY 1.0 INT 0.000 0 an 12000 4 11114 4780 CAMCO KBG29 CAMCO DMY 1.0 INT 0.000 0 0/28/2001 øtI)Ø( Depth TVD Type Descriotion ID 510 509 NIP CAMCO D'S NIPPLE 2.875 11074 4762 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 1327/2006 2.813 11282 4853 NIP CAMCO 0 NIPPLE 2.750 Gas Lift ,ndrellDummy Valve 3 (9905-9906, OD:4.725) - SLEEVE-C :11074-11075, 00:4.500) ...... Gas Lift mdrellDummy Valve 4 :11114-11115, 00:4.725) NIP :11282-11283, 00:4.500) LINER :11280-12014, 00:3.500, Wt9.30) Perf - r-- :11600-11630) - f-- - ,--- - - - - - - >, c:: c:: Þ 0 ('( ~ 'æ g- <3 .9 81 Lo in Date Run Number Depth Driller Schlumberger Depth Bottom Log Int~fVal Top Log Interval Casing Fluid Type Salin it Densit Fluid Level BIT/CASING/TUBING STRING Bit Size From To Casing/Tubing Size Wei ht Grade From To Maximum Recorded Temperatures Logger On Bottom Time Unit Number Location Recorded By Witnessed B .s::::. t Ó 0 c:: Z Õ) (t- ~ 0> en t\Ï (t ëi: b en a. Q) 0) :E a. Q) Z 0 0 a... 0 ëi5 0 N 0 ð ....... (') 0 .s::::. 0 t c:: g (') c:: (¡j , 0 z 0 9 z l- N Ü CEMENT BOND LOG SCMT-GR-CCL 01-APR-2006 LAT: 70 Deg 10' 12.99" North LOMG: 150 Deg 18' 59.53" West Elev.: K.B. 153 ft G.L. 119.3ft D.F, 151.77 ft Elev.: Oft 153.1 ft above Perm, Datum Permanent Datum: Log Measured From: Drilling Measured From: MSL RKB RKB API Serial No. 50-1 03-20340-00 i-A r -2006 1 11812 ft Section Township 9N Range 7E 3 11620 ft 11200ft FREEZE PROTECT - 8.5 Ibm/ al 6.500 in 3.500 in 9.3 Ibm/ft L-80 Oft 12014 ft 113 degF 1-Apr -2006 2128 PRUDHOE BAY K. BOYER N. WOODS 16:30 ,.cI,· .,-) _ 1-t1 . 'ij 114( 0 I :;::.1 :!... I --- - I· I ',ê:::', , 113 0 - TTL - I : I I ~T ~¡-I.- J -1--1- ~-I- -I- -~-~ _'" --I -I-- = ...... - =:::' -e- -'-- - :=:- -- I 'i±J.--+=~-L ---I-- 1--1- '- - I--- .!.- L .!- _ l. .L. _..L , -¡-- _ ..L .!-I .:- f-. §§ - ~_+_ _ .1 +- f-. - i--+ t- - I f-.- ï -U i-f-. '- .L I ~ - -'. -I- .!- .J-.-< --,- ~ 7......-'- !----~:::r=q _ '-~ - r '- - :i- _~~ =;j-T _I y- _ _...L~ 1-- ---+ L,. 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'. - --.. - - , --- - " '. -- - .... , c:'-- " .-- ~--- -I-- -- .. _.. _I---_~ -, --- --= --- --- - ,.- - - .' -'- . . ~ .;-:- , .' - :::c '- . . --- - I-- -'-- f--I-..J '1 .' ~ ï "'t , II I I . , . 1:;1 . :' 'd 11410 ~j - -. ." ~- /'.:J .;' À ~ .1- 115( 0 -~ -~ ~ ..- -I "'-. -¡...a <,.. '- - - ..., <: - ~ ~- " ..:: - ;' .. oJ ..., ,~ ,. ~... r i""" -" - .....~ -- , " ,- '..... Ie "'!'" ... 11- "" ¡..> ..J - ~ ..... , II - f\-.. , \'1"- 1 i"" I . . I ." ..... ,.,....- .... ~ ~ - ," .. -, .. ... '\ ........ ...... \ .,.. ... - ...... Ii.. - I .. I 1 I .... r 116( 0 1<' > ... - - I ..,- r~ III ... - . . . . .' .. .- ...... I'" . r J. ' , l' . , .(, ,,/ ., · " \ Z , ' .. ~ -- - IL, .4> I' · · '. "'t ,.' · J <.1IIt;; 1;(' ¡:;¡¡ I " Lì" ~ y -'" ~" ;'- It. , ~ · Ll ... 11I"'- · ~t:"" · · , -:-. · L · , - J 1£ i ( ...... J ~ t:' , , .... ~ . I . l"- I I " " " " - -- " -.... ~ . -- , , . .' " ,- ", þ . " , - ,,.. . 1..'- ,. .... 1"": . , , " .......... '. .' . , .. -.. ....... - ¡', '" ....' III ,,.. - .' - - .... .... . '- , , " , .... .'" -'.. .. .- ..... -' , " - - '. ... .... .'" I. - -- ,- ,- .. '. , . ,- , 'I, I" " . .. .. . . -. I 'I, n I -' -' '- ,- '- '. '. " ,- . -, .- -- ... -"I"~ :: ~."" ,- ....... ... -. , I A .n A '" - .' I, , , , ... -- ,- " c... e e ø.c)CJ-ttl~ MECHANI CAL INTEGRITY REPORT' "'-. '-~UD -.,~_. :~ i.J~~~.:....:: OPER & FIELD <..:...QC\-!:.. Y- \"L.'\j -"\~~ k-ž:LL NUM13 ER 'd' ~ - 3 > d-- :~ I. G R £ ~ ~ ;. S ~: . :éi!::LL DATJ._ TD: t~ ()~~.MD. 5)SO TVD j :?ETD: \\ 'õ'~ MD 5 \<:0 ~ TVD C¿s i~g: '5 "i;) l~ Shoe: \\if\O HD L\~5) TVD i DV: ~~ HD ·Tvu 'T~~'::. . ~I C"'..r\ _-'-.Ie:.. . "')'f) Shoe: \)ú\~ MD Sd41rm i :CP: \ \:::hvl·m '-\.~Sd- ::~lTJ ") ·l l' <) (>,Q l Ii '¿ ^ '"'. -=- u '0 i:; g: ~ / () Pac k e!:' \. \ àSO ill) TVD í Set ê. i: , .:> \J ( :':ole Size Co~IY.. ¿nå Perfs \\CoOO to \ \\030' :":EC7..Þ...NIG-.L INTEGRITY - ?JŒT /1 Þ_nmÚus Press Test: :;:1' d~ì'5í 15 min d~Sè>j 30 min d-SS-O C OIIi!TIe n t s : ~~\ \"'^'\v-o. "I \:)'1 O~S\::,,-~, ~ I ;}"1 -0 <.0 ..- ~CHlÜECAL INTEGRITY - PART 12 CONC,LUSIONS: ~r~:_~~~O K-~ \~ ,~ ) Jf1- 9];v1 ~ ( \ \--QÇo J- ? -- '1 i -1 l J ~ JrJ 3j ~i 2 ? ar i: ? ar :: DV C em en t: Volume s:· Þ-.mt. Liner Csg Cwi: ~ol to cover Der£s CJ:L~~""-~'\r-~ ~ s\œ.~'i \,,)± 'ror% ~ Theoretical TOC ~ ÚL~~ ~'b~ . Cement Bond Log (Yes or No) '--t€-,,:,> L\h -0<::. In AOGCC File ~,,~ \"'~ \:~ ~ ~ CEL ~valuation, zone ¿Dove perfs .\HJM, ~~ \ì ~~.."'- Proåuction Log: Type Evaluation f 1 : - : 2: RE: Tam 2N-332 (200-079) e e Tom, I measure - 1540' distance between top of reservoir picks in Tarn 2N-332 and 2N-320. Cheers Jerry -----Original Message----- From: Thomas Maunder lto:tom maunder@admin.state.aK.us Sent: Monday, April 10, 2006 12:04 PM To: Veldhuis, Jerry H Subject: Re: Tarn 2N-332 (200-079) Hi Jerry, How does the distance compare at the "top" of the interval. That is the base point I use for "what comes through the roof". Tom Veldhuis, Jerry H wrote, On 4/10/2006 11:58 AM: Gentlemen, To answer the question posed below "Are there any other wellbores that penetrate the Bermuda within 1/4 mile radius of 2N-332". I have looked at the software applications we use for G & G and engineering work in our offices and at the wellbore path info for the Tarn 2N-332 well to help clarify the question from Tom Maunder mentioned below. I also see only the one wellbore 2N-320 as the nearest neighbor to the 2N-332. At the approximate center of the reservoir penetration in 332 - 4850' sstvd ) it is less than 1/4 mile from the 320 Bermuda reservoir center point (I put it - 1550' due east). Hope this helps verify/clarify the concerns. Call if questions Jerry Veldhuis Geophysicist NSOD / Tarn-Meltwater Team ConocoPhillips Alaska, Inc. ATO 1144 (907) 265-6396 office -----Original Message----- From: Dahlgren, Eric Sent: Monday, April 10, 2006 11:09 AM To: Veldhuis, Jerry H Subject: FW: Tarn 2N-332 (200-079) lof2 4110/2006 12:38 PM RE: Tam 2N-332 (200-079) e e Sorry to pass the buck, but can you help mw with this? EWD -----Original Message----- From: CPF2 Prod Engrs Sent: Monday, April 10, 2006 11:02 AM To: Dahlgren, Eric Subject: FW: Tarn 2N-332 (200-079) Eric, Can you help Bob out with this. MTB -----Original Message----- From: NSK Prod Engr Tech Sent: Monday, April 10, 2006 10:57 AM To: CPF2 Prod Engrs Subject: FW: Tarn 2N-332 (200-079) Mike, I need some help with this one. -Bob -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, April 10, 2006 9:33 AM To: NSK Prod Engr Tech Subject: Tarn 2N-332 (200-079) Bob, We have received the sundry for 2N-332. One question. Are there any other wellbores that penetrate the Bermuda within 1/4 mile radius of 2N-332. I used 4900' tvd in -332 as my center point. I only show 2N-320 to be in the area and from my rough calculations it appears to be about 1600' distant at 4900' tvd. The map I can access may not be the most current, so I'd appreciate if someone over there would verify if there are any other wells in the area. Thanks. Call or message with any questions. Tom Maunder, PE AOGCC 20f2 4/10/200612:38 PM 4800 4400 4000 3600 3200 2800 ^ I 2400 ..--. +- Q) Q) 2000 ..... '-' .£: +- 1600 '- 0 Z 1200 800 400 0 400 800 PHILLIPS Alaska, Inc. ~oó.. 079 i C_.. .. fin'hF';;; iJh:-;;¡¡¡¡ii;;idi Dot. o,,,nod' '.-Moy-2000 i Plot Refentl"C8 is 332 V....ion '12. < L Cooter_a are ÍfI teat rafer.¡')1Ce slot 1332. \ IT1\I8 Verticol Depth. or. '''"enco RKB (HobO'. 19E).! . InB ' .... ~l\IT£g Structure : Tam Drill SlIe 2N Well : 332 : Tarn Development neld locatIon: North Slope, ~o / ~'> ,<;\"-\(:)~ I- <- West (feet) 9600 9200 8800 8400 8000 I ')L \<.000 7600 7200 6800 6400 6000 5600 5200 4800 4400 12800 12400 12000 11600 11200 10800 10400 10000 ~. .... 4500 ~ ~ 4500 4500· , ~, 4100"'" , , ''''<, ',\ .~'00 3900 ',,410~\41oo . '" .3900 37~0'" ~ ~" ~ ···....3700 "X$I Iml. 51~ò"" I 490Ò"' , J 4700t, .,4300 .. 4300 , /ill] ...·...,.5300 4300 ", ""0.5100 , ""....4900 41òit, '·......4700 .... ........ ...., "-....",~500 3900" .... .... ", '...",~300 "'04100 37'oÔ", , _ ", 3900 ... "e. ~ ......., ...3500 §. ""-','!coo I '""--~"'" j - _ ....1..900 _ o"'~_,_,. AQnn I - - ___,,!~O_ - -__4.?~0_ _ _J3~~~~~:~::-:':~·"d~00'.1.'0~ r - - - - ......3900··~·9?0 - - - - _....3700 - - - - .....3500 - - - - .....3300 - - - - 3100 ....-- ~ ; ...... J:;ee . .;; ~ "^'- 5100 4700 4500 4300 4tOO 3900 ~oo I ~ _... - _..- - - - - ,-~.....---!1~C:h' ~2't-", _ ::.1~qL . ~100 3900 _- 4700 4500 510049004700 3900 I-·---::'-:":.f-"'-"""'~_'__ . 3700 3500 3300 31000 ...- 3700 3500 ...- ---..--.. ~31 ON '"'' 1 ,." "., ---;;;;-""-,~ I 12800 12400 12000 11600 11200 10800 10400 10000 6800 5200 4800 6400 6000 5600 9600 9200 8800 (8400 ) 8000 < - West feet 7600 7200 4800 4400 4000 3600 3200 2800 ^ 2400 I Z 0 2000 ::1. :T ......... ...... 1600 () () - '-' 1200 800 400 0 400 800 e e 4400 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Re: Jet Pumped Wells Subject: Re: Jet Punlped \Vells From: "NSK Problenl Well Sup"" <n1617@)conocophi11ips.com> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: Ton1 ivlaunder <tom_t11aunder@)adnlin.state.ak.us> CC: "n 1617" <n 1617(~leonoeophi11ips.eom> Tom: I requested a list of surface powered jet pump wells from our PEls. The followlng should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently 51 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L-313 (PTD 1982190) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2 N - 3 03 (PTD 2 0 0 16 9 0 ) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (~TD 1981970) ..~..~, 2N- 3 32 (~TD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <tom rnaunder'i,iìadrnin.state.élk.us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails fro h'l b k maw 1 e ac regarding the wells out there on jet pumps. Would you please provide an updated listing of the wells presently on Jet pumps in greater KRU?? Thanks in advance. Torr Kuparuk and Alpine Annular Disposal during the third quarter of 2002: " "h(1) h(2)' h(3) Total f~r Froze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2-23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July2002 Sept2002 CD2-41, CD2-19, CD2-16, CD2-38 1C-IS 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1C-104 CD2-39 1966 100 0 2066 379 27500 29945 oct. 2o01 Sept 2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept 2002 CD2-38, CD2-44, CD2-29 c;ooK Inter Annutar L~tsposat aurtng tne tntra 6'uarrer oj~ zuuz: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date' Date Volumes Hansen #1 52255 100 0 52355 0 14869 67224 January. Sept 2002 ' Hansen #1 2002 _f Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2002: ' Freeze P~otect To~ai Volume' Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 CD2-33, CD2-39, CD2- 14, CD2-15 1C-26 34160 100 0 0 34260 Open, Freeze Protected August ' September 1C-123, lC-! 19, 1C-102 2001 2001 ., 2N-332 31453 100 0 325 3187.8 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 1C-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 1C-102, 1C-131, 1C-125 IECEIVE'D SCANNED' NOV 0 5 2002. OCT 2 2002 Nasim Oit & Gas G~ns, Commission Anchorage Annular Dis ~osal durin the third ~2001: Z AI I, I I.14,1,1.4,1 .l..~ l,O~.lLlOl, f,I, {4,14,11,11,~ I, I I.G I, I I, I, I LI, {, IA.f,,f,l ~,G I UI~ .Z~LIkl ; . h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, lC-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June 2001 Sept 2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2OOO July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 ~ 1C-16 19579 100 0 19679 '0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Dia =osal Authorization Expired during the third quarter 2001: ' Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, ID-14'~ 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 - 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 "2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219).in August 2001. The volumes for the expired permit applies just to that permit. ~nnu~ar Lnsposat aurmg rne rmra ~uarrer of zt~ol : h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, lC-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June 2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 ,. 1C-16 19579 100 0 19679 0 19679 Sept2001 Sept2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 7 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 ! Total Volumes into Annuli ~or which Disposal Authorization Expired during the third quarter 2001: ' Total Volume ~ Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQll CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141," 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1 D-36, 1 D-34 2N-318 - 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. DATA SUBMITTAL COMPLIANCE REPORT 9/912002 Permit to Drill 2000790 Well Name/No. KUPARUK RIV U TARN 2N-332 Operator PHILLIPS ALASKA INC. APl No. 50-t03-20340-00-00 MD 12026 TVD 5250 Completion Dat 7/12/2000 ~ Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__.~o Sample No Directional Survey No .. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type M~!a. Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments 3835 8598 Case 2/22/2001 09822;~3835-8598 3835 11791 Case 2/22/2001 09836-'~3835-11791 3835 8598 Case 2122/2001 09824'~3835-8598 MD GPJNeu 2/5 FINAL 115 12020 OH 2/14/2001 115-12020 BL, Sepia TVD GR/Neu 2/5 FINAL 115 12020 OH 2/1412001 115-12020 BL, Sepia MD ReslGR 2/5 FINAL 115 12020 OH 2114/2001 115-12020 BL, Sepia TVD Res/GR 2/5 FINAL 115 12020 OH 2/14/2001 115-12020 BL, Sepia MD RES/GR 2/5 FINAL 115 8684 CH 2/22/2001 115-8684 BL, Sepia MD GPJDEN/NEU 2/5 FINAL 115 8684 CH 2/22/2001 115-8684 BL, Sepia TVD GPJDEN/NEU 2/5 FINAL 115 8684 CH 2/22/2001 115-8684 BL, Sepia TVD GR/RES 2/5 FINAL 115 8684 CH 2/22/2001 115-8684 BL, Sepia 9836 FINAL 2/22/2001 9836 ~"LIs Verification Digital Data LIS Verification FINAL 2/22/2001 LIS Verification Paper Copy 9824 FINAL 2/22/2001 9824 ~IS Verification Digital Data LIS Verification FINAL 2/2212001 LIS Verification Paper Copy 9822 FINAL 2/22/2001 982~//LIS Verification Digital Data LIS Verification FINAL 2/22/2001 LIS Verification Paper Copy SRVY RPT 0 8684 OH 8/1/2000 SPERRY 0-8684. PB1 SRVY RPT 6208 12026 OH 8/112000 SPERRY 6208.65-12026 MWD Formation Eval comp 3835 8598 1/912001 3835-8598 Digital Data MWD LIS 1/9/2001 Verification Listing LDWG LIS 3835 8598 1/9/2001 3835-8598 Digital Data Permit to Drill MD 12026 2000790 TVD DATA SUBMITTAL COMPLIANCE REPORT 919/2002 Well Name/No. KUPARUK RIV U TARN 2N-332 Operator PHILLIPS ALASKA INC. 5250 Completion Dat 711212000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-t03-20340-00-00 UIC N LDWG LIS LDWG LIS LDWG LIS 3835 11971 1/9/2001 1/9/2001 1/912001 Lis Verification 3835-11971 Digital Data Lis Verification Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? ~ Analysis -Y-WN- Received? Start Interval Stop Sent Received Daily History Received? Formation Tops Dataset Number Comments Comments: Compliance Reviewed By: Date: ~~Sl~k OIL A~D GAS CO~SER¥&TIO~ COMMISSIO~ TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 17, 2001 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Request for Annular Disposal AuthorizationmSundry Approval 301-219 Kuparuk River Unit (Tam) 2N-332 Phillips Alaska, Inc Permit No: 200-079 Dear Mr. Mallary: Enclosed is the approved sundry application for annular disposal operations in KRU (Tam) 2N- 332. In addition to complying with the requirements and limitations of 20 AAC 25.080 (volume not greater than 35,000 barrels or disposal period greater than one year), the Commission is requiring that pressures be monitored on the surface casing annuli of wells 2N-331 and 2N-329 while waste is being disposed of into 2N-332. At a minimum, pressure readings should be taken before pumping begins, during disposal pumping and at the conclusion of a given batch. Please inform Tom Maunder at 793-1250 Should the'pressure monitoring indicate any communication between the wells. The pressure monitoring records should be submitted to the Commission with the normal quarterly report or sooner if the currently planned wells are finished. BY ORDER OF THE C. gMMISSION Dated this / ~ 7w of August, 2001 jjc/Enclosures STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon. Suspend.. Operational ~utdown Re-enter su%oended well Alter casing Repair well Plugging. Time extension.. Stimulate Change approved program .. Pull lubing .. Variance _ Perforate _ Other _X Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 99' FNL, 924' FEL, Sec. 3, TgN, R7E, UM At top of productive interval 2166' FSL, 98' FWL, Sec. 33, T10N, R7E, UM At effective depth At total depth 3028' FNL, 249' FEL, Sec. 32, T1 ON.. R7E, UM 5. Type of Well: Development Exploratory Stratigraph,c Service_. (=sp~ 460669. 5911910) (asp'$ 451139, 5914229) (asp's 450793, 5914315) 6. Datum elevation (DF or KB feet) RKB 153 feet 7. Umt or Property name Kuparuk River Unit 8. Well number 2N-332 9. Permitnumber/approvalnumber 200-079 lO. APInumber 50-103-20340 11. Field / Pool Kuparuk River Field / Tarn Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 113' SURF CASING 3754' PROD CASING 11127' LINER 734' LINER Perforation depth: I I I i · [Tubing (si~e. grade, and measured depth Size 16" 7-5/8" 5-1/2" 3-1/2" measured 11600'-11630' true vertical 5009'-5024' Packers & SSSV (type & measured depth) 12026 5250 11889 5167 feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds High Early 385 sx AS III Lite, 240 sx Class G 255 sx Cla.~.q fi, 420 ~ Class G (Included above) 3-1--'2'. 9.3~-'. L-80 'rbg ~ 11307' MI). 11290= CSR CAMCO DS ~ 510' MD. Measured Depth 113' 3907' 11280' 12014' True vertical Depth 113' 2311' 4852' 5243' RECEIVED JUL 27 2001 Alaska 0il & Gas Cons. CommissiOn Anchorage 13. Attachments Description summary of proposal __ Detailed operations program. BOP sketch_ LOT test. surface cement details and casing detail sheets, schematic X 14. Estimated date for commencing operation 15. Status of well classification as: July 27, 2001 16. If proposal was verbally approved Oil __X Gas __ Name of approve,~// // Date approved Service 1/. I hereby cert~y.)~t the tore~in.ff~true and c~p,~ct to the best el rny knowledge. Signed /¢"~'/'"~'~ /-"~ /'"'"'~"~-'/~"'"'"'~" ~r FOR COMMISSION USE ONLY Suspended _ Questions? Call Brian Noel :~65-6979 Conditions of approval: Notify Commission ,o representative may witness i Approva, no.. )i Plug integrity BOP Test _ Location clearance ° -' Mechanical Ir.tegrily Test_ Subsequent form required 10-__.~,_1_~[.l~5'~,[ i"~' ~:~( ~ ~ ~'~ 2-~. ~, Taylor ~eamou~ · I Approved by order of the Oommission uommissioner Date ORiGiNAL Form 10-403 Rev 06/15/88 · SUBMIT IN /,,' Annulus Disposal Transmittal Form Designation of the well or wells to receive drilling wastes: 2N-332 The depth to the base of freshwater aquifers and if present: No Aquifers / Base Permafrost = +/-1,200 TVD RKB ~, stratigraphic description of the interval exposed to the 7-5/8" surface casing set in the Cretaceous shales of open annulus and other information sufficient to support the Colville Group below the West Sak sands. From the a commission finding that the waste will be confined and 7-5/8" shoe to the top of cement on production casing will not come to the surface or contaminate freshwater, shale and minor non-hydrocarbon bearing sands are exposed. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste: Nine wells on 2N pad - See attached map. There are no water wells within one mile of 2N-332. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry: types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined: Maximum anticipated pressure at casing shoe during disposal operations is 1,945 psi. See attached calculation page. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: See attached: cementing reports, LOT / FIT reports and casing reports for 2N-332 and the ten wells within 1/4 mile radius. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: See attached: casing summary sheet and calculation pages. Any additional data required by the Commission to confirm containment of drilling wastes: WELLS W/SURFACE CASING SHOE (+/- 2300' TVD) WITHIN 1/4 MILE 2N-332 Wells Permit# IPermitDatelCementReportl CasingTall¥ I No. ofLOTI Sourcewell I Ann. Vol. lStartDatel EndDate] x x 2 0 398-252 09/15/98 x x 2 2N-320, 2N-308, 2N-307 27607 01/01/99 02/28/99 letter 05/14/98 x x 3 see note A 32689 Ma¥-98 Auil-98 x x 2 0 letter 05/14/98 x x I 2N-321 109 Aug-98 398-253 09/25/98 x x 2 0 398-183 07/17/98' x x 2 12N-347, 2N-332, 2N-316 33825 May-00 Jul-00 letter 05/14/98 x x 2 2N-326, 2N-303 31808 Ma¥-98 Nov-00 300-186 07/21/00 x x 2 2N-349, 2N-305, 2N-326 31640 Sep-00 Oct-00 2N-320 2N-321A 2N-323 2N-326 2N-329 2N-331 2N-341 2N-343 2N-347 2N-348' 2N-350' * ) 2N-348 and 2N-350 proposed well paths to be drilled August 2001 ~A) soume wells were 2N-313 (9764), 2N-343 (2159), 2N-317 (5949), 2N-337 (7934), 2N-339 (6990) Kuparuk River Unit Comparison Well Name - Profile Name Sperry-Sun Drilling Services Horizontal Distance Proximity Scan on Current Survey Data (North Reference) Reference Survey: Kuparuk 2N- 2N-332PBI Single Point Scan at 3874.00ft. Measured Depth. Scan Radius is 1320.OOft. Reference Well C o m p a r i s o n W e I I Measured Vertical Measured Vertical Depth Depth Depth Depth Northings (ft) (ft) (ft) (ft) (ft) Eastings (ft) North Slope, Alaska Kuparuk 2N Proximity Relative Relative Distance North (ft) Direction Kuparuk 2N 2N-320 - 2N-320 3874.00 2300.11 3234.90 2300.25 674.33 N 2N-321 - 2N-321 3874.00 2300.11 3864.21 2300.25 1544.05 N 2N-323 - 2N-323 '/'' 3874.00 2300.11 3454.97 2300.25 1088.45 N 2N-326 - 2N-326 '/ 3874.00 2300.11 4305.95 2300.25 1099.84 N 2N-329 - 2N-329 v" 3874.00 2300.11 3284.63 2300.25 367.15 N 2N-331 - 2N-331 GYRO v' 3874.00 2300.11 3814.70 2N-341 - 2N-341 3874.00 2300.11 4211.62 2N-343 - 2N-343 GYRO 3874.00 2300.11 3268.02 2N-347 - 2N-347 v" -- · ~ 3874.00 2300.11 4218.87 ,~, 2N-348 Plan - 2N-348 Wp03 e~ ~-~'~ ~,\~, e,.r,. ) 3874.00 2300.11 3390.87 ~'~-~ ~,C4,l~ !~ ' -~.\~'/ 2N 350 Plan-2N-350 Wp02 ~:~'~'"'~~e~, ~-l~-,)~" -- ~"~ 387400 2300 11 - . . 3753.58 All station coordinates were calculated using the Minimum Curvature method. All data is in feet (us) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. Grid Convergence at Surface is -0.298°. 2300.25 167.29 N 2300.25 598.04 S 2300.25 549.34 S 2300.25 164.00 N 2300.25 176.90 N 2300.25 199.00 S 1437.56W 1101.45 84.28 1969.20W 1130.40 29.95 1812.72W 891.06 53.99 2864.33W 629.22 328.28 1825.30W 735.25 105.58 2560.67W 398.22 183.91 2989.56W 1248.87 201.42 2003.13W 1233.77 154.54 3211.78W 787.71 239.43 2090.55W 588.68 131.19 2612.15W 767.63 185.88 3 July, 2001 - 15:59 Page 2 of 2 DrillQuest 2.00.09.001 "~),i ..... :::-~-~ ..... ,~.1',~;00 ..... i' ..... ::::!::: ..... /::: ..... i.! ..... :~?~;`/.~`~..~....~~;..~`~..~?~`````~' :'"". ".' '" ' "'x" '" ' '. "' ...... 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Grade L 80 Pburst @ 100% 6890 psi Pburst @ 85% 5857 psi Fluid Weigth on Backside 8.3 ppg Max Disposal Pressure 1500 psi Maximum Mud Weight = 44.6 ppg (to burst casing) Surface Casing Burst MMW = Pb@85%+(Fluid Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) Maximum Pressure at Surface Shoe Max Disposal MW 12.0 ppg Max Pressure at Surface Shoe = 1945 psi Max Pressure at Surface Shoe Max Press=Max Disposal Press+(Max Disposal MW)(.052)(TVD)-(Fluid Wt. On Backside)(.052)(TVD) Intermediate Casin(; Size 5.500 In. Wt. 15.50 lbs. Grade L 80 Pcollapse @ 100% 4990 psi Pcollapse @ 85% 4242 psi Gas Depth (TVD) 2311 ft. Gas Gradient 0.11 ppg Max Disposal Pressure 1500 psi Maximum Mud Weight = (to collapse casing) 24.9 ppg Intermediate Casing Collapse MMW = Pc@85%+(Gas Gradient)(Gas TVD)-Max Disposal Press (TVD)(.052) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 02, 2001 RE: MWD Formation Evaluation Logs 2N-332, AK-MM-00069 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-332: ~ °~O'"/at 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20340-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20340-00 2" x 5" MD Neutron & Density Logs: 50-103-20340-00 2" x 5" TVD Neutron & Density Logs: 50-103-20340-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 01, 2001 RE: MWD Formation Evaluation Logs 2N-332 PB1, AK-MM-00069 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-332 PBI: ~/pO- O-I 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20340-70 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20340-70 2" x 5" MD Neutron & Density Logs: 50-103-20340-70 2" x 5" TVD Neutron & Density Logs: 50-103-20340-70 1 Blueline J 1 Folded Sepia / 1 Blueline,-'/ 1 Folded Sepia./' 1 Blueline ~'' 1 Folded Sepia.-/... 1 Bluelinev'/ 1 Folded Sepia ~ To: RE: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 05, 2001 MWD Formation Evaluation Logs 2N-332, AK-MM-00069 1 LDWG formatted Disc with verification listing. API#: 50-103-20340-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETI'ER TO THE ATTENTION OF: Sperry-Sun Drilling Service Arm: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: WELL LOG TRANSMITTAL To: State of Alaska January 05, 2001 Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-332 PB1, AK-MM-00069 1 LDWG formatted Disc with verification listing. API#: 50-103-20340-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATrACI-IED COPY OF THE TRANSMITFAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ! To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-332 PB 1, AK-MM-00069 December 15, 2000 1 LDWG formatted Disc with verification listing. API#: 50-103-20340-70 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATI'ENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 CASING TEST and FORMATION INTEGRITY. TEST Well Name: 2N-326 Reason(s) for test: Date: 10122/00 Supervisor: Deerl W. Gladden [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7 5/8" 29.7# LB0 BTC Mod Casing Setting Depth: 4,295' TMD 2,298' TVD Hole Depth: 9,571' TMD Mud Weight: 10.5 PP9 Length of Open Hole Section: 5,276' Leak-off Press. + Mud Weight = 661 psi . + 10.5 ppg / 0.052 x TVD Q.052 x 2,298' EMW for open hole section = 16.0 ppg u = i~.~, ,, ~ ~,D. EMW = Pump output = 0.0846 bps Fluid Pumped = 2.5 bbl 2,200 psi 2,100 psi 2,000 psi 1.9D0 psi 1.800 psi 1.700 psi 1.600 psi i.6(X) psi 1,400 psi i.300 psi 1,200 psi I,ID0 psi 1.000 psi ~0 psi 8O0 psi 70) psi 6~0 psi 5~0 psi 400 psi 300 psi 200 psi 100 psi 0 psi I'"l'"l'"l"'l'"l'~' ................ ONE MINUTE TICKS I ........ - LEAK-OFF TEST ~ CASING TEST ~ LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME i TIME LINE . STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE :::ZZZZZZZ;E. . EZZZEEEZZ7 2 stks 49 psi i ................ .&. ............... & ................. CASING TEST DATA MINUTES POR CSG TEST STROKES PRESSURE ' ................ ' ............... Ir''~ ....... '.' .... 1 ..................... .O.. ?!. .k?. .._ ~ ..... .o._p.?.t .... . 2 stks 31 psi !. ................ L ............... d ................. .I 4 stks 90 psi' ! , ! 4 stks 140 Dsi ..................................................... i' ................ F .......................... ~' ......'1 ,. - , 6stks 381pm 6~tks 140psi ~ ' ' ' ..................................................... ? ................ t ................................. i · 8 stks 188 ~si ...................... &- .......................... r ................ ~' .......................... ~' ...... "1 ' 10 stks 233 psi i 12stks ! 282psi ................ T, ................ 14 stks ,i ............ 322 pSl:'""1~ ~,'..~'~ .............. [, .............................. 14 stke 1,404 p'"s~" , ................ .,. ............... · ......... --- .....~ ~,~ .vF ............... .~ ........... ~.r.d. ........... ,....-. ,-~,~ i ! 16 stks i 376.1E. si i I i , , 18 stks ; 420 ps, ,,..¢f~ ; 18 stks I 1,940 ps,; : i 20stks ~ 470PSI ~.,,Li, i 198tks , 2,004psi i ................ '~- ............... ? ......... -" ...... ~ ~ .............r ............... '1 ........... z ..... I I I · _4 I' · I I , 22stk~ , 514 m~ .... I ................ -i- ............... .i, ............................... i- ............... .i ................. I I I · ~. I I : i 24stks ~ 555ps, d:~ i ................ -4- ............... · ......... -'- ................... ...,~ i I i · I I . I i i ii i i- : . 26 stks. ,, 599 psi , ~.~'q ,. . , : i ~ -.'2 ~ : , , , 28stk$ , 644ps1..,~ , . , ' ................ "~ ............... t ................ ~ .I.m .............. I' ............... tH ................ i 30 stks t ' 661 Psi I ................................. '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 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 11 ' 1: ................................. t ................. I I I ' SHUT IN TIME I SHUT IN PRESSURE OOmln i ~ 661 psi : 10min i 622.E. si i 20m~n - , 613DS, , 4.0m~n , 577~s, , 5 0 min !' i 564psi i 6.0 mln , , 555 $1 , 7 0 mln , . , 550051 , 8.0mln . , 541DSr , 9.0mln : - I 537psl : I SHUT IN TIME , SHUT IN PRESSURE I · I I ' i , 00m,n , , 2.004os, , I- ..... '- .......... F ............... 4 ....-' .......r. .... -I I · i I · i I 1.Omln I I 2,004 ps, , r ................ r ............... I .............. : 2.0m~n : ~ 2,004 i · I l : 3.0 mln I t .2,004 p si'?', I. ................ E. ............... ,4 ................. ,4 I · I I · I i i · I I , 4.0 mln , .. 2,003 ps1., i 50rain i i 2,003~si ,~ .... :""-' ..........F ............... t ........... ' .... 1 i ' I ' I ., 6.0 mln ! I 2,003 pSI j i' ................ r ............... 1 ........ ~ ...... ~--i i 7.0 min ! ! 2,003 ps, i r ................ ' ............... -i ........... i....S:.0...m.j.n...~[ ............... i...2..,.0.9.3..P..=.!.i ! 9.0min i '_. ! 2,002psi · i . I ' ~- · i i 10 0 m[n : ~ ~'~' ', - ~ ..... ~.'.' ......... ~ ........... ~...4 .......... ;;',!~ .... d I - · I ~-,..I "- I , 15.0 m[n , : 2,0.02_ psi , ~ ................ ~ ........... r-=-I .... ~'~' ..... 1 I ' I I · I ; 20.0 mln : / 2,002-psi j r ................ r ............... 1 ........ i · i i · i I 25.0 mln, I 2,002pm :- ~ ................................ I--~ .............. !...~..o:.o...m.."~..i ............... j...2_,P.g&p.~Lj NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-326 Date: - 10i16100 Supervisor: Dearl W, Gladden Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open' Hole Adequacy for Higher Mud Weight Casing Size and Description: 7 5~8" 29.7# L80 BTC Mod Casing Setting Depth: 4,295' TMD 2,298' TVD Hole Depth: 4,333' TMD 2,310' TVD ' Mud Weight: 9.5 PP9 Length of Open Hole Section: 38' EMW --- Leak-off Press.. + Mud Weight 0.052 x TVD = 778 psi + 9.5 ppg 0.052 x 2,3!o' EMW for open hole section = 16.0 ppg Pump output = '0.0846 bps - Fluid Pumped = 0.7 bbl 3.200 I I-I I I I I I I IIIIIIIII I'1 I I I I I I I I I I I I I ! I I - .... _. '--__ ' ........ ITIMELINE' "' . .' .............. ._._ --'~.'-- I --e-- LEAK-OFF TEST ! --,~--CASING TEST r -e- LOT SHUT IN TIME i ~ CASING TEST SHUT IN TIME I i TIME LINE rJ 3.100 psi 3.000 psi Z~00Pa 2.800 psi 2.700 psi 2.600 pa 2.,500 p.fl 2.4OO psi 2.3OO pa 2.200 pa 2.100pa 2.000 psi 1,¢;~0 psi ! .800 PSi 1,700 psi l,~00pa 1.500 psi 1,400 psi 1,300 psi 1,200 psi 1.100 psi I 800pa i ~opa 500 psi 400 psi 300 pd 100 psi STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE :::::::::::::::::::::::::::: ......... .o..t,_?j ..... ii' .................... ..... .... 2atke 201psi ~j.~ 2arks ! 31 Esi ............................................ -'---:-'- ~=~ ........... ~ ............... I ............ ',---I 4 atks 447Ds, .',~c? ~ 4 stks I 140 Ds, ...........................................6 stks 621~si" ................. '~, .~'~ I~ ............... 6 stks I~ .......... 381 ssi' ..... .J ...,~ ................ ........ ......... 1 .... ..................................................................... iiiiiiiiliZiiiiii',',iiiiiiiiliiliii: iiiiiiiiiiiiiiiii Z'[E.E(Ei! '' i i 14stks i 1,404 , ................ .~ ............... , .................. ~ ................ ?--~--~-,- .... .,--%---_-~.._. -,- --;.I1~' ; , 11~ $~K$ 1,ti/U DS1 ! m ! ! I ! m ! ! I ! I ! ! ! SHUT IN TIME SHUT IN PRESSURE ""676';~'FrT'r .................. 'A;~,"&'F'I ..... L*.: ..........I- ........................... .r. .... -I .... L..o_mj.n.... ~ ................... &.o..o~.E~i..k ' 2.0 min[ 2,004 p. ,~ I I I I ................................. ..s..~.~.~ ~.a..E., I ............... .s..H.U..T.~ .P..~.E..S.S.U..~.E 3.0 min i~.~4.'~ ~.i...'~' ....o...o...mj :... ,,' ............... i...ZZ~.~,.s.L.] ................. '~ ................ ,....4...o...mj.n....: ............... j...2.,.o..o.a.. P.~L 1.0min'!' i 772~..si ! ................ t ............... ! ................ I 20min , , 760 psi , ..... : .......... 4- ............... ~ ................. .I · I I · 3.0m~n ; : 755Ds, : ........... : .... t ............... ! ............ :'"I ....4.:.0...m. Ln... ,:. ............... ,,,....7..5..2. p_.s.!...~ ...g:9_.mJ:... i. ............... i...7..s..o...R?L.j 5.0 min ~ i...2.;.O..O.3..p..s.L' ""~".~'~'i~'"~ ................ 2,003 ~.si .................. .................. 6.0min ; i 749 psi i 100min : i 2,002Dsi : · I I · 7.0m~n : : 747Ds, : 150min [ i 2,002Dsi l ................ t- ............... f .......... " ...... t ...... : .......... I' ............... ~ ........... z .....'1 · ! . I ' 8.0mln , , 745nsl , ' ' ' ' ' 20 0 mm , , 2,002 Ds~ , ................ 4- ............... } ......... ~ ...... 4 ...... :: .......... I. ............... ~ ........... · ..... - · m I ' 9.0 mln : : 742pm ; 25.0 min: j 2,002 psi ) ................ ~ ............... ? ................. ~ ,-- ............... -- ............ "1---- ....... ' ..... "1 . · m I · I .._l..O....O...m. Ln..jL ............... !....7...4...O.p_.s.!...j .....3.0.:.O...m..i.n. .................. j...2.;.o..o.2..p.~t.j NOTE: STROKES TuRN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska Drilling Cementing Details Well Name: 2N-326 Report Date: 10/13/2000 Report Number: 8 Rig Name: Nabors 19E AFC No.: AK0116 Field: Tarn ............. i I~ll,,I. I Ilal II Casing Size Hole Diameter:. Angle thru KRU: Shoe Depth: LC Depth: % washout: 7 3/8" 9 718" 4295" 4209" Centralizers State type used, intervals covered and spacing Comments: _ Used 41 Gemeco bow spring Centralizers & 4 Stop collars - Cent In middle of Jt on stop collars on Jts # 1,2 &79,80 - Across collar on Jts # 3-12,15,18, 21, 24, 27, 30, 33, 36, 39, 42, 45, 48, 51, 54, 57, 60, 63, 66, 69, 72, 75, 82, liS, 88, 91, 94, 97, & 100 i - Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.2 22 17 17 9 Gels before: Gels after: Total Volume Circulated: 6/7 2/3 9085 stks ( 917 bbls) Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbls 8.4ppg Spacer 0 Type: Volume: Weight: Comments: MUDPUSHXL 40 10.2ppg Lead. Cement 0 ". : Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments':.. . :' · AS III Lite 72 410 10.7 4A4 · !'.:'::Z:::. Z'I.::z. ::' ;:i': '..."'.'.:'..'."..: Additives: ::.... i .:; :..: ..' :: . i:' ".'. ....... ......... :. D053 30.0%, D046 0.60%, D079 1.5%, S001 1.5%, D124 50.00%, D044 9.0% Tall'Cement,..0' .':. ~ ':'. '. '.. :. Z iType: Mix wtr temp: No. of Sacks: Weight: Yield: C~i~;~'t~:'!: '" ..:"i' :; :"~. i..:". :':. '~'.": ~ 72 24o ::: :,.~.: ;::..:..:. ': ':., ... '.. * ':: ..' ... . ... G 15.8 1.17 i':.: 'i !' i;'! :i :is: '::. '; ':.' :"i: .Z':: ::,'. 'i ,.... ':".. :., Additives: ?.'. ".' ;:' .. {!:! :r.i ii'!: i{.. ,: .. :.' :. ::.. ;.i'. :': ..... '!' D046 0.20%, D065 0.30%, S001 1.0% blSpla~dht: ;io.:: .'. :...! :..' :'. "....!. Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: ~)rfirh~nt~i'! :;:: 'i'.. ;.:~: ::.' '. .... '-: 6.65bpm 6.6$bpm 115K ;!':ii:.i:!i::: :i:::::::"ii! i:: !':!'.:! !i! i::'.:= '!=:::':'i;.' .: :: ::. :.' .:':;.:::!:.!' 12' 30 fpm 43K i:: :}!,:! :,:,; ::! ':;, :...":: .' :.: .':;~ :;: Theoretical Displacement:193.46 Actual Displacement: Sir. Wt. in mud:101K ~alculated top of cement: CP: Bumped plug: Floats held: ~urface Date: 10/1 3/00 No Yes Time:5:30AM :lemarks:No CMT to surface. TIH w/Tam tool. Open Tam port collar, Pump 5 bbl water with Rig. Turn over to Dowell. Dowell pumped 105.9 bb110.Tppg CMT- O 89 ~bl pumped 10.3ppg CMT to Surface, O 95 bbls pumped 10.5+ & e 105.9 pumped had 10.6+ CMT to Surface. Closed Tam port collar ,Pressure test to 1000 pal 'OK" ClP Top Job ~ 8=30 AM If& .... ~. ~,~ ....... I_. _ Cement Company: IRig Contractor: NABORS IApproved By: Dearl W. Gladden Dowell Casing Detail 7-$/8" surface casir~a_ WELL: 2N-326 PHILLIPS Alaska, Inc. DATE: 10/14/00 ! OF I PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 19E RT to GL = 34.40' TOPS 7 5/8" Landing Joint (38.97 total) RKB tc 34.74 7 5/8"' FMC GEN IV FLUTED MANDREL HANGER 2.62 34.74 jts.80-102 7 5/8". 29.7#. L-80 BTC-MOD 964.13 37.36 Tam Port Collar 2.48 1001.49 j~s 3-79 7 5/8", 29.7#, L-80 BTC-MOD' 3204.90 1003.97 Gemeco Float Collar 1.36 4208.87 its 1-2 7 5/8". 29~7#, L-80 BTC-MOD 83.80 4210.23 Gemeco Float Shoe 1.51 4294.03 'BTM OF SHOE @ ..... >>>>> 4295.54 TD 9 7/8"' H, 4303' Csg Hanger goes in the , op of Joint # 102 ~ 41 TOTAL, Gemeco Bow Spring Centralizers 4, Centralizers In center of its. i & 2, 78 and 79 over slop collars 37 ,Centralizers over collars of its., 3-12, 15, 18, 21,24, 27, 30, $3 36, 39, 42, 45, 48, 51, 54, 57, 60, 63, 6~, 69, 72,75, 82, 85, 88, 91, 94, 97 & !'00 ,. ' ,' , ,, .' .,. ." Remarks: String Weights with Blocks: 115k Up. 43k Dn,. 15k Blocks. Ran 102 joints of casing." Drifted casing with 6.750" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Eight joints surplus. Nabors 19E' Drilling Supervisor: Dearl W. Gladden ., P , LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 14, 2000 Mr. Daniel T. Seamount Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Well Completion Report for 2N-332 (200-079) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Well Completion Report for the drilling operations on 2N-332. If there are any questions, please contact me at 265-6830 or Tom Brassfield at 265-6377. Sincerely, R. Thomas Kuparuk Drilling Team Leader Phillips Drilling RTfrJB/skad RECEIVED AUG 1 6 2000 Alaska 0ii & Gas Cons. Commissioe Anchorage '(" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~l Gas D Suspended r"'l Abandoned D Service 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-079 / 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 '~ 50-103-20340-00 4. Location of well at surface ........... ~ ! '.?~::.; "~. !':'.' i!.~I'~, i ~ 9. Unit or Lease Name 99' FNL, 924' FEL, Sec. 3, T9N, R7E, UM (ASP: 460669, 5911909) i d~'L =: I~ Kuparuk River Unit AtTop Producing Interval i '~._ ~':~.(~) i 10. Well Number i' , ~, :-,.._'.,-:, 2166' FSL, 98' FWL, Sec. 33, T10N, R7E, UM (ASP: 451139, 5914229) i ~ c~'~,.~'~.b' ~. 2N-332 At Total Depth~.~~.,'~ ~.. 11. Field and Pool 2249' FSL, 248' FEL, Sec. 32, T10N, RTE, UM (ASP: 450793, 5914315) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tarn Pool RKB 35', Pad 119 feetI ADL 375108 & 380054 & 375074, ALK 4809 12. Date Spudded 13. Date T.D. Reached 14. Date Oomp.,l.Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions June 10, 2000 July 1, 2000 July~'r2000,'~'~ I N/A feat MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12026' MD/5250' TVD 11889' MD/5167' TVD YES r~ No DI N/A feetMD 1260' 22. Type Electric or Other Logs Run GR/Res/Den/Neu, CCI. 23. CASING, LINER AND CEMENTING RECORD SEI-DING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 113' 24" 9 cu yds High Early 7.625" 29.7# L-80 Surface 3907' 9.875" 385 sx AS III Lite, 240 sx Class G 5.5" x 15.5# L-80 Surface 11311' 7.5" 255 sx Class G & 420 sx Class G 3.5" 9.3# L-80 11280' 12015' 7.5" (included above) 2N-332 PB1 cement plug dressed off to 6050' MD 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) 3.5" 11307' 11290' (CSR) 11600'-11630' MD 5009'-5024' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11600'-11630' Pump 192,400#s 16/20 prop and place 191,500#'s behind pipe with 12 ppa on formation leaving 900# in pipe. 2N-332 PBI: 118sxClass G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 29, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 8/4/2000 6 h rs Test Period > 454 810 0 100I 2029 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 360 psi not available 24-Hour Rate > 1816 3240 0 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A ooo 0 RI GIN A L Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~' ,30. ~EOLO~IC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 11494' 4955' T-2 11694' 5058' Annulus left open - freeze protected with diesel. 31. LIST OF A'I-rACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 Signed ~ Title KuDaruk Drillino Team Leader Date . Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Shut-in, Other-explain. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate "none". Form 10-407 RECEIVED AU(; 1 6 2000 Alaska Oil & Gas Cons. Commission Anchorage Date: 08/10/00 ARCO ALASKA INC. WELL SD/vSW_ARY REPORT Page: 1 WELL:2N-332 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:06/10/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20340-00 06/09/00 (D1) TD/TVD: 115/115 SUPV:R.W. SPRINGER MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 (115) RIG OVER WELL, PREPARING TO N/U DIVERTER Released rig from 2N-347 @ 1400 hrs. 6/9/00. Move sub from 2N-347 to 2N-332. 06/10/00 (D2) TD/TVD: 634/630 SUPV:R.W. SPRINGER MW: 10.0 VISC: 100 PV/YP: 20/43 (519) DRILLING 9-7/8" SURFACE HOLE @ 1095' APIWL: 6.5 Rig up. N/U diverter. Accept rig @ 0600 hrs. 6/10/00. PJSM and pre-spud meeting. Function test diverters. Clean out conductor. Drilled from 113-634' 06/11/00 (D3) TD/TVD: 634/630 SUPV:R.W. SPRINGER MW: 0.0 VISC: 100 PV/YP: 0/ 0 0) DRILLING @ 2515' APIWL: 0.0 Drilled from 634' to 1807'. Maximum gas 830 units @ -1300' Pump hi-vis sweep, circ hole clean. POH short trip from 1804'-882', no drag, no tight spots. RIH. Drilled from 1807'-2072'. 06/12/00 (D4) MW: 10.2 VISC: 52 PV/YP: 20/19 APIWL: 6.4 TD/TVD: 3482/2176 (2848) DRILLING @ 3900', T.D. @ 3917' SUPV:R.W. SPRINGER Drilled from 2072' to 3134', pumped sweeps @ 2598', 2819' & 3103' Circ and condition f/short trip. Short trip, tight from 2109' to 1858'. RIH. Drilled from 3134'-3482'. 06/13/00 (D5) MW: 10.3 VISC: 53 PV/YP: 20/21 APIWL: 6.5 TD/TVD: 3917/2290 (435) DISPLACING CEMENT SUPV:R.W. SPRINGER Drilled from 3482' to 3917'. Circulate lo-hi sweep. POH, short trip to HWDP. RIH to bttm, no fill. Circulate and pump lo-hi sweeps, 900 units gas on bottoms up. Monitor well, pump dry job, POH. PJSM. Run 7-5/8" casing. 06/14/00 (D6) MW: 10.3 VISC: 47 PV/YP: 19/14 APIWL: 6.5 TD/TVD: 3917/2290 ( 0) DRILLING CEMENT & FLOAT SHOE. SUPV:R.W. SPRINGER Continue running 7-5/8" casing. PJSM. Pump cement. N/D diverter. N/U BOPE and test to 250/25009. RECEIVED AU(; 1 6 2OO0 Alaska Oil & Gas Cons. Commi~ion Anchorage Date: 08/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT PaGe: 2 06/15/00 (D7) MW: 9.4 VISC: 47 PV/YP: 20/15 TD/TVD: 4166/2290 ( 249) DRILLING 6-3/4" @ 4496' SUPV:R.W. SPRINGER APIWL: 5.0 RIH w/drill out assembly, tag cement @ 3743'. Drilled cement from 3743' to 3800'. Drilled cement and float shoe, 20' new hole to 3937'. Circ hole clean, displace hole w/new 9.5 PPG mud. Perform FIT to 16.1 PPG EMW. POH. PJSM. RIH to 3906'. Ream from 3906' to 3937'. Directional drilled from 3937' to 4166' 06/16/00 (D8) MW: 9.7 VISC: 45 PV/YP: 19/11 APIWL: 4.6 TD/TVD: 5367/2290 (1201) DRILLING @ 5680' SUPV:R.W. SPRINGER Directional drill from 4166' to 5177'. Circ sweep and circ hole clean. Wiper trip to casing shoe. Wash from 5137' to 5177', no fill. Drill from 5177' to 5367'. 06/17/00 (D9) MW: 9.7 VISC: 46 PV/YP: 16/17 TD/TVD: 6536/2290 (1169) DRILLING @ 6750' 48 HR FIELD POWER SUPV:R.W. SPRINGER Directional drill from 5367' to 6536'. APIWL: 4.6 06/18/00 (D10) MW: 9.6 VISC: 45 PV/YP: 14/17 APIWL: 4.8 TD/TVD: 7358/2290 ( 822) DRILLING @ 7665' (24 HR FIELD POWER) SUPV:R.W. SPRINGER Directional drilling from 6536' to 6853'. Short trip from 6853' to 5106' No overpull or drag hole Good. Circ hole clean. Drilled from 6853' to 7358'. 06/19/00 (Dll) MW: 9.6 VISC: 49 PV/YP: 16/17 APIWL: 4.8 TD/TVD: 8367/2290 (1009) WIPER TRIP F/8430-6783' (24 HR FIELD POWER) SUPV:R.W. SPRINGER Directional drilling from 7358' to 7863'. Pump hi-vis sweep and circ hole clean. Drilled from 7863'-8304'. Circ hole clean for ECD. Drilled from 8304' to 8367' 06/20/00 (D12) MW: 9.6 VISC: 45 PV/YP: 15/13 APIWL: 4.4 TD/TVD: 8683/3710 ( 316) R/U TO TEST BOPS SUPV:DEARL W. GLADDEN Drilling from 8367' to 8462'. Circ hole clean. Wiper trip to 5783'. TIH. Pump sweep, circ hole clean. Drilling from 8462' to 8683'. PJSM. TOH. 06/21/00 (D13) MW: 9.6 VISC: 44 PV/YP: 16/14 APIWL: 4.4 TD/TVD: 6050/3710 ( 0) PBMD 6050' CTOC SUPV:DEARL W. GLADDEN PJSM. Test BOPs. PJSM. TIH w/ tbG stinger. Circ and condition hole, set 20 bbl Gel pill, covers 6783' to 6416'. PJSM. Pump pluGback plug covers 6416' to 6050'. TOH. Circ hole and assy clean. RECEIVED AUG 16 2000 Alaska Oil & Gas Cons. Commission, Anchorage Date: 08/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/22/00 (D14) MW: 9.6 VISC: 44 PV/YP: 14/11 APIWL: 6.2 TD/TVD: 6050/3710 ( 0) DRLG 6 1/2 X 7 1/2" HOLE SUPV:DEARL W. GLADDEN CBU, condition contaminated mud. TOH. PJSM. P/U BHA #4. 06/23/00 (D15) MW: 9.6 VISC: 50 PV/YP: 16/16 APIWL: 4.8 TD/TVD: 6801/3227 ( 751) DIR DRLG @ 7054' SUPV:DEARL W. GLADDEN Dir time drilling from 6150' to 6359', sidetracking off cement plug, actual departure point 6250' MD. Dir drililng 6359' to 6422'. Finish circ sweep to surface. Pull up to 6302', run check survey @ 6302' & 6328'. Dir drilling 6422' to 6801' 06/24/00 (D16) MW: 9.6 VISC: 48 PV/YP: 14/14 APIWL: 4.6 TD/TVD: 7812/3572 (1011) DIR DRLG @ 7866' SUPV:DEARL W. GLADDEN Dir drilling 6801' to 7243'. Pump sweeps as needed to clean hole and maintain good ECDs. Dir drilling 7243' to 7812' Pump sweeps as needed. 06/25/00 (D17) MW: 9.6 VISC: 53 PV/YP: 16/19 APIWL: 4.0 TD/TVD: 8570/3819 (758) DIR DRLG @ 8862' ( ON HI LINE POWER 24 HRS) SUPV:DEARL W. GLADDEN Finish pumping sweep out of hole. Wiper trip to 5978', no excess drag, no swab. TIH. Dir drilling 7812' to 8096' Finish circ sweep from hole. Dir drilling 8096' to 8507' Finish circ sweep from hole. Dir drilling 8507' to 8570' 06/26/00 (D18) MW: 9.7 VISC: 52 PV/YP: 17/18 APIWL: 3.6 TD/TVD: 9486/4148 (916) DIR DRLG @ 9771' (RIG ON HI LINE POWER 24 HRS) SUPV:DEARL W. GLADDEN Dir drilling from 8570'-9265'. Circ and condition. Circ hole clean, rotate and reciprocate drill pipe thru circulation. Wiper trip to 7400'. Dir drilling from 9265' to 9486' 06/27/00 (D19) MW: 9.7 VISC: 47 PV/YP: 14/12 APIWL: 3.6 TD/TVD:10686/4599 (1200) DIR DRLG @ 10895' (RIG ON HI LINE POWER 24 HRS) SUPV:DEARL W. GLADDEN Dir drilling 9486' to 10686'. Pump sweeps as needed to keep hole clean. 06/28/00 (D20) MW: 9.6 VISC: 48 PV/YP: 13/15 APIWL: 3.0 TD/TVD:l1034/4743 ( 348) R/U TO TEST BOPS ( TESTED CHOKE MANIFOLD WHILE POOH) (R SUPV:DEARL W. GLADDEN Dir drilling from 10636' to 11034'. Circ hole clean. Wiper trip. TOH. RECEIVED AU(; 1 6 000 Alaska Oil & Gas Cons. Commission Anchorage Date: 08/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 06/29/00 (D21) MW: 9.7 VISC: 47 PV/YP: 14/14 APIWL: 3.0 TD/TVD:l1034/4743 ( 0) P/U KELLY - WASH TO BTTM (RIG ON HI LINE POWER 24 HRS) SUPV:DEARL W. GLADDEN Monitor well for flow. Safety meeting. Test BOPs, 300/3500 psi. Service rig, repair loose brake pads. TIH. 06/30/00 (D22) MW: 9.7 VISC: 47 PV/YP: 12/14 APIWL: 2.8 TD/TVD:l1535/4976 ( 501) DIR DRLG @ 11650' (RIG ON HI LINE POWER 24 HRS) SUPV:DEARL W. GLADDEN TIH. Pump sweep. Dir drilling from 11034' to 11535' 07/01/00 (D23) MW: 9.7 VISC: 47 PV/YP: 15/15 APIWL: 3.0 TD/TVD:12020/5246 (485) TIH - COULD NOT VERIFY PROPER FILL SUPV:DEARL W. GLADDEN Dir drilling from 11535' to 12020'. Pump sweeps as needed. CBU, condition for wiper trip. TIH to bottom 12020', no fill. Pump hi vis sweep, spot lub mud on bottom. TOH. 07/02/00 (D24) MW: 9.6 VISC: 46 PV/YP: 11/10 APIWL: 3.0 TD/TVD:12026/5247 ( 6) RUN CSG - 5 1/2" X 3 1/2" MONO BORE SUPV:DEARL W. GLADDEN TOH. Monitor well, fill not correct, due to aerated mud from lube could not verify proper fill. TIH, no problems. CBU. TOH. PJSM. 07/03/00 (D25) MW: 9.6 VISC: 42 PV/YP: 11/ 9 APIWL: 3.0 TD/TVD:12026/5247 ( 0) CMT 5 1/2" X 3 1/2" MONO CSG SUPV:DEARL W. GLADDEN Install test plug, C/O top pipe rams to 5.5", test rams and doors to 300/3500. PJSM. Run 3.5" tubing. Run 5.5" casing. 07/04/00 (D26) MW: 8.5 VISC: 0. PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12026/5247 ( 0) RUNNING COMPLETION (OFF HI-LINE POWER @ 1800 HR SUPV:R.W. SPRINGER Run 5.5" casing. PJSM. Pump cement. Bump plug. Floats held. NU BOPE and test packoff. Rig up to run 3.5" completion. PJSM. 07/05/00 (D27) MW: 15.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12026/5247 ( 0) NIPPLE UP TREE. (RIG OFF HI-LINE POWER) SUPV:R.W. SPRINGER Run 3.5" tubing. Test casing to 3500 psi. Pump diesel down tubing and u-tube to annulus. Test tubing to 3500 psi, OK. PJSM. 07/06/00 (D28) TD/TVD:12026/5247 ( SUPV:R.W. SPRINGER MW: 0.0 VISC: 0 PV/YP: 0/ 0 0) RIG RELEASED MOVED TO 2N-316 APIWL: 0.0 PJSM. N/D BOPE. N/U tree and test. Release rig @ 0600 7/6/00 RECEIVED AUG 16 2000 AlaSka Oil & Gas Cons. Commission An~amge PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-332(W4-6)) WELL 2N-332 JOB SCOPE DRILLING SUPPORT-CAPITAL DATE DAILY WORK 07/12/00 PERFORATE - 2.5" HSD 35B UP RDX - BH DAY OPERATION COMPLETE I SUCCESSFUL 1 YES I YES InitialTbgPress IF,nalTbgPress [InitiallnnerAnn 200 PSI 0 PSi 50 PSI DAILY SUMMARY KEY PERSON SWS-STEPHENSON Final Inner Ann 0 PSI JOB NUMBER 0707001737.2 UNIT NUMBER SWS - 2145 SUPERVISOR JOHNS Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PERFORATE FROM 11600' - 11630' USING 2/5" HSD @ 4 SPF WITH BH CHARGES TIME LOG ENTRY 08:30 SWS MIRU - CALLED DSO - SAFETY MEETING 10:00 PT WELL TO 3K PSI - RIH 10:20 A LITTLE SLOW GOING IN AREAS OVER 74 DEGS, BUT CONTINUING TO FALL. 11:30 13:15 TOOL WILL NOT FALL BELOW 11615 FT CCL DEPTH (11648 FT AT BNOS). FINALLY WORKED THROUGH 11615 AREA, TOOL NOW AT 11835 FT CCL DEPTH, LOG TIE IN STRIP FOR SHOOT. 13:45 LOG DOWN COUNTING COLLARS 14:00 LOG UP INTO POSITION TO SHOOT - GOOD INDICATIONS OF DETONATION - PERFORATE FROM 11610'- 11630' 14:10 POOH 15:15 RIG DOWN GUN 1 - RIG UP GUN 2 15:30 RIH WITH SWIVEL - CCL - WGT - ROLLERS - SAFE - 10' 2.5" HSD WITH BH - ROLLERS 17:00 LOG TIE IN PASS OVER JEWELRY 17:15 AS RIH TO PERFED ZONE - CCL SIGNAL WEAKENED DUE TO DEBRIS 17:30 LOG INTO SHOOTING POSITION & PERFORATE FROM 11600'- 11610', NOTE PULLED TIGHTED AFTER SHOT 17:40 POOH 18:20 START RIG DOWN 19:00 COMPLETE RIG DOWN - LEAVE LOCATION 20:00 SPOT EQUIP ON 2A RECEIVED AUG 16 2000 AlaSka Oil a Gas Cons. Oommission Anchorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-332(W4-6)) WELL 2N-332 JOB SCOPE DRILLING SUPPORT-CAPITAL DATE DAILY WORK 07/16/00 FRACTURING DAY OPERATION COMPLETE I SUCCESSFUL 2 YES I YES Init,alTbgPress IFinalTbgPress IlnitiallnnerAnn 0 PSI 0 PSI 0 PSI DAILY SUMMARY KEY PERSON DS-GALLEGOS JOB NUMBER 0707001737.2 UNIT NUMBER SUPERVISOR FERGUSON Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSII 0 PSII 0 PSI PUMP 200 BBL BREAKDOWN OF 20# GEL AND PERFORM SDT. LOW XS FRICTION, ELIMINATE SCOUR STAGES. PERFORM DATAFRAC AND REVISE SCHEDULE TO 300 BBL PAD(FROM 200 BBLS) AND LENGTHEN 4 PPA FLAT TO 450 BBLS. PUMP 192,400 #'S 16/20 PROP AND PLACE 191,500 #'S BEHIND PIPE WITH 12 PPA ON FORMATION, LEAVING 900 #'S IN PIPE. PLACE 106% OF DESIGN.[Frac-Refrac] TIME LOG ENTRY 07:45 ARRIVE LOCATION, DOWELL RU PUMP EQUIPMENT 10:10 SAFETY MEETING 10:30 SET TREESAVER AND PT LINES TO 9000 PSI 11:00 START BREAKDOWN WITH 20# GEL AT 25 BPM, GOOD BREAKBACK, TREATING AT 30 BPM AND 5200 PSi WITH WELL LOADED WITH 20# 11:15 PERFORM SDT. ISIP=737, FG=0.6 PSI/FT, XS FRICTION=1087 PSI AT 30 BPM. EXCELLENT FORMATION TIE IN AND LOW FRICTION #'S. PLAN TO SKIP SCOUR STAGE AND CONSERVE FLUID. 11:30 START DATAFRAC WITH 200 BBLS 40# X/L GEL 11:38 CUT ACTIVATOR AND START FLUSH ON DF 11:45 SD FOR DF ANALYSIS 12:55 DF ANALYSIS: INCREASE PAD FROM 200 BBLS TO 300 BBLS DUE TO FASTER CLOSURE. TC=7.5 MIN, PC=800 PSI, EFF=37%, PNET=168 PSI, INCREASE 4 PPA FLAT STAGE TO 450 BBLS FROM 150 13:10 START FRAC 14:00 WELL TREATING SMOOTHELY, APPEAR TO BE GETTING GOOD EXTENSION AND STAYING IN ZONE. 14:20 WEL TREATING GOOD, ELECT TO GO LONG AND RAMP TO 12 PPA 14:30 GO TO FLUSH AND END UP CUTTING RATE TO FINAL 7 BPM. FLUSH WITH 95 BBLS. 14:40 SD FLUSH COMPLETE 15:00 PLACE 191,400 #'S BEHIND PIPE AND LEFT 900 #'S IN TUBING. MAX CONC OF 12 PPA ON FORMATION. 17:30 RDMO RECEIVED AU(; 1 6 2000 Alaska 0ii & Gas Cons. Commission Anchorage 18-Jul-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-332 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,208.65' MD 6,234.76' MD 12,026.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) AU(; 0 1 -000 Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska Alaska State Plane 4 Kuparuk 2N 2N-332 'ORIGINAL SURVEY REPORT 18 July, 2000 Your Ref: API-5010320340000 Surface Coordinates: 5911909.47 N, 460669.29 E (70° 10' 12.9852" N, 209° 41' 00.4705" E) Kelly Bushing: 153. lOft above Mean Sea Level DI~R~ !- ~1 N {~ sBRvIIZBI~ A Halliburton Company RECEIVED AUG 01 2000 Alaska Oil & Gas Cons. Commission Anchorage Survey Reh svy9263 Sperry-Sun Drilling Services Survey Report for 2N-332 Your Ref: API-5010320340000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) 6208.65 73.390 285,270 2865.85 6234.76 73.210 285.840 2873.35 6260.86 71,240 285.980 2881.32 6283.63 70.200 283.900 2888.84 6315.12 69.390 284.200 2899.72 6345.56 68.440 284.690 2910.67 6377.49 67.250 285.690 2922.71 6409.20 66,380 284,150 2935.19 6440.66 66.720 284,490 2947.71 6472.43 66.200 284,860 2960.40 6504.46 67.220 285,730 2973.06 6536.24 69,400 286,440 2984.81 6567.98 68,680 286,650 2996.16 6599.73 69.570 286.780 3007.48 6629.76 69.460 286,650 3017.99 6661.46 70.830 286.300 3028.75 6693.20 70.170 286.030 3039.35 6725.14 71,830 285.910 3049.75 6756.99 71.410 286.190 3059.79 6788.96 70.000 286.100 3070.35 6820.51 71.750 283.960 3080.69 6852.38 71.270 283.640 3090.80 6884.07 72.810 282.280 3100.57 6915.00 73.020 281.960 3109.66 6946.65 72.430 281.900 3119.05 Vertical Local Coordinates Depth Northings . Eastings (ft) (fi) (ft) 3018.95 1108.29 N 4686.69W 3026.45 1114.99 N 4710.78W 3034.42 1121.81N 4734.69W 3041.94 1127.35 N 4755.45W 3052.82 1134.52 N 4784.12W 3063.77 1141.61N 4811.62W 3075.81 1149.36N 4840.16W 3088.29 1156.86 N 4868,32W 3100.81 1164.00 N 4896.29W 3113.50 1171.38 N 4924.47W 3126.16 1179.14 N 4952.84W 3137.91 1187.32N 4981.21W 3149.26 1195.76 N 5009.63W 3160.58 1204.29 N 5038.04W 3171.09 1212.39 N 5064.98W 3181.85 1220.84 N 5093.57W 3192,45 1229.17 N 5122.31W 3202.85 1237.48 N 5151.34W 3212.89 1245.84 N 5180.39W 3223.45 1254.23N 5209.37W 3233.79 1261.95 N 5238.16W 3243.90 1269.16 N 5267.51W 3253.67 1275.92N 5296.89W 3262.76 1282.13 N 5325.79W 3272.15 1288.38 N 5355.36W Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°llOOff) 5913041.99 N 455988.88 E 5913048.82 N 455964.83 E 2.20 5913055.76 N 455940.96 E 7.57 5913061.41 N 455920.23 E 9.76 5913068.73 N 455891.60 E 2.72 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 4815.95 Tie-on Suwey 4840.94 Window Point 4865.77 4887.25 4916.80 5913075.95 N 455864.14 E 3.46 4945.20 5913083.85 N 455835.64E 4.72 4974.75 5913091.50 N 455807.52E 5.24 5003.89 5913098.78 N 455779.60 E 1.47 5032.75 5913106,31 N 455751.46 E 1.95 5061.87 5913114,22 N 455723.13 E 4.05 5091.27 5913122.54 N 455694.80 E 7.17 5120.76 5913131.13 N 455666.44 E 2.35 5150.36 5913139.81 N 455638.07E 2.83 5179.97 5913148.04 N 455611.18 E 0.55 5208.05 5913156.64 N 455582.63 E 4.44 5237.82 5913165.12 N 455553.94 E 2.23 5267.71 5913173.58 N 455524.96 E 5.21 5297.88 5913182.09 N 455495.95 E 1.56 5328.07 5913190.63 N 455467.02E 4.42 5358.20 5913198.50 N 455438.28 E 8.48 5388.00 5913205.86 N 455408.96 E 1.78 5418.22 5913212.77N 455379.63 E 6.35 5448.36 5913219.13 N 455350.76 E 1.20 5477.92 5913225.53 N 455321.22 E 1.87 5508.14 RECEIVED AUG 0 1 000 AJaska 0ii & Gas Cu;=~. Cm-.missiu~ Anchorage Continued... 18 July, 2000 - 11:31 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-332 Your Ref: API-5010320340000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (fi) (ft) (ft) fit) (ft) (ft) 6978.49 71,090 281.280 3129.02 7009.77 69.870 281.290 3139.47 7041.23 69.400 281.540 3150.42 7072.65 69,050 282.040 3161.56 7103.35 69,190 283.210 3172.51 7135.09 68.630 283.290 3183.93 7167.34 69.850 283.130 3195.36 7199.29 69.770 283.970 3206.39 7230.98 71.300 283.890 3216.95 7263.40 71.520 283.680 3227.28 7293.72 71.490 284,160 3236.90 7325.07 71.030 283.710 3246.97 7357.02 70.720 283.850 3257.44 7388.65 70.310 283.650 3267.99 7420.24 69.740 283.630 3278.78 7452.25 69.270 282.860 3289.99 7484.18 69.130 282,140 3301.33 7514.83 71.510 282.890 3311.65 7546.72 71.420 282.590 3321.79 7578.69 70.410 281.850 3332.24 7610.21 69,940 282.250 3342.93 7641.95 69.550 281.190 3353.92 7673.73 68.810 281.350 3365.21 7704.65 67.460 281.430 3376.73 7735.42 67.640 281,720 3388.48 3282.12 1294.45 N 5384.98W 3292.57 1300.22 N 5413.90W 3303.52 1306.06 N 5442.81W 3314.66 1312.06 N 5471.56W 3325.61 1318.33 N 5499.55W 3337.03 1325.12 N 5528.38W 3348.46 1332.01 N 5557.74W 3359.49 1339.03N 5586.89W 3370.05 1346.23 N 5615.89W 3380.38 1353.55 N 5645.73W 3390.00 1360.47N 5673.64W 3400.07 1367.61 N 5702.45W 3410.54 1374.80 N 5731.77W 3421.09 1381.89 N 5760.74W 3431.88 1388.89 N 5789.59W 3443.09 1395.76 N 5818.77W 3454.43 1402.22 N 5847.92W 3464.75 1408.48 N 5876.09W 3474.89 1415.15 N 5905.58W 3485.34 1421.54 N 5935.11W 3496.03 1427.73 N 5964.10W 3507.02 1433.78N 5993.26W 3518.31 1439.59 N 6022.39W 3529.83 1445.25 N 6050.52W 3541.58 1450.96 N 6078.38W 5913231.76 N 455291.63 E 5913237.68N 455262.76 E 5913243.67N 455233.88 E 5913249.82 N 455205.16 E 5913256.23 N 455177.20 E 5913263.17 N 455148.41 E 5913270.21 N 455119.10 E 5913277.39 N 455089.98 E 5913284.73 N 455061.03 E 5913292.20 N 455031.22 E 5913299.27N 455003.35 E 5913306.56 N 454974.58 E 5913313.91N 454945.30 E 5913321.14 N 454916.38 E 5913328.29 N 454887.57 E 5913335.31 N 454858.42 E 5913341.93 N 454829.32 E 5913348.33 N 454801.18 E 5913355.15 N 454771.73 E 5913361.69 N 454742.24 E 5913368.04 N 454713.27 E 5913374.23 N 454684.15 E 5913380.19 N 454655.05 E 5913386.00 N 454626.96 E 5913391.85 N 454599.13 E Dogleg Rate (°llOOff) 4.60 3.90 1.67 1.86 3.59 1.78 3.81 2.48 4.83 0.92 1.50 2.00 1.05 1.43 1.81 2.69 2.15 8.10 0.94 3.84 1.91 3.37 2.38 4.37 1.05 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 5538.36 5567.82 5597.30 5626.67 5655.35 5684.96 5715.12 5745.1o 5774.98 5805.71 5834.46 5864.14 5894.33 5924.15 5953.84 5983.82 6o13.67 6042.52 6o72.75 6102.96 6132.60 6162.37 6192.o5 6220.73 6249.16 RECEIVED 0 1 00( Continued... 18 July, 2000 - 11:31 -3- Naska 0ii & {~as Co,-,,. ¢0m,~i=si0n DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-332 Your Ref: APi-5010320340000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (~t) 7766.48 66.690 281.740 3400.53 7799.41 65.460 282.040 3413.89 7830.17 66.180 282.370 3426.49 7862.28 65.780 283.230 3439,56 7893.47 66.440 283.740 3452.19 7924.50 66.170 284.190 3464.66 7956.22 68.340 284.760 3476.92 7988.51 68.510 285.020 3488.79 8020.15 68.700 285.980 3500.34 8052.04 68.370 285.730 3512.01 8084.17 70.080 286.180 3523.40 8114.69 70.340 285.580 3533.74 8146.41 73.560 285.800 3543.56 8178.16 74.140 285.310 3552.39 - 8209.68 73.770 285.460 3561.11 8241.62 73.600 285.400 3570.08 8272.90 73.490 284.650 3578.94 8304.50 73.310 284.680 3587.97 8336.43 73.040 284.260 3597.21 8368.46 73.300 283.760 3606.48 8400.02 73.570 284.580 3615.48 8431.56 73.490 284.890 3624.42 8463.24 73.650 283.720 3633.38 8494.09 72.190 283.370 3642.44 8526.08 72.010 283.910 3652.28 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (fi) 3553.63 1456.78 N 6106.41W 3566.99 1462.98 N 6135.86W 3579.59 1468.91N 6163.29W 3592.66 1475.41 N 6191.89W 3605.29 1482.06 N 6219.62W 3617.76 1488.92 N 6247.20W 3630.02 1496.23 N 6275.52W 3641.89 1503.95 N 6304.54W 3653.44 1511.82 N 6332.92W 3665.11 1519.93 N 6361.47W 3676.50 1528.19 N 6390.36W 3686.84 1536.04N 6417.98W 3696.66 1544.20 N 6447.01W 3705.49 1552.38 N 6476.39W 3714.21 1560.41N 6505.59W 3723.18 1568.57 N 6535.14W 3732.04 1576.35 N 6564.12W 3741.07 1584.01N 6593.41W 3750.31 1591.65 N 6623.01W 3759.58 1599.07N 6652.75W 3768.58 1606.48 N 6682.08W . 3777.52 1614.17 N 6711.33W 3786.48 1621.68 N 6740.78W 3795.54 1628.58 N 6769.45W 3805.38 1635.76N 6799.03W Alaska State Plane 4 Kuparuk 2N 5913397.82N 454571.13 E 5913404.17 N 454541.72 E 5913410.25 N 454514.32E 5913416.89 N 454485.76 E 5913423.68 N 454458.07E 5913430.68 N 454430.53 E 5913438.14 N 454402.25 E 5913446.01N 454373.27E 5913454.03N 454344.93 E 5913462.28 N 454318.43 E Dogleg Rate (°llOOft) 3.06 3.83 2.54 2.75 2.59 1.59 7.04 0.92 2.89 1.27 5913470.69 N 454287.59 E 5.48 5913478.69 N 454260.01 E 2.04 5913487.00 N 454231.03E 10.17 5913495.33 N 454201.69 E 2.35 5913503.51 N 454172.53 E 1.26 5913511.82 N 454143.03 E 5913519.75 N 454114.10 E 5913527.57N 454084.84 E 5913535.36 N 454055.29 E 5913542.93 N 454025.59 E 5913550.49 N 453996.30 E 5913558.33 N 453967.09 E 5913565.99 N 453937.69 E 5913573.05 N 453909.06 E 5913580.38 N 453879.52 E 0.56 2.33 0.58 1.52 1.70 2.63 0.98 3.58 4.86 1.70 Vertical Section Comment 6277.77 6307.86 6335.91 6365.24 6393.76 6422.17 6451.42 6481.43 6510.87 6540.52 6570.53 6599.22 6629.35 6659.83 6690.1o 6720.73 6750.72 6780.99 6811.55 6842.21 6872.45 6902.69 6933.07 6962.56 6993.00 RECEIVED ]a,,Jgl,~gl, ~'li ~ uo~ ~ .................. Anchorage Continued... 18 July, 2000.11:31 -4 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-332 Your Ref: AP1-5010320340000 North Slope Alaska Measured Depth (fi) 8557.94 8589.40 8621.06 8652.69 8684.49 8716.61 8778.79 8842.04 8905.21 8968.27 9031.15 9094.09 9157.40 9219.75 9283.83 9347.10 9409.84 9473.13 9536.40 9599.71 9631.50 9693.99 9756.90 9820.87 9884.47 Incl. 72.200 72,510 72.280 72.370 71.130 71.050 70.720 69.920 69.080 68.290 67.300 66.110 65.870 66.340 66.010 67.060 72.100 71.180 71.000 71.140 69.870 67.980 67.670 67.670 67.770 Azim. 284.240 284.610 284.100 283.670 283.260 283.220 282.430 281.710 282.310 281.520 281.050 283.000 283.310 283.900 284.900 286.020 286.850 286.900 285.960 286.320 286.050 285.500 284.230 283.660 284.270 Sub-Sea Depth (fi) 3662.07 3671.60 3681.18 3690.78 3700.74 3711.15 3731.51 3752.81 3774.94 3797.86 3821.62 3846.51 3872.27 3897.53 3923.41 3948.61 3970.49 3990.43 4010.93 4031.47 4O42.O8 4064.55 4088.29 4112.60 4136.71 VertiCal Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (fi) (ft) (ft) (ft) 3815.17 1643.14 N 6828.44W 5913587.91 N 453850.16 E 3824.70 1650.60 N 6857.47W 5913595.52 N 453821.16 E 3834.28 1658.09 N 6886.71W 5913603.16 N 453791.97 E 3843.88 1665.32 N 6915.96W 5913610.54 N 453762.75 E 3853.84 1672.35 N 6945.33W 5913617.72N 453733.42 E 3864.25 1679.31 N 6974.91W 5913624.84 N 453703.89 E 3884.61 1692.35 N 7032.20W 5913638.17 N 453646.67 E 3905.91 1704.81N 7090.43W 5913650.93 N 453588.51 E 3928.04 1717.12 N 7148.31W 5913663.54 N 453530.70 E 3950.96 1729.25 N 7205.79W 5913675.97N 453473.29 E 3974.72 1740.64N 7262.88W 5913687.66 N 453416.27E 3999.61 1752.68 N 7319.41W 5913699.99 N 453359.80 E 4025.37 1765.84 N 7375.73W 5913713.44N 453303.56 E 4050.63 1779.25 N 7431.13W 5913727.14 N 453248.23 E 4076.51 1793.83 N 7487.91W 5913742.01 N 453191.54 E 4101.71 1809.30 N 7543.85W 5913757.77 N 453135.69 E 4123.59 1825.94 N 7600.22W 5913774.70 N 453079.41 E 4143.53 1843.37N 7657.70W 5913792.43N 453022.02 E 4164.03 1860.30 N 7715.11W 5913809.66 N 452964.71 E 4184.57 1876.95 N 7772.64W 5913826.60 N 452907.28 E 4195.18 1885.30 N 7801.42W 5913835.10 N 452878.54 E 4217.65 1901.16 N 7857.53W 5913851.24N 452822.52 E 4241.39 1916.10 N 7913.83W 5913866.48 N 452766.30 E 4265.70 1930.36 N 7971.26W 5913881.04N 452708.95 E 4289.81 1944.56 N 8028.37W 5913895.54 N 452651.92 E Dogleg Rate (°ll00ft) 1.15 1.49 1.70 1.33 4.09 0.28 1.31 1.66 1.60 1.71 1.72 3.42 0.59 1.15 1.52 2.32 8.13 1.46 1.43 0.58 4.07 3.13 1.93 0.82 0.90 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 7023.32 7053.29 7083.47 7113.60 7143.80 7174.19 7232.94 7292.48 7351.63 7410.35 7468.53 7526.32 7584.15 7641.16 7699.77 7757.76 7816.46 7876.41 7936.18 7995.99 8025.92 8084.18 8142.41 8201.58 8260.43 RECEIVED AUG 01 200 Continued... 18 July, 2000 - 11:31 -5- Alaska 0ii & Gas CoNs. Commission Anchoraqe DriliQuest 2. 00. 02 Sperry-Sun Drilling Services Survey Report for 2N-332 Your Ref: API-5010320340000 North Slope Alaska Measured Depth (fi) 9947.67 10010.51 10073,76 10137.51 10200,10 Incl. 68.380 70.330 71.070 69.360 69.190 10263.01 10326.74 10389.06 10452.32 10515.69 68.290 67.340 66.150 65.120 63.830 10578.71 10640.69 10705.60 1O768.63 10831.90 65.000 64.040 64.110 65.840 65.700 10895.58 10958.97 11021.65 11086.50 11150.18 65.670 65.810 63.67O 63.780 65.090 11213.98 11277.75 11341.38 11374.43 11406.33 64.320 62.780 60.890 61.890 61.550 Azim. 285.110 285.280 284.100 283.640 282.770 282.850 282.000 282.880 281.450 280.670 279.38O 278,720 279.310 280.39O 279.800 279.5OO 279.330 282.230 282.300 283.060 283,510 283.290 282.500 282.010 282.260 Sub-Sea Depth (~t) 4160,31 4182,47 4203,37 4224.95 4247.10 4269.91 4293.98 4318.58 4344.68 4371.99 4399.20 4425.86 4454.24 4480.91 4506.87 4533.09 4559.14 4585.89 4614.60 4642.08 4669.34 4697.74 4727.77 4743.60 4758.71 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (fi) (ft) (fi) (ft) 4313.41 1959.43 N 8085.08W 4335.57 1974.84 N 8141.83W 4356.47 1989.98 N 8199.57W 4378.05 2004.36 N 8257.81W 4400.20 2017.73 N 8314.80W 4423.01 2030.73N 8371.97W 4447.08 2043.43N 8429.60W 4471.68 2055.76 N 8485.51W 4497.78 2067.91N 8541.84W 4525.09 2078.88 N 8597.96W 4552.30 2088.77N 8653.93W 4578.96 2097.57N 8709.18W 4607.34 2106.72 N 8766.84W 4634.01 2116.50 N 8823.10W 4659.97 2126.61 N 8879.91W 4686,19 2136.34N 8937.12W 4712.24 2145.79 N 8994.13W 4738.99 2156.38 N 9049.81W 4767.70 2168.73 N 9106.63W 4795.18 2181.34N 9162.67W 4822.44 2194.60 N 9218.81W 4850.84 2207.83 N 9274.35W 4880.87 2220,35 N 9329.03W 4896.70 2226.51 N 9357.38W 4911.81 2232.41N 9384.84W 5913910.70 N 452595.29 E 5913926.40 N 452538.63 E 5913941.84N 452480.97 E 5913956.52 N 452422.82 E 5913970.19 N 452365.91 E 5913983.48 N 452308.81 E 5913996.48 N 452251.25 E 5914009.10 N 452195.41 E 5914021.54 N 452139.15 E 5914032.80 N 452083.10 E 5914042.98 N 452027.18 E 5914052.07N 451971,98 E 5914061.51N 451914.38 E 5914071.58 N 451858.17 E 5914081.98 N 451801.43 E 5914092.01N 451744.27E 5914101.76 N 451687.32 E 5914112.63 N 451631.70 E 5914125.28 N 451574.95 E 5914138.18 N 451518.98 E 5914151.73N 451462.91 E 5914165.25 N 451407.45 E 5914178.05 N 451352.84 E 5914184.35 N 451324.53 E 5914190.40 N 451297.09 E Dogleg Rate (°/100ft) 1.57 3.11 2.11 2.77 1.33 1.44 1.94 2.31 2.63 2.32 2.62 1.82 0.82 3.15 0.88 0,43 o.33 5,4o 0.20 2.32 1.37 2.43 3.17 3.29 1.27 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 8319.04 8377.82 8437.49 8497.48 8556.01 8614.64 8673.64 8730.89 8788.50 8845.64 8902.38 8958.17 9016.38 9073.38 9130,99 9188.90 9246.55 9303.17 9361.31 9418.75 9476.43 9533.52 9589.61 9618.62 9646.71 RECEIVED AU(; 0 1 200(' Continued... 18July, 2000- 11:31 -6- Alaska 0il & Gas Cows. Commission Anchoraqe DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-332 Your Ref: API-5010320340000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (~t) (~t) (fi) (~t) (ft) 11438.40 61.010 283.430 4774.12 4927.22 2238.66 N 9412.26W 11470.46 59.810 282.660 4789.95 4943.05 2244.96 N 9439.42W 11509.34 59.530 283.230 4809.59 4962.69 2252.48 N 9472.13W 11534.44 59.210 283.350 4822.38 4975.48 2257.44N 9493.15W 11566.57 59.300 284.380 4838.80 4991.90 2264.06 N 9519.96W Global Coordinates Northings Eastings (~t) (~t) 5914196.80 N 451269.71 5914203.23 N 451242.59 5914210.92 N 451209.92 5914215.99 N 451188.93 5914222.75 N 451162.16 11598.78 59.040 283.900 4855.31 5008.41 2270.81 N 9546.78W 11630.62 58.490 284.620 4871.82 5024.92 2277.52 N 9573.16W 11662.68 58.480 283.920 4888.58 5041.68 2284.26 N 9599.65W 11726.30 57.830 284.700 4922.15 5075.25 2297.61 N 9652.02W 11790.39 56.330 284.650 4956.98 5110.08 2311.24 N 9704.06W 5914229.64N 451135.38 5914236.48 N 451109.03 5914243.36 N 451082.58 5914256.98 N 451030.29 5914270.88 N 450978.33 11854.48 54.580 283.380 4993.32 5146.42 2324.03 N 9755.27W 11943.14 52.270 282.530 5046.14 5199.24 2340.00 N 9824.65W 12026.00 52.270 282.530 5096.85 5249.95 - 2354.22 N 9888.63W 5914283.94 N 450927.18 5914300.26 N 450857.89 5914314.81 N 450794.00 Dogleg Rate (°/lOOff) All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well, The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 283.360° '(True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12026.00ft., The Bottom Hole Displacement is 10165.00ft., in the Direction of 283.391° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. 3.62 4.29 1.46 1.34 2.77 1.51 2.59 1.86 1.46 2.34 E 3.18 E 2.72 E 0.00 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 9674.83 97o2.71 9736.27 9757.86 9785.48 9813.13 984O.35 9867.68 9921.72 9975.5O 10028.28 10099.47 10165.00 Projected Survey RECEIVED AUu 01 Continued... 18 July, 2000 - 11:31 - 7'- N._a.s_ka. O..j! & Gas Cons. ¢0m_m_is_sl.o.n ~;h0rago DrillQuest 2.00. 02 Sperry-Sun Drilling Services Survey Report for 2N.332 Your Ref: AP1-5010320340000 North Slope Alaska Alaska State Plane 4 Kuparuk 2N Comments Measured Depth (fi) Station Coordinates TVD Northings Eastings (ft) (fi) (ft) 6208.65 3018.95 1108.29 N 4686.69W 6234.76 3026.45 1114.99 N 4710.78W 12026.00 5249.95 2354.22 N 9888.63W Comment Tie-on Survey Window Point Projected Survey Survey tool program From To Measured Vertical Measured Vertical Depth Depth Depth Depth (fi) (fi) (ft) (ft) 0.00 0.00 12026.00 5249.95 Survey Tool Description MWD Magnetic RECEIVED /~UG 01 2000 18 July, 2000-11:31 -8- Nas_~ ~.il & 6as Cons. ~ho. rage .o - DrillQuest 2. 00. 02 18-Jul-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-332 PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 8,684.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) AU6 0 1 200C Alaska Oil & Eias Cons. North Slope Alaska Alaska State Plane 4 Kuparuk 2N 2N-332 PB1 ORIGINAL SURVEY REPORT 18 July, 2000 Your Ref: API.5010320340070 Surface Coordinates: 5911909.47 N, 460669.29 E (70° 10' 12.9852" N, 209° 41' 00.4705" E) Kelly Bushing: 153.10fl above Mean Sea Level A HIIIIburton Company RECEIVED AUG 0 1 2000 Alaska Oil & G.?,.s Co;s Co.mmiSSlOr. Survey Ref: svy9262 Sperry-Sun Drilling Services Survey Report for 2N-332 PB1 Your Ref: API-5010320340070 North Slope Alaska Measured Depth (~t) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (~t) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -153.10 115.00 0.000 0.000 -38.10 153.35 0.860 271.370 0.25 240.79 1.440 269.820 87.67 329.31 2.410 269.690 176.14 418.75 3.930 276.060 510.45 7.240 280.200 600.97 11.210 277.390 690.69 14.240 279.540 783.60 18.840 274.950 874.30 20.470 273.440 966.02 23.020 273.270 1064.90 26.470 272.530 1159.59 28.530 274.480 1256.17 31.800 274.010 265.44 356.69 446.02 533.53 622.58 707.99 793.18 882.96 966.95 1050.44 1352.54 35.960 278.860 1130.45 1447.59 39.740 282.070 1205.49 1542.49 45.960 282.910 1275.03 1637.40 50.860 283.280 1338.02 1733.45 56.490 285.350 1394.89 1821.19 60.970 286.730 1914.77 65.440 286.420 2009.30 64.890 284.160 2104.57 66.330 285.010 2199.01 67.650 284.580 1440.43 1482.60 1522.31 1561.65 1598.57 0.00 0.00 N 0.00 E 115.00 0.00 N 0.00 E 153.35 0.01 N 0.29 W 240.77 0.02 N 2.04 W 329.24 0.01 N 5.02 W 418.54 0.32N 9.94W 509.79 1.67 N 18.76W 599.12 3.82 N 33.10W 686.63 6.77N 52.64W 775.68 9.96 N 78.87W 861.09 12.17 N 109.29W 946.28 14.16 N 143.21W 1036.06 16.24N 184.54W 1120.05 18.93 N 228.17W 1203.54 22.52 N 276.57W 1283.55 28.65 N 329.89W 1358.59 39.31 N 387.20W 1428.13 53.29 N 450.17W 1491.12 69.37N 519.29W 1547.99 88.55 N 594.22W 1593.53 109.28 N 666.27W 1635.70 133.10 N 746.31W 1675.41 155.73 N 829.05W 1714.75 177.58 N 913.02W 1751.67 199.77N 997.06W 5911909.47N 460669.29 5911909.47N 460669.29 5911909.48 N 460669.00 5911909.50 N 460667.25 5911909.50 N 460664.27 5911909.84 N 460659.35 5911911.24N 460650.54 5911913.46 N 460636.21 5911916.51N 460616.69 5911919.84 N 460590.48 5911922.21 N 460560.07 5911924.37N 460526.17 5911926.66 N 460484.85 5911929.59 N 460441.24 5911933.42N 460392.87 5911939.83 N 460339.59 5911950~9 N 460282.34 5911965.09 N 460219.45 5911981.53 N 460150.42 5912001.10 N 460075.60 5912022.20N 460003.67 5912046.44N 459923.76 5912069.49 N 459841.14 5912091.77N 459757.30 5912114.40 N 459673.38 Dogleg Rate (°ilOOft) Alaska State Plane 4 Kuparuk 2N Vertical Section Comment E 0.00 E 0.00 0.00 E 2.24 0.28 E 0.66 1.99 E 1.10 4.88 E 1.74 9.75 E 3.63 18.64 E 4.41 33.09 E 3.42 52.78 E 5.14 79.04 E 1.88 E 2.78 E 3.5O E 2.37 E 3.39 E 5.15 E 4.48 E 6.58 E 5.17 E 6.11 E 5.28 E 4.79 E 2.25 E 1.72 E 1.46 109.15 142.61 183.30 226.37 274.28 327.58 385.80 450.30 521.26 598.60 673.49 756.87 842.60 929.34 1016.24 RECEIVED AUG 0 1 OOC Continued... 18 July, 2000 - 11:13 -2- .Alaska 0ii & Ga.s Cons. Commissior., Anchorage DrillQuest2.00.02 Sperry-Sun Drilling Services Survey Report for 2N.332 PB1 Your Ref: API.5010320340070 North Slope Alaska Measured Depth (fi) Incl. Azim. 2293.84 69.250 285.420 2389.18 69.520 286.500 2490.55 69.200 284.330 2585.81 71.140 283.710 2679.60 71.750 283.980 Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 1633.40 1786.50 222.60 N 1082.25W 1666.97 1820.07 247.14 N 1168.05W 1702.70 1855.80 272.36 N 1259.49W 1735.02 1888.12 294.06 N 1346.43W 1764.86 1917.96 315.34 N 1432.76W 2774.34 71.510 284.150 1794.72 2869.19 70.760 284.120 1825.39 2963.54 70.870 284.870 1856.39 3051.91 71.010 286.130 1885.25 3146.65 70.890 285.720 1916.17 3241.50 71.530 285.260 1946.73 3335.95 71.460 286,570 1976.70 3431.20 71.180 287.010 2007.21 3526.07 71.440 284.980 2037.61 3620.02 72.100 281.920 2067.01 3715.19 71.740 281.330 2096.55 3809.80 71.540 280.780 2126.35 3843.14 71.450 279.740 2136.93 3931.93 70.160 276.520 2166.13 4027,19 68.410 278.530 2199.83 4129.53 72.330 280.850 2234.20 4217,80 75.640 283.500 2258.56 4311.47 73.890 283.030 2283.17 4407.04 71.630 281.670 2311.50 4502.13 70.480 282.870 2342.37 1947.82 337.19 N 1519.98W 1978.49 359.11N 1607.01W 2009.49 381.41N 1693.28W 2038.35 403.73 N 1773.77W 2069.27 428.30 N 1859.88W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°llOOft) 5912137.67 N 459588.32 5912162.65 N 459502.66 5912188.34N 459411.36 5912210.50 N 459324.54 5912232.22 N 459238.33 5912254.52 N 459151.24 5912276.89 N 459064.32 5912299.64 N 458978.18 5912322.38 N 458897.82 5912347.39 N 458811.84 2099.83 452.29 N 1946,42W 5912371.82 N 458725.44 2129.80 476.84 N 2032.55W 5912396.82 N 458639.45 2160.31 502.91N 2118,93W 5912423.33 N 458553.21 2190.71 527.67 N 2205.32W 5912448.54 N 458466.96 2220.11 548.42 N 2292,09W 5912469.74 N 458380.30 2249.65 566.65 N 2380.71W 5912488.43 N 458291.79 2279.45 583.87 N 2468.83W 5912506.10 N 458203.77 2290.03 589.50 N 2499,94W 5912511.89 N 458172.69 2319.23 601.36 N 2582,94W 5912524.19 N 458089.77 2352.93 613.02 N 2671.26W 5912536.30 N 458001.51 2387.30 629.27 N 2766.25W 2411.66 647.17 N 2849.16W 2436.27 667.91N 2937.13W 2464.60 687.44 N 3026.28W 2495.47 706.55 N 3114.16W 5912553.04N 457906.62 5912571.37N 457823.81 5912592.57N 457735.96 5912612.56 N 457646.92 5912632.12 N 457559.15 1.88 1.10 2.03 2.13 0.71 0.31 0.79 0.76 1.36 0.43 0.82 1.32 0.53 2.05 3.17 0.70 0.59 2.97 3.72 2.70 E 4.39 E 4.73 E 1.93 E 2.73 E 1.70 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 1104.40 1193.54 1288.34 1377.94 1466.85 1556.75 1646.50 1735.59 1819.06 19o8.52 1998.25 2087.73 2177.80 2267.56 2356.78 2447.21 2536.93 2568.50 2651.99 2740.62 2836.79 2921.6o 3011.97 3103.23 3193.15 RECEIVED AUG 0 1 Continued... 18 July, 2000- 11:13 -3- Alaska Oil & G~s Cons. Con~missior Anchorage DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-332 PB1 Your Ref: API-5010320340070 North Slope Alaska Measured Depth (~t) Incl. Azim. Sub-Sea Depth (ft) 4596.86 70.570 283.680 2373.95 4694.06 73.180 286.330 2404.19 4787.11 73.450 286.730 2430.91 4881.23 73.260 286.280 2457.87 4976.50 73.270 285.640 2485.30 5071.53 72.530 286.010 2513.24 5166.01 69.710 284.420 2543.81 5260.38 71.400 283.040 2575.23 5355.02 74.600 283.010 2602.90 5449.76 74.540 283.180 2628.10 5545.05 72.930 284.430 2654.79 5640.36 71.450 282.310 2683.95 5734.98 72.590 280.580 2713.15 5829.52 72.360 281.710 2741.62 5924.64 71.320 284.420 2771.27 6019.82 69.550 286.730 2803.15 6113.44 69.720 285.440 2835.73 6208.65 73.390 285.270 2865.85 6303.08 76.860 284.870 2890.09 6398.14 79.500 285.070 2909.56 6493.33 77.880 285.200 2928.23 6587.98 76.070 282.510 2949.56 6682.75 72.720 281.780 2975.05 6777.13 68.780 281.270 3006.16 6872.53 71.550 282.370 3038.53 Vertical Local Coordinates Depth Northings Eastings (fi) (ft) (fi) 2527.05 727.05 N 3201.09W 2557.29 750.98 N 3290.29W 2584.01 776.34 N 3375.74W 2610.97 801.96 N 3462.20W 2638.40 827.05 N 3549.92W 2666.34 851.81N 3637.30W 2696.91 875.28 N 3723.55W 2728.33 896.40 N 3809.99W 2756.00 916.79 N 3898.16W 2781.20 937.48 N 3987.11W 2807.89 959.31N 4075.94W 2837.05 980.29 N 4164.21W 2866.25 998.15 N 4252.41W 2894.72 1015.57N 4340.86W 2924.37 1035.99 N 4428.90W 2956.25 1060.06 N 4515.28W 2988.83 1084.38 N 4599.61W 3018.95 1108.29 N 4686.69W 3043.19 1132.01N 4774.81W 3062.66 1156.04N 4864.68W 3081.33 1180.41N 4954.78W 3102.66 1202.50 N 5044.30W 3128.15 1221.71 N 5133.52W 3159.26 1239.51N 5220.81W 3191.63 1257.90 N 5308.63W Global Coordinates Northings Eastings (~t) (ft) 5912653.08 N 457472.34E 5912677.47N 457383.27E 5912703.27 N 457297.96 E 5912729.33N 457211.64 E 5912754.87N 457124.07 E 5912780.09 N 457036.82 E 5912804.00 N 456950.70 E 5912825.57 N 456864.38 E 5912846.42 N 456776.33 E 5912867.57 N 456687.50 E Dogleg Rate (°/lOOft) 0.81 3.73 0.50 0.50 0.64 0.86 3.38 2.26 3.38 0.18 5912889.85 N 456598.79 E 2.11 5912911.29 N 456510.64E 2.63 5912929.60 N 456422.54 E 2.12 5912947.48 N 456334.19 E 1.17 5912968.36 N 456246.27 E 2.92 5912992.88 N 456160.02 E 5913017.63 N 456075.83 E 5913041.99 N 455988.88 E 5913066.17 N 455900.90 E 5913090.66 N 455811.16 E 5913115.50 N 455721.19 E 5913138.05 N 455631.80 E 5913157.72N 455542.69 E 5913175.97 N 455455.51 E 5913194.81N 455367.79 E 2.95 1.30 3.86 3.70 2.78 1.71 3.36 3.61 4.21 3.10 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 3282.46 3374.78 3463.77 3553.81 3644.95 3735.70 3825.03 3914.01 4004.50 4095.83 4187.30 4278.03 4367.97 4458.06 4548.43 4638.o3 4725.70 4815.95 4907.16 5000.16 5093.45 5185.65 5276.89 5365.93 5455.63 RECEIVED AUG 0 1 200 Continued... 18 July, 2000 - 11:13 -4- Alaska Oil & G~.,s Cons. Co~,amissior Anchorage DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 2N-332 PB1 Your Ref: API-5010320340070 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (fi) (ft) (fi) (ft) (ft) 6966.59 75.070 283.430 3065.54 3218.64 1278.02 N 5396.44 W 7061.47 79.070 282.750 3086.77 3239.87 1298.95 N 5486.49 W 7156.23 79.610 282.720 3104.29 3257.39 1319.48 N 5577.33 W 7250.24 77.980 279.900 3122.56 3275.66. 1337.57 N 5667.74 W 7345.16 76.750 277.610 3143.33 3296.43 1351.67 N 5759.27 W 7440.25 74.160 275.450 3167.21 3320.31 1362.15 N 5850.70 W 7535.75 71.290 273.380 3195.57 3348.67 1369.18 N 5941.61 W 7629.94 69.370 269.140 3227.29 3380.39 1371.15 N 6030.25 W 7724.80 72.440 270.440 3258.32 3411.42 1370.83 N 6119.88 W 7819.54 74.430 271.400 3285.33 3438.43 1372.29 N 6210.67 W 7914.25 74.040 275.480 3311.07 3464.17 1377.75 N 6301.63 W 8008.88 68.780 280.220 3341.24 3494.34 1389.94 N 6390.43 W 8104.45 64.930 283.860 3378.81 3531.91 1408.22 N 6476.35 W 8198.44 67.160 286.680 3416.97 3570.07 1430.86 N 6559.19 W 8292.39 69.840 287.450 3451.40 3604.50 1456.51 N 6642.74 W 8386.63 71.710 286.570 3482.43 3635.53 1482.54 N 6727.83W 8481.85 73.340 286.250 3511.03 3664.13 1508.20 N 6814.95W 8584.57 77.020 288.550 3537.30 3690.40 1537.90 N 6909.68W 8684.00 77.020 288.550 3559.63 3712.73 1568.72N 7001.54W Global Coordinates Northings Eastings (ft) (ft) 5913215.39 N 455280.09 E 5913236.79 N 455190.16 E 5913257.78 N 455099.44 E 5913276.34N 455009.13 E 5913290.92 N 454917.68 E 5913301.87N 454826.32 E 5913309.37N 454735.46 E 5913311.80 N 454646.84 E 5913311.95 N 454557.22 E 5913313.88 N 454466.45 E 5913319.82 N 454375.52 E 5913332.46 N 454286.80 E 5913351.19 N 454200.98 E 5913374.25 N 454118.27 E 5913400.34N 454034.86 E 5913426.80 N 453949.92 E 5913452.91N 453862.94 E 5913483.10 N 453768.37E 5913514.40 N 453676.69 E Dogleg Rate (°ll00ft) 3.89 4.27 0.57 3.42 2.69 3.50 3.65 4.70 3.49 2.31 4.17 7.31 5.34 3.63 2.95 2.17 1.74 4.19 0.00 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 283.360° (True). Based upon Minimum. Curvature type calculations, at a Measured Depth of 8684.00ft., The Bottom Hole' Displacement is 7175.13ft., in the Direction of 282.629° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. RECEIVED AUG 01 Alaska State Plane 4 Kuparuk 2N Vertical Section Comment 5545.71 5638.16 5731.28 5823.43 5915.74 6007.12 6097.19 6183.89 6271.02 6359.69 6449.45 6538.66 6626.48 6712.31 6799.53 6888.33 6979.02 7078.05 7174.54 Projected Survey · Continued... 18 July, 2000 - 11:13 -5- Alaska 0il & Gas C0~s. C0mmissior DrillQuest 2,00,02 Sperry-Sun Drilling Services Survey Report for 2N-332 PB1 Your Reft API.5010320340070 North Slope Alaska Alaska State Plane 4 Kuparuk 2N Comments Measured Depth (fi) 8684.00 Station Coordinetes TVD Northings Eestings (fi) (ft) (ft) 3712.73 1568.72 N 7001.54 W Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (fi) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 8684.00 3712.73 Survey Tool Description MWD Magnetic 18 July, 2000- 11:13 -6- RECEIVED AUG 0 ! P_OOP_ DrillQuest 2. 00. 02 CASING TEST and FORMATION' INTEGRITY TEST Well Name: 2N-332 Date: 7,--'~/00 Reason(e) for reel: Supervisor. R.W. SPRINGER [] Initial Casing Shoe Test [~[] Formation Adequacy for Annular Injection E1 Deep Test: Open Hole Adequacy for Higher Mud Weight IIHLITES MINI/TES LOT ~IlqOKES PRESSURE Casing Size and Description: 7..5/8";2g.7#,L-B0 BTC-MOD .,. j ~,, r 0 elks i 0 psi ..... ~ ' ,~?z~,~"7-~D .... j ~k--; ',"-i~";,- E~./-,',,,,,,,.~J. 7'~ e.. f,~"~ ........... , ...... _P.'.L! Casing Seffing Depth: 3907' TMD Hole Depth: 3,907' TMD ! ~ 8 stks r 200 ~el ' , .... . ' I ........ , ..........F ...... ~- ...... -1 . ~10' TVD . _ . .. , 2,110 TVD ! j 12 stks ,' 250~ Mud Weight: _ g.$ ppg Length of OpeT~ Hole Section: ,~!t_l~l ,' .........~ ~)' s'-~" ['"~i~.~ ps'--T'-r .... ' - '"'--'~'~'"" '~'~ r"--'"""'"---' ...... :t,~ i 24 sr~ ~ 400 p,F EMW for open hole section = 17.4 ppg f ......... -~'~--~;~"' ,-d~ ~'~ Pump mJtput = 0.o580 bps Fluid Pumped = 7.5 bbl ..[ 48 stks 725 CASING TEST DATA FOR CgG TES"I ~,I'ROi~S PRF,~SUflE f ............... ['-5-;iG-- o psi ,ill! .... Ill--Ill ..... ..i11.1~..I! ! .~_~__k~. ...... ~F.."',J...J ] 4 stka .. 4._.~.. p_.s.i...j ~' '~ 6 stirs 975 ~si .' :::::::::::::::::::::::::::::::::::::: I ' · ! ................. ............... ! ............... ......... ! .............. ~ ................ .............. s2 st_k?. ..... ~s psi.._] 'i..5, s,,,, ~" ,4 stb ...,.&s_e,..L.i ee dks ,.._~.s.o ps__J..j ~..,.......,......~.~ ........ -~ ~ i 76 stks 950 psi '--.....-..----........---- .... ..... ..... , .O.tk.....gS_O_~_?.i .... ' 92.tk. i- ~0 aks i -~SO p~ s.a~i.~u,= ~ s. ur~,.~ssu.~ 3 0 rain , ~ 2,000 0.0 rain_L_ ] 950 psi J ; 4.0 rain i i 2,000 p~. -"~ ....... r ...... -;' , ~ ................ t-' ............. ~ .........%'-i 1.0m{n [- f 875 ps} J ' 50mln : I 2,000 ps{ .... *} '~. .......... .-'-d.}--'~-'-'= .... '*--} .............................. 2.0 mtn ' : 8SO.p~m i ~ 6 0 rain ~ ""1 2,OEO rmsi ..~ ~. .+.. .... }. ......--.-{.---.--.-.-.-..4---.,~-4 3.0 rain j i 825 psi ] .... ,_ ; : ,,, ,,,.,v,..si _ . [ ",= . .. ~. ~.,a ,.,, ~. ~-"-. P' ,~.o re,r,, ..._~2~ 1-Eb-A:,~'", ......... : I-,---:--.---.~; ............... .I .......... 5.0rain i { ....~.....p.si__.j [ 9.0rain ! ~ 1,gOOpsi j 6.0 mLn"T i coo psi i i _! 0.0 rain [ [ _l,ggQ I~_! l ,P'"~ .... t----'-", °'--- 8 0 rain , ~ 7gO ,l~i..~ { 20.0 rain f ; 1,980 psi { ........ +: - : , ........ ~ ;- -- :- =--.~ ............... ~ .............. · 9.0 rain ; |775psi | ~ 25.0 rain ~ _~ 1,g$Op~i { ~o'o~in ,,':- ..... ]--'-~T'] V~o,o~,~W'i ~,'--~7op..~i_'] ¥ ! ~.~..,,,,,E [ ~,.,,..su.~ .... '--' .... "'F--I''""''--"'T .... --''--'"~ i i 0.0 minj ; 2,038 1.Omin ; i 2,000 2.0 rain { ,: 2,000 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME':see lime line above ' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION 'INTEGRITY TEST .- Well Name: 2N-320 Supervisor:- Scott Reynolds . Casing Size and Description:. Casing Setting Depth: 7 M-, 20.? pP~, --so, STC'. Mud Weight: 9.3' PP~I Hole DePth:. 2,322;. TVD Date: 02/01/99 3251 TMD . . 2,310' TVD' EIdW = Leak-off Press. + MW 0.052 x'I'VD 810 psi + 9.3 ppg' EMW . LOT = (O.O52 x 2.310') = 16.0 ppg Fluid Pumped = 0.7 bbl Pump output = 0.0840 bpe :. 'NOTE.' STROKE8 TURN TO MINUTEs DURING 'SHUT IN TIME':see time line above ' LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEsT STROKES PRESSURE 't -' 0 ~tks 0 3 stks 220 s,p_.~ 4 stks ' 5,tks '., ., 7 stks 675 8 ,. . ........ . . SH~ IN ~E .8H~ IN PRESSUR .. . , ..... 0.0 rain 810 psi. 3.0 min..~ .... _-4.0min ..,. '. . 760ps~ 5.0rain . _ 750ps~ 6.0min 7.0 rain . 740 psi. _8.0min - ' __. 730ps~ .... ~.0 rain- . ' 730 psi ~o. omin. 0 stks .__...O.p.._s.i..__ I stks __..1, .O_O.~.s..i._.. 2 stks lO0~sl ...... 4 8tks -"'~'l~'t~'~'s-i'.~ ~_~ 6 atks __..3.0_.0. p...s.i. ~ i0 stks 700 p..si ............ ~2 stks-'i~b-~b'~i-' ~a stks'~;'~'~'~.~i-' .... . !4_ s_t_ks_ ...... ~,_2..2..o..p..s.L ~5 stks _~,.3..o..o..p..s.L ........... ~6 stks !_.!1.,.4._o.o..p.s.J_~. ~? stks ~__,..s.o._o.p. s2_ ......... ~8 stks_L,.6_o.o..p..s.L 20 s__..__tk~_ ~.,~.o_o..p..,.L ............ 21 stks_.!.,~.o.o_p_s.L _22 st~.~ _.=,_o_oo.;.,_L' . , SHUT IN TIME: SHUT IN PRESSUF ................... ~.o rn,n ............. _2_ ,_o. o_o..p..s~ [ 2.0 rain 2,000 psl.,,i 4.0 min ....... ...~1,9_.9.~0 ps~ ~ 6.0 min .................. _l__,~.~_0.ps.. i_.. 7.o rain ...................... ~;~.~_.o p..s~ a.o min .......... !_,~o_p~[:~ __ _25;0 m~n .......... ~;P4~_ _a0.o mi, ....... NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY .. CASING TEsT and FORMATION INTEGRITY'TEST Well Neme: 2N-320 ' 8upervi~or. ' D.BURLEY . D=te: 2/7/99 :Casing Size end Description: Ce.ing Setting Depthi . Mud Weight: 9.3 ppg Hole. Depth: 4,5t4' TVD 29.7 pPf,'L-80, BTG 32st .TMD 2,310' TVD . EIVIW = · · . 400 psi +9.3 ppg EMW LOT = (0.052 x 2,310') - -. ' ' - b tl.0 ppg Fluid Pumped = 7.t bbl Pump output =. 0.084.0 bps t i UOOld 'i' "'i: :!"'i: .......... L' ' '!"','1 ....... :'~ .... 1"' I~OM r . ,_ ~ooM J' m t~M r -i r 1.1~ · ~M I . ~L~K-OFF ~ - LOT SH~ IN ~ME ~ ~ J ~ ~SING ~8H~IN ~E ~ F, ; ~ME LINE ~' j ........... :dd'fdfdddd/fddddiedfdfdd'dddddddddidddddeddddddddd" 0 -kkiik'kkkkkk. kkkktkkkkkkkkkkikkkkkilkkkkklklikklkkkkd k . _ , , .- ~ioTE: STROKES TURN-TO MINUTES DURING "SHUT IN TIME":see 6me line above . · LEAK-OFF DATA CASING TEST DATA MINU~ . . - MINUii::S FOR FOR LOT sTROKE~ PRESSURE CSGTEST STROKES PRESSURE __ - -; 0 S~'k'~-- 0 psi 4 stks _ . 10 stks 240 pSi :- ~2;(~ 2so psi _ ' 18 stks '3~'~T ' 20 etks ' --~ p~i~ , . 25 stks 380 psi 30 etks -f 390 psi 3S stks' ~= 3~b-~si = ' 40stko q .390psi dS'~tks~ _ . . S0 stks~: 55 stks ~00 psi 60 stkS - - .65 stks ....... ~9~.~ ~0 utko 3~.p~i 75 utks 390 psi - B5 ~ 3~'~p~ SH~ IN ~ 8H~ IN PRESSUF 0.0 min ...... 38o psi - 1.0min" ' ' '320psi ' 2.o min. . 3oo psi _ 3.0 rain 290 psi _ " 4.0 rain - ' .28Q psi ' ~:b min: · ; · 280 psi 6.0 mjn - " .. ' 27o psi _ ' 7.0~in' . ' ' ~70 PS! 8.0 mfn 26o psi _ - 9.0 mJn '~60 psi ' , , , i 10.0 rain .... 2~ ~J ~ - --~i~S: -~0'0-~i'-: _. . :_ _~_6_.~iJ~s300 p~'i- 8 ~i'~- - 500 ps'f : ' ~3~i~'~-- ~,~20 pal _ ~ ~ .... 2.000 p~i _ _ ~ . ~ , SHUT IN nME SH~ IN PRESSUI 0.0 min : '' ,. 1.0 min 2,000 psi - 2.0 min' : - 2,0~ ; :: : : ~: :: -~ . ..3.0 mm ; _2,000 - ~.0 min t,99o pm 7:0 min' 1,980 psi . 8.0 min ' t,9~0 psi g.o min ...... t,~80 psJ- ~- ~0.0 ~in ~ . 4,eThOs - ~5.0 min ~ ~ 1lOS0 Psi :- 20.0 min ....... i,9~T~ -- 25.0 min t~94~ · 30.~min I " ' "~',9~ IRE NOTE: TO-CLE~ DATA HIGHLIGHT AND PRESS THE DELETE KEY .e Cementing Details ARCO Alaska, Inc. Well Name: 2N-320 R~;t Date: 01129/99 R~;_-~ N~.;,~,~ 6 POOL 6 AFC No.: AK9797 Field: Tarn ig! . Centmlizem State/ype used,/ntetva/s covered en~ Comments: ;Ran cantralizam in center of Jta 1,2,53, 64 over Mop collars end over caelng collars on J~ 3-14 end over collie of Jt~ 34 Gemeco Bow SpHItg 17,20,23,26,20,32,3t'),38,41,44,47,50,67,6O,93,~9,72. Centr-!!-,,m ., Waight: PV(pl~r concl):- I?V(elter concl): I YP(~,~. c~-~,): YP(&~M ~.-,G): Mud Comments: 10.2 28 14~ ~4 14 Gals before: Gels altec. Total Volume Circulated: 14/57 6tl0 1020 Wash e Ty~e.: Volume: Comments: ARCO 20 8.4 .Spacer O Type: Volume:. Corranm~: ARCO B46 40 10.6 Lead Cement O Type: Mix wtr temp: No. of Sacks: I Wu~h~ Comments: AS In Ute 6O 304. t0.7 4.4~ Additives: Standard Blend Comment~: . G 6O 261I [t6'8 1.17 Additives: '. · 1% 81, 0.2~ D40, end 0.3% D66 Displacement 0 Rata(before tail at 8hoe): Rate(tall around ahoe): .$tr. Wt. Up: C~: 8 BPM ' 9 BPM .. Reciprocation larch: Rectpro~tion qx~d: .$tr. WL Down: Did no~ Reciprocate. ,0 .. H ' Theoretical Dbplacemer~ ' Actuel DispIacemm~.'.' .8tr. Wt. in mud: t46.27 bble 146.77 bbla Celmletad top of Mment: C.P: Bumped plug: I F;~,a~ Ratuma to euda~ Data:l/2WgO ye~I Time:09:66 ~emarks:Condition mud ~ 8 bpm W/full retume. Pumped 10 bbla preaueh, 4O bbl" epecer, 3tl bbla of lead and 62 bble of tall ¢e~,e,-~;. weahup water ind 120.77 bble of mud, full returns throughout. Hid 76 bble of 10.7 ppg cement.ratuma to eUfflCe. Casing pulled tight attw making up cement md, did not r~olpracat~ . , , . ~ement Company: I Rig Contractor: lap! By: Do',~=ll . , iPOOL IRickey D. Overstreet '"1 · ARCO Alaska, Inc~ Casing Detail 7.625' Surface Casin; WELL: TARN 2N-320 DATE: 1129199 Subsidimy of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOP8 ' Above RKB 7 518" Landing Joint 34.60 FMC GEN ¥- Prudho~ 7 5~8" Csg Hgr 3.21. 34.60 its. 54-76 7 518", 29.7#, L-80. BTC-mod(23 jts) 976.66 · 37.81 TAM 7. 518" Port Collar 2.48 1014.47 jts. 3-53 7 518", 29.7#, L-80 BTC-mod (51 its) 2145.68 10~6.95' Gemeco Float Collar' 1.36· 3162.63 ' its 1-2 7 518", 29.7#, L-80 aTC-mod(2 its) 85.75 3163.99 Gemeco Float Shoe ' 1.50 3249.74 Casin[I shoe i~ . 3251.24 __ T.D. @ 3265' leavin~l 12' of rathole ., . 34 Gemeco Bow. Sprin~ CENTRALIZERS ' Run centralizem in' center of Jts. 1, 2, 83, 54, over stop collars -- and. over casin~ collars on Jts. 3-14 and over collars of its.. 17, 20, 23, 26, 29, 32, 38, 38, 41, 42,44, 48, 47, 48, 50, 81, 87, 60', 63, 66, 69, 72. . ,, · ,, , . , . . , Joints ~7- 103 (27 joints) will remain in' the pipe shed. , . · . . . : ..' , ,. . · · .,. , · · . ,. ! , . · ... , . , , · .. · · , . Remarks:' String Weights with Blocks: 135K Up,' 95K Dn, 70k Blocks. Ran 76 ~oints of caslnt;l.. · Drifted casing with 6.750" plastic rabbit.. 'Used Arctic Grade APl Modified No 'Lead thread compound on all connections. Casing 'is non-coated. ,, ,, . Pool 6 Drflling Supervisor. DA VE BURLEY . 907 276 7542;# 1/ 8 SENT BY: 7-19- 0 ; 1'88PS ; ( PHILLIPS Alaska, Inc. A Sub=idi,~ry o! PHILLIPS; PETROl ~.tJM COMPANY P.O, BOX 1O036O Anchorage, Ak 995106360 PHILLIPS AK INC, Date Pages'. CC', · i~i~or Review [] please. Comment [] Please Reply [] Please Recycle ,Comments: RECEIVED JUL 1 9 2000 Alaska Oil & Gas Cons. Commiss'mn Anchorage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 July 13, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Sundry Approvals for 2N-347 and 2N-332 Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Application for Sundry Approvals for 2N-347 and 2N-332. We are requesting approval for annular injection down these wells. If you have any questions regarding this matter, please contact me at 265-6434 or Tom Brassfield at 265-6377. Sincerely, J. Trantham Drilling Engineering Supervisor PAI Drilling JTfrB/skad RECEIVED ,JUL 1 8 2000 Ala~a Oil & Gas Cons. Commission A~chorage , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory __ Stratigraphic _ Service _ 4. Location of well at surface 99' FNL, 924' FEL, Sec. 3, T9N, R7E, UM (ASP: 460669, 5911909) At top of productive interval 2166' FSL, 98' FWL, Sec. 33, T10N, R7E, UM (ASP: 451139, 5914229) At effective depth At total depth 2249' FSL, 248' FEL, Sec. 32, T10N, R7E, UM (ASP: 450793, 5914315) 6. Datum elevation (DF or KB feet) RKB 35 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-332 9. Permitnumber/approvalnumber 200-079 10. APInumber 50-103-20340-00 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12026 feet Plugs (measured) true vertical 5250 feet Effective depth: measured 11889 feet Junk (measured) true vertical 5167 feet Casing Length Size Cemented Conductor 78' 16" 9 cu. Yds High Early Surface 3872' 7.625" 385 ex AS III Lite, 240 sx Class G Intermediate 11245' 5.5" X 255 sx Class G & 420 sx Class G Production 734' 3.5" (included above) Measured Depth Truevertical Depth 113' 113' 3907' 2311' 11280' 4852' 12015' 5243' Perforation depth: measured 11600'-11630' MD true vertical 5009'-5024' TVD Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3.5", 9.3#, L-80 @ 11307' ORIGINAL Casing Seal Receptacle @ 11290' MD, No SSSV RECEIVED ,JUL 1 8 2000 Alaska 0il & Gas Cms. Commission Anchorage 13. Attachments Description summary of proposal w Detailed operations program __ BOP sketch LOT test, surface cement details and casing detail sheets, schematic __X 15. Status of well classification as: 14. Estimated date for commencing operation July 26, 2000 16. If proposal was verbally approved Name of approver Date approved Oil ~X Service Gas ~ Suspended 17. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Signed J/~1, ~4,,e..~'-T~14~'~1~'~ Title: Drilling Engineering Supervisor Jam'Es Trantham FOR COMMISSION USE ONLY Questions? Call Tom Brassfield 265-6377 Date I'2~' Prepared ~, Sharon All, up-Draket Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance_ Mechanical Integrity Test_ Subsequent form required 10- ORIGINAL SIGNED BY Cop Approved by order of the Commission D Taylor Seamount Approved Returned Form 10-403 Rev 06/16/88. _,. 7 ~'r~,,I '" Approval no. SUBMIT IN TRIPLICATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-332 Date: 6/15/00 Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test Reason(s) for test: [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-5/8', 29.7#, L-80 BTC-MOD Casing Setting Depth: 3,907' TMD 2,310' TVD Hole Depth: 3,937' TMD 2,320' TVD Mud Weight: 9.5 ppg Length of Open Hole Section: 30' EMW = Leak-off Press. + Mud Weight = 800 psi + 9.5 ppg 0.052 x TVD 0.052 x 2,320' EMW for open hole section = 16.1 ppg Pump output = 0.0940 bps Fluid Pumped = 1.1 bbl 2,20o 2.om pd Jr-- -. & -' -- - ..... ! 1,700¢ / 1,,mo p~ 1,$o p,d --e-- LEAK4:)FF TEST 1,4m p~ --d~CASING TEST 1,~o pM -.e-- LOT SHUT IN TIME 12oo pM 1.1oo pM / ~ CASING TEST SHUT IN TIME ~.om p~ / t TIMELINE 7OO¢ ~ psi i 0 psi ~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKr~ PRE88ORE .................. .9.~t..k..~. ........ _o..R.~l ..... ................. .?..s.t..k..~. ........ .0..R?.[ ..... .................... ..4..~.t_k..=_ ....... .~..p..=!. .... .................... ..6....t_k.... ....... [o_.p.?!. .... .................. ..S.~t_.k..s. ..... ~.6..0...p..=!..., ................... !o...s.t.L~. ..... ~Z..p..s!..., .................. .l_Lst...k_,. ...... ..8~....~..,! .... 1 I , , · i I i i I i i i , ! i , ! , CASING TEST DATA MINUTES FOR CS(;I TEST STROKES PRESSURE ................ ~. ............... t ................ Oetke j Opel j ............................... · ....... i 35p ' 2 8tk8 si ................... .4..?.t..kLL...4~...P.~!.. j i , 6etke I 975psl l ............................... · ......... ................... .8..?.t..k.s.j..!:[.og....p~.l .................._.._. I · , , i ................ · ............... · ................ i i , i i i i I ................ ~ ................ · ................ .-l 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 SHUT IN TIME SHUT IN PRESSURE .._o....O_.m.i..n. ....................... 1.0 min 2,000 psi 2.0 mln' ': "'~',~iJiJ 'l~'~]'I''~ i · i i , ,. 0 0 mln , ,, 800o~st p .............. .~ ............... .~. ......... I.. ..... . · , 1.0min i ~ 787pei I ......... '~ .... i ............... i ......... ' ...... ,,..~:.o_..m..,.n...j ............... ,..i....?!/..8...p..sL.; · i i 3.0 mln ,, ,, 773psi . 4.0 min ,,, J.L 769 IR. el i .......... ': .... I ............... i ........... "~"' i....s_:.o...m.:.L.i ............... ,,....7.~Lp.?.,...~ ..~-..o...m..Ln_..i ............... ,'.j._].[o_..p.s. Lj SHUT IN TIME I SHUT IN PRF. SSURE ....3....0.._m.i..n.._: ................ 2,000 pei 4.0 rain i ,2,000~si ::::::::::::::::::::::::::::::::::::::::::::: 6.0 min ,,, i 2,000 psi "'~:6"~iiF': ............... ;"~',i~i~-~i" :::::::::::::::::::::::::::::::::::::::::: 9.0 min ,j j 1,990 psi ~ ............ ;"", ............... , ..............7, .. J..o:..o...m.,..n...,, ............... i..).,~..p.s..L4 ,. 8.0 minj "-L 756 psi j . 20.0 rain i i 1,980 psi .~ , .......... ~ .... , ............... , ............ 7" , ........... :"", ............... , ................ , i i i i , 9.Omln , , 756 psi , ~ 25.0mln I : 1,980psi: i- .............. - ............... .i- ................ · i,- ............... .i. ............... · ................ '-~ ...1..o_...o...m. Ln..j ............... i..j.5..1, p....s)...j _3..0....0...m.i..n..! ................ l...~.,_e.Z.o...p..~Lj NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME':see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-332 Date: 715100 Supervisor: R.W. SPRINGER Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-518",29.7#,L-80 BTC-MOD Casing Setting Depth: 3907' TMD Hole Depth: 3,907' TMD 2310' TVD 2,310' TVD Mud Weight: 9.5 ppg Length of Open Hole Section: #VALUE! EMW = Leak-off Press. + Mud Weight 0.052 x TVD -- 950 psi + 9.5 ppg 0.052 x 2,310' EMW for open hole section = 17.4 ppg Pump output = 0.0580 bps Fluid Pumped = 7.5 bbl 2,100 psi 2,000 psi 1,gO0 psi 1,800 psi 1,700 psi 1.600 psi 1,500 psi 1.400 psi 1,300 psi 1.200 psi 1,100 psi 1,000 psi g00 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi O psi iTIME:.EINE -'.'-" I :ONE.-M!N.~]~i]].~.KS:.. 1 I' ,~ "'; :' ' ' , ~ ~ ~ LEAK-OFF TEST , ~ ~ ~CASING TEST ~ ..... ~--..- LOT SHUT IN TIME · ~ ~ CASING TEST SHUT IN I ~ I T~MF ~ , , , , , , , , , , , STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE i 2stks 35 psi i. ................ i. ............... .i ................. , ~ 4 stks 400 psi i 4stks i 125psi i ................ t ............... f ............. ~ 8stks i 200ps, i i ' i = 12stks : 250 ps, : i 16stks i 300 psi ................ · I ................ ? ................. '1 i i · i ; 20stks : 325 ps, ................ L_2_Ts_!.k..s...i___5.o_.o...p.s_L_i i 28stks i 450 psi i 32stks i 500 psi ................. ~,- ............... f ................. 4 i i · i ~ 36stks ; 575 ps, ,, ................ 'l ................ 1' ................. i i · i , 40stks : 600 ps, ................ i___9.~!~?__.l__.7.~.s.._p, sJ_..l i i · i : 52stks ; 775 ps, i ................ ..i. ............... & ................. .i i i . i : 56stks : 850 ps, : ..... ........... Ji ................ Il ................. l ................ -i ..... i ...... i i · i = 64stks = 925 ps, ................ 'I- ............... T ................. i i · i -i 68stks i 950 ps, ,,, ................ LT_.~..s..~L L.~.s..o___p.s_ L.i i 76stks i 950 psi i 80stks i 950 psi ................ ! 116stks i 950 psi ~ 6 stks ____.9.7..5_..p__s_i_..~ ................. ?"~'~'t'~<'~ .... 1,500 psi ; , , , , ................. i. ............... .i ................. , , , ................. ? .................................. , , i i i i i i ! i i i i i i i i , ! , i i i I I I i SHUT IN TIME I SHUT IN PRESSURE .... ............... .... ................. SHUT ,. TIME; SHUT,. PRESSURE :'-"~'.~'~-i~"'[ .................. , ................. i- .................................. 0.0min ! ! 950 psi i i 4.0min i 2,000 psi ................ .~_ ............... ~ ................. j ~ ................ ~. ............... .a ................. 5.0 mini i 2,000 psi 1.0min i ' 875p" ; [---~)"~'i~ [ .................2.0 m,n' ~',' ................ If' ................. 850 ps,' it' ..................... ................ 1 ................ 1' ................. i ................................................. : 7.0 m~n : : 2,000 ps, .._.3_:P__m!.n...~ ............... i____8..2..s_.p?.L_i '~ .......... .: .... '. ............... ~ ............... '... : 8.Om~n : : 1,990ps, 4.0rain i ,~ 810 psi ! .... ' ....................................................5.0 m,n' =' :' 800 ps,' ,' ['"~'.~'~'i'~'"[ ............... ................ ,.i ................ 4. ................. ,4 .................................................. 7.0min i i 790 psi i i 150min ! i 1,990psi ! , ............ -.----~ ........... '1- . , -- _j ................ I ................. "1 i ' - ................... J ........... ~ ' i i · S.0 m,n = = 790 Es, :~ --------- ,I--20'O-m'n--I ............... m_l__,_9__8_O__p__s_[_: ................ -I ................ + ................ -I NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST ?l~lo° Well Name: 2N-332 Date: ~ Reason(s) for test: . Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test' [] Formation Adequacy for Annular Injection. [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-518",29.7#,L-80 BTC-MOD Casing Setting Depth: 3907' TMD . 2310' TVD' Mud Weight: 9.5 ppg · Hole Depth: '. ~ TMD (~ q g l U 'f'V.D . Len~h of Open Hole Se~ion: e~! EMW = Leak-off PresS.- + Mud Weight ... = - 950 psi - 0.052 x TVD 0.052 ~ EMw for open hole section =~4"ppg Pump output = 0.0580 bps. Fluid Pumped = 7.5 bbl 4. 9.Sppg 2,1'00 pd 'lReOpd 1,800 pd 1.700~ 1.600 p,d 1.S00pd 1.,4e0 pM 1.3ao 'mi m 1.20o pd Silo pd I1! I! - .I I III III ,,"" '~' II I .,~ · ._ - -.- CF_.AK-OFF TEST ! I ,~ "' '='a--CASING TEST II ~' I' .M,/.- -e-. LOT SHUT IN TIME I ,L~ ~' ~l~ CASING TEST SHUT IN , , , , , .... , , ! , , STROKES · . LEAK-OFF DATA CASING TEST DATA MINUTES MIN~$ FOR LOT STROKES PRESSURE .....O..s..t.k..s. ......... .0..~..?). ..... .................... ..4.~.t.k.~ ....... ~.~..~.~! .... .... .S..s..t.k_s. ..... .2..0_O.~.s..~ .... · ....L2..s. Lk~ ...... .2_s_o_.p_,.~ .... .................. .~..s..s.!~ ...... ~.o..o.~.~ .... ................... .2..0_s_.t.k..s. ....... .3..2..5..p...s.! .... - .._2..4._s.t.k..s. ..... .4..0..0...p.?.L' 28 stks 450 si ....3..2..s..t.k..s. ...... .S..0..0...p.s..,... ................... .3..e.~.t~?. ..... .s..7..s.£.s.!... .~ ............. ..4.0_s..t.k.~_ ..... .6. .0. .0. ~.?L ....4..4.~.t.k.~ ..... .6..S. .0. ~.s. !. .. · ....4..8..s.!.k..s. ..... .7..2..5. ~.s..i...i 52 stks 775 si 56 stks ... .8. .5..0. .~.s. !.. . .I , S0 stk$ ....9..0..0.£.s_i... ............... t"~'~.'~ii~" ...~.2..5...p.s..,... 68 etke .,9..5..0. p...s.! .... ................. .7.2_. ~!.k_s. .... .0..S..0...p.s.! .... ............... 76 etke ..._9..S..O...p.s_.i .... .80 stks 950 psi ............... ~"~'~ii~" '"~b'~.'~i .... 116 stks 950 psi -. FOR CSG TEST STROKES PRESSURE 0 stks 0 psi 4stks i 400psi I 8 stks 1,500 asi SHUT IN TIME SHUT IN PRESSURE 1.0 min i 875i)si 2.0 min ' ,..8..5.0_..E....s.i .... 3.0 rain ' . ............. t . .. .8. .2. .5. ~.s..i_ ., 4.0 min ............... , .... .8..1..0.p...s..i...i 5.0 min · ,....8..0.9~.s.! .... '--i 6.0 rain i 800psi · 'l :~:~ 'm%' ..... " ......... ]'"~b'i~"'ii"'! ;r 8 .... 0-m~n-r" "'""--'"". - ]'"'790 ...... DS,':'-- I ' .mil.........~l.. iml.~......--..i,., .: 9.0min ~ I 775 psi r ........... 't' ............... · ............. ~ .... ! 10.0min ' f._..7~...5.p_.s.! .... , 130 Stks 950 psi .... ..2:.0...m..i.n. ...................... .2.,.O..O.O...p..s_ SHUT IN TIME SHUT IAI PRESSURE 3.0 rain 2,000 psi ; ...~............... .... ..........,,--................... .... ... .... q.... ....... ,~.--.-.,i .... .4...o._m. Ln..., .................. .2..,.o..o.o..Es.U 5.0 min 2,000 psi j _.e...o...m..i.n__ 2,~o Es, , _..7:..o..mZn. ..... 8.0 rain 1,990 p.~i ! "'~:~'~'~ .................... 3';b'~'o-p.~i! "'i'~:~';~'ii~ ................. :l';b'~,~'i;~'f'l i...~_~.._o.~.L.... :::::::::::::::: ":,';b-~'~'~-~q f"~'~lT~';~i;~':[ ............... ~,~8o~si j :::::::::::::::::::::::::::::: NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME':see time line-above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska Drilling Cementing Details Well Name: 2N-332 Report Date: 06/15/2000 Report Number: 7 Ri~l Name: Nabors 19E AFC No.: AK0055 Field: TARN i Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: % washout: 7-6/8" 9-718" 71I 3907 3820 Centralizers State type used, intervals covered and spacing Comments: 39 BOW SPRING JTS 1-12 & EVERY 3 J'rS TO SURFACE Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.3 20 19 21 14 Gels before: Gels after: Total Volume Circulated: 10/18 2/6 2+ HOLE VOLUMES Wash 0 Type: Volume: Weight: Comments: ARCO Wash 15 BBL 8.5 Spacer 0 Type: Volume: Weight: Comments: ARCO B45 40 BBL 10.5 PPG Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III UteI 75 385 10.7 4.44 304 BBL Additives: G W/.50% D124,9.0% D44, 0.4% D46, 30% D53, 1.5% Sl, 1.5% D79 .Comments: GI 175 240 SX 15.8 1.17 50 .BBL TOTAL, CMT TO :SURFACE W1102 BBL OF 175 Additives: .BBL DISPLACEMENT G W/1.0% Sl, 0.2% D46, 0.3% D6S Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: 'Comments: 6 BPM 5 BPM 90 Reciprocation length: Reciprooation speed: Sir. Wt. Down: 10' 1 STROKE/MIN 55 Theoretical Displacement: Actual Displacement: Sir. Wt. in mud: 175.3 Calculated top of cement: CP: Bumped plug: Floats held: CEMENT TO SURFACE Date:6/14/00 NO YES Time:0630 Remarks:FULL RETURNS THROUGHOUT CEMENTING, NO BROACHING , ! Cement Company: Rig Contractor: Approved By: Dowell NABORS R.W. SPRINGER RECE VED- J',JL ~ 8 2000 Alaska 0it & Gas Cms. Commission ~o~e Casing Detail 7-5/8" surface casing # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors19E RTto GL=34.50' TOPS Above RKB 4.54 7 5/8" Landing Joint (38.97 total) 34.50 4.54 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.50 39.04 its.70-93 7 5/8", 29.7#, L-80 BTC-MOD 986.88 41.54 Tam Port Collar 2.47 1028.42 its 3-69 7 5/8", 29.7#, L-80 BTC-MOD 2789.49 1030.89 Gemeco Float Collar 1.37 3820.38 its 1-2 7 5/8", 29.7#, L-80 BTC-MOD 83.67 3821.75 Gemeco Float Shoe 1.50 3905.42 BTM OF SHOE @ ..... >>>>> 3906.92 TD of 9 7/8" hole = 3917'MD 39 TOTAL, Gemeco Bow Spring Centralizers 3, Centralizers in center of jts. 2, 69 and 70 over stop collars 96 ,Centralizers over collars of jts. 1, 3-12, 15, 18, 21,24, 27, 30, 33 36, 39, 42, 45, 48, 51,54, 57, 60, 63, 66, 72, 75,81, 84, 87, 90 II i 8 20(0 Alaska Oil ~i Gas Cons. C~remission Remarks: String Weights with Blocks: ??? k Up, ?? k Dn, 18k Blocks. Ran 93 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Three joints surplus including one jt that did not drift. WELL: 2N-332 PHILLIPS Alaska, Inc. DATE: 6/13/00 1 OF 1 PAGES PHILLIPS ALASKA INC CASING TALLY PAGE: i of 2 WELL: 2N-332 Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 6/13/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 41.05 26 42.43 51 42,61 76 42,63 101 126 151 176 2 42.62 27 34.91 52 42.62 77 42.62 102 127 152 177 3 40.85 28 42.65 53 42.16 78 40.13 103 128 153 i178 4 42.63 29 37.93 54 40.12 79 42.41 104 129 154 179 5 41.58 30 42.66 55 42.70 80 41.12 105 130 155 180 6 42.02 31 40.56 56 42.35 81 41.18 106 131 156 181 7 40.95 32 42.03 57 42.52 82 40.61 107 132 157 182 8 42.62 33 40.94 58 35.68 83 40.70 108 133 158 183 9 41.37 34 40.86 59 40.70 84 42.39 109 134 159 184 10 42.56 35 42.38 60 42.39 85 42.17 110 135 160 185 11 40.40 36 40.92 61 40.57 86 39.34 111 136 161 186 12 42.69 37 42.63 62 41.78 87 39.15 112 137 162 187 13 42.65 38 42.34 63 42.62 88 39.82 113 138 163 188 14 42.66 39 42.68 64 42.63 89 40.23 114 139 164 189 15 42.67 40 42.66 65 42.58 90 40.49 115 140 165 190 16 42.38 41 41.02 66 42.62 91 37.42 116 ,141 166 191 17 38.40 42 42.62 67 42.44 92 42.60 117 142 167 192 18 42.60 43 42.63 68 42.70 93 40.99 118 143 168 193 19 42.64 44 42.47 69 40.53 94 119 144 169 194 20 42.22 45 40.58 70 42.40 95 120 145 170 195 21 42.61 46 42.69 71 40.18 96 121 146 171 196 22 42.08 47 42.50 72 40.49 97 122 147 172 197 23 34.73 48 40.33 73 42.61 98 123 148 173 198 24 42.62 49 42.66 74 42.51 99 124 149 17z 199 25 42.56 50 42.60 75 42.69 100 125 150 175 200 Tot 1042.16 Tot 1038,68 Tot 1043,20 Tot 736,00 Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3860.04 TOTAL JOINTS THIS PAGE = 93 RECEIVED JUL i 8 2000 Alaska Oi~ & ~a,~ C,u.~. ,.,,.,,,,,,.~,-.,. Anchorage DIRECTIONS: Float Shoe = 1,50 Float Collar = 1,32 Stage Collar = 2.50 Fluted Hanger = 1.32 PHILLIPS ALASKA INC CASING TALLY PAGE: 2 of 2 WELL NUMBER: Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 6/13/00 Column9 Column 10 Column !1 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 2011 226 251 276 301 326 351 376 202 227 252 277, 302 327 352 377 203 228 253 278 303 328 353 378 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 231 256 281 306 331 356 381 207 232 257 282 307 332 357 382 208 233 258 283 308 333 358 383 209 234 259 284 309 334 3591 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 , 213 238 263 :288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 24Z 269 294 319! 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 1299 324 349 37z 399 225 250 275 1300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 3860.04 TOTAL JOINTS THIS PAGE = TOTAL JOINTS = 93 Average Jt = 41,51 DIRECTIONS: ,..I~.~l 182000 -- Alaska Oil & Gas Cons. Commission Anchorage Type of request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ " Time extension _ Change approved program _ Pull tubing _ Variance _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: ~ Development _X Exploratory _ Slratigraphic _ Service _ 4. Location of well at surface 151' FNL, 1143' FEL, Sec. 3,.T9N, R7E, UM (ASP: 460450, 5911859) At top of productive interval 230' FSL, 1076' FEL, Sec. 32, T10N, R7E, UM (ASP:449958, 5912302) At effective depth At total depth 124' FSL, 1466' FEL, Sec. 32, T10N, R7E, UM (ASP: 449568, 5912203) 12. Present well condition summmy TOtal depth: measured 12735 : feet true vertical 5268 feet ., Effective depth: measured 12604 feet true vertical 5196 feet Plugs (measured) Junk (measured) Stimulate _ Perforate _ Other _X Annular Injection 6. Datum elevation (DF or KB feat) RKB 35 feet 7. Unit or Property name Kuparuk River Unit ~~t,~3p~l approval number 200-063 10. APl number 50-103-20337-00 11. Field I Pool Kuparuk River Field/Kuparuk Oil Pool casing Length Size Conductor 80' 16" Surface 4175' 7.625" Intermediate 11881' 5.5' X Produ~on 808' 3.5" Cemented, 9 cu. yds High Early 410 ax A8 III LW, 240 sx Class a 105 sx Class ~ & 248 ex Class (3 Measured Depth True vertical Depth 115' : 115' 4210' 2300' 11916' 4805' 12724' 5262' Perforation depth: measured 12352'-12382' MD '. true vertical 5052'-5070' TVD Tubing (size, grade, and measured depth 3.5', 9.3#, L-80 {3 11910' Packers & SSSV (type & measured depth) DUPLICATE Casing Seal Receptacle @ 11896' MD 14794"TVD, No $SSV RECEIVED 8 r-~jt~.~ ,. , , AlaSka 0il & Gas Cms. ~ssion Anchorage 13. Attachments Description summary of proposal_ Detailed operations program __ LOT test, surface cement details and casing detail sheete, sohematio .X BOP sketch _ 14. Estimated date for commenoing operation July 26, 2000 16. If proposal was verbally approved Oil __X 'Name of approver Date approved Sewice __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge.. Signed Ok Title: Drilling Engineering Supewisor James Tran~ham ' FOR COMMISSION USE ONLY 15. Statue of well olassification aa: Gas __ Suspended _ Questions? Call Tom Brassfield IConditione of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _. Location cioaranca_ Mechanioal Integrity Test _ ~, ! Subsequent form required lO- Approved by order of the Commissi Commissioner ., Form 10-403 Rev 06/15/88 · Approval no. SUBMIT I N TRIPLICATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-347 Date: 5/24/00 Supervisor: R.W. SPRINGER Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-5/8", 29.7#, L-80 BTC MOD Casing Setting Depth: 4,210' TMD 2,303' TVD Hole Depth: 4,240' TMD 2,309' TVD Mud Weight: 9.5 ppg Length of Open Hole Section: 30' EMW = Leak-off Press. + Mud Weight 0.052 x TVD -- 800 psi + 9.5 ppg 0.052 x 2,309' EMW for open hole section = 16.2 ppg Pump output = 0.1010 bps Fluid Pumped = 0.8 bbl 2,2OO 1,90O psi ~ 1,8oo Psi / ITiI~iE'~Li'~I~.:'....:';": . '? :'"': "..'~ ~"~"": I;~:~'~:,;~,~,~s'."':'l 1,~ psi ~ ~ I 1,~ ~ 1,~ psi ~ ].3m pa ~ ~ LEAK-OFF TEST ].2m psi ~CASING TEST 1,1mini ~ + LOT SHUT IN TIME 1,~ psi / ~ p, ~ CASING TE~ SHUT IN TIME ~ TIME LINE omi ~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .................... ~.s..t.k..s. ........ .4. .0. _0. j~.s. ! .... ................ ,, ....e..s..t.k..s. ....... .s..o..o...p. sj .... , ! , , , ! , SHUT IN TIME SHUT IN PRESSURE .... .O....O_..m.!.n. ...................... ..O.O..O...p.,.! .... ...!..9_.m__,.n.._: ................... .7_.r_.~___p~! .... ...~..o...m.!.n...j ..................... J.r..~.£~.i .... ~.0 min ~ 750 p~i ....+.o...m..Ln...~ ................... ~.o.£~.~ .... ....s...9...m.!.n.._. ~ .................... 7.~.o__p.~_~ .... .... §.9_..m__Ln_. ," ................... .7.~.o...p~! .... _.._7_._o...m.i.~... ,~ ............... i...!~.o.J~.i .... __.O_..O_.m_i.n___ i ............... L__Z~_~_~_i .... .._L°.-9...m. Ln..Z ............... i....T~.~...P~.~ .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .................... .O.._s.t._k?_. ........ .0..p.?). .... ..................... .2...s_t.k.s.. ...... ~.s..o..p..s.L.j ..................... &?.t..k~. ...... .s..s..o..p._s.L.i 6 stks 525 psi i .................... .Lo..?.t..k.s. ...... .?.o..o..p.?L.J .................... .L2...s.t..k.s. ..... ~.,.~..o..o.p..s.[.-'--,. .................... ~..4..?.t..k.s. ..... .!.,.2..S.O..p.?!., .................... .!.S...~.t..k?. ..... ~,.~..7.s...P_s.L .................... J..s..s..t.k.~ ..... J.,.T.o..o..p.?.i... .................... .2..o...s.t..k.s...,.. ~.:.~..4.o..P_s.L i , i. ................ i. ............... .~ ................. I SHUT IN TIME SHUT IN PRESSURE .... ~.:.O...m..i.n. ...................... .2.,p..o.o..p_s.L ,~ ...._~:.o...mj~ ...................... ~:.o._o.o_.p.~L' .....a...O...mj.n. ..................... ~,p._o.o._p.~L' ~....~...o...mj.n. ...................... &,.o..o.o...p.~Lj ___s:_o._.m._i.,. ...................... .2.,.o..o.o_..p_.s.t.., ...?:.o...m.'.,.,. ...................... .2_.,_o._o.o._p..s.L: ....T:.O...mj.n. ...................... .2.., .0..0..0. P..s.L~ 8.0 rain 2,000 psi l ....?...o...m.j.n. ...................... ~.,.o_.o.o.._p.~[..: ..Lo...o...m_i_n. .................. ]_.~.,.°..°..°..p.~L] , 2,000 ps~ ...J.s....o...m..i.n._.., ................................. ..__~_o__..o___m._i_n...[ ............... j..~,..o.9.9_.p_~[_., _.a..o:.o...m..i.n...L ............... ]..~:.°.9.°..P.~[..; NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N 347 #2 LOT Date: 5/30/00 Supervisor: Dearl W. GladdenX Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7 5/8", 29.7 ppf, L-80, BTC Casing Setting Depth: 4,210' TMD 2,292' TVD Mud Weight: 9.8 ppg Length of Open Hole Section: EMW = Leak-off Press. 400 psi 0.052 x TVD + Mud Weight - 0.052 x.~' + 9.8 ppg EMW for open hole section =..1-1~ppg Pump output = 0.1010 bps Fluid Pumped = 4.4 bbl 2,300 psi II II II I 2.200psi .... I, l ....I, I ....I, 1, , , I ............... ,~ L ....... z]0opsi .... I'1' ' 'I'1 .... 1'1' ' '1 .................... r ....... 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1.500 psi 1,400 psi 1,300 psi 1,200 psi ].ooopsi f I mo psi ~ ' .-e- LEAK-OFF TEST 800 p~ ~r 700 psi ~, 'm;~"CASlNG TEST ~oo psi ~ [ ~ LOT SHUT IN TIME soo psi / --,e-CASING TEST SHUT IN TIME 3oopsi4°° psi ~l [j ~ar'~ ' ' ' ;%~ ~ ~~ ~ ~l~l~ I TIME LINE 200 psi ................ ~P'~ III IIIIIIIIIIIIIIII 100 psi o~! !!! I!!!!!!!!!!!!!!! 0 2 4 6 8 ~ ~2141618 2~ 22 24 26 28 3~ 32 34 3~ 38 4~ 42 4~ 4~ 48 5~ 52 54 56 58 6~ 62 ~4 (~ 68 7~ 72 74 76 78 8~ 82 84 8~ 88 ~;~ ~ 94 ~ stk stk stk stk slk slk slk stk stk slk stk st~ sfk stk stk stk stk stk slk sfk s~ ~ ~ ~ ~ s~ s~ sffi ~ s~ ~ ~ ~ ~ ~ ~ ~ ~ s~ ~ ~ s~ ~ sffi s~ s~ stk ~ ~ STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................ -~- .......................... %- .... ~ ................ ;. ........................... ; .... ~ 0stks 0ps~ i i 0stks 0ps~ ............... -P ................................ ~ ................ ~ ................................. '1 ~ 2stks 101asi ~ ~ 2stks 150 psi ............... - ......................... [- ......~ ................ ~ ................................. ., .................. ?...s.!.k..s. ..... !S..O..R.?.i...i .................... .4..?!k..s' ....... ..~..s.O..p.?j_.j,,' ................. !O..~!.k.~ ..... ~.S...P.?i..j ................. 3A~!.k..s. ..... · i 14stks 395psl j .................. !S...s.t..k..s. ..... .4..o..o..R.s!..j .................. ~ A .s.t..k.?. .... .3_.9..!.p..sl.j 20 stks 378 z~si i 22 stks 369 psi i ................. ._2.4...s.t..k..s. .... .3.Z.4...p..s!.j .................. .2..S...s.t..k..s. ..... .3..S..l_.p_.s!.j .................. .2..e_s.t_k..s. ..... .3..4..3...p..s!.j ................. .3__O_._s.!.k..s. .... A3..4...p..sl..j 32 stks 330 psi i .................. ~..s.!.k..s. ..... ~.!..p..sl.j 36 stks 325 psi j ................... i'~'$iJ~i; ..... §i'Y~;~i'" i i ............................................... T · ~! 405lk$, 317~$1 i ............... ~ .............. -I- ......... ~-- ..... ............... ," ...4&.s.!.k..s.. ± .. AI.~ ..P..S.i._ j 10 stks 900 psi i ................... i-~"ii'~ .... 'i;i-[ii~-'~'ii~-~----- ................... !.4.?..t.k.?. .... J,~.O...P.S.L 16 stks 1,475psi i ................... .1..e..s..t.k..s. .... j.,Z.o..o...p, sj.j ................... .~..O..sj.k..s. .... j:.9_!.o.~.sj,i ................... .2.Ls..t.k..s' .... .2.:.o..o..o...p.s..i.; ! ! ! SHUT IN TIME SHUT IN PRESSURE ,...o_..9...m. Ln. .................... ..~:.o..o..o_._Rs_!.~ ................ 3:.o..o..o.~.~ ................................................. j ...l...°...m.!.n... 44 stks , 317 psi ,..2....0...m.l.n' .................... .2..,.0..0..0...p.s..,. !..s.,..uz :.,.~:.M.? ,.L ............. .s..,.u.~:.,..,..,~ .s.s..u.., E ...3...9...m.!.n' ................... .2.:.O..O.9..Rs.Lj ....0:.0....m.i..n. ................... ..3jZ. R.Sj .... __..l:.O._..m.i..n. ................... .3..1..o..p..s!_' ..__~:.o._..mj..n_ ..................... .3..o..7..R.s!_ 3.0 min _ 303 psi ............... 'T' .............. ..I. ................ 4.0 min i 299 psi 5,0min = ~ 295 psi ............... · 1- .............."1- ................ · i i · I .Omen ~ j 290ps~ : ._.7:.O....m.i..n._ i ................ L .2..9. ?...p..s.i.... 8.0min i i 288 psi l __.9:.O._..m_i__n__.L ............... (...2..S..S..R.s..i... _.4.:.o...m.!.n- .................... .2..,.o..o..o...p. sj..j ....5....o...m.!.n' .................... .2..,.o..o.?...p?j. j ....6...9___m.!.n. .................... _2.,.o..o..o...p?jj ,..Z...o...m.!.n. .................... .2..,.o..o..o...p. sj. j ....8....o...m.!.n- .................... .2..,.o_.o_ .o.R.s..i.; ....9....o...m.!.n' .................... .2. ,.o..o_o...p.s..L., ..!.o.._9._.m. Ln. ................... .2..,.o..o..o. ~.s._i.. ..!.s....o...m. Ln. ................... .2..,.o..o..o...p. sj., 20.0 min. j 2,000 psi i . I I ,, I 25.0 m~nl ~ 2,000as~ ~ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska Drilling Cementing Details Well Name: 2N-347 Report Date: 05/23/2000 Report Number: 7 Rig Name: NM)om 19E AFC No.: AK0054 Field: TARN I Casing Size Hole Diameter:. Angle thru KRU: J Shoe Depth: LC Depth: J % washout: 7-5/8" 9-718 72I 421 O' 4122 I ~entralizers State type used, intervals covered and spacing Comments: *,1 TOTAL BOW TYPE, JTS 1-12. EVERY 3RD JT TO SURFACE. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.2 25 15 VIS 47 AFTER CONDrrlONING. Gels before: Gels after: Total Volume Circulated: 4/7 3+ HOLE VOLUMES I/I/ash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.34 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 40 10.2 · · Lead c~ment' 0 · : Type: Mix wtr tamp: No. of Sacks: Weight: Yield: Comments:.. ' '.: ': AS M LW 75 410 10.7 4.44 :... .. . . . . . " ' '. :' .' .' Additives: :' ' ' i"' .... .::..' i:.. '::' .:' ;' ..: '.' ·... G WIS0%D124, 9%D44, .4%D46, 30%D53,1.5%S1,1.5%D79 ~,',l::'C,~"t'.' :i!O:. :.':' 'i'.:." i. ':.;: ' '. ": · Type: Mixwtr tamp: I Ne. of Sacks: Weight: I Yield: ~orrih~:ents... . .:'i.. ..... ..'~.' ':..i:.' '...i .:: .....'"'.......il...". G 75 240 15.8 1.17 .':. '.::.i':. '! .:.:i':: '::'::i :i[.'i::. i.: :.i.' i:..: ?'i:' :[ .::':' :::: !:. Additives: ..... .: : ':":." '.'". .... ..." ' ' : 'G + 1%S1,.2%D46, .3%D65 I:)l~plaCeinenti:: :0 ':.'::: ' '...' ': .': ;' 'i': Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: C~tnm'en'ts ?.' :: ::;.::':. ": .':'i':. ' . ...? 6-7 4 125 I)ISI~CED :W/MUD WIRIG; i :,' :i.', .: ;i ::'; i: .: .'..~: .~ i:. ;': ?.? i i"i '".:?'". :i;': !' :: :.. Reciprocation length: Reciprocation speed: Str. Wt. Down: '.~ .::.:.'....~.:....:..':.:.: .... : 15 1/MINUTE 55 i~ :. ::'..i::L.:..i.:: :i .i.".': !:i'i::: :!" .i.¥.i.¥...::':. :. :..::.' :;:.. Theoretical Displacement: Actual Displacement: Str. Wt. in mud: . '.:?~!.'i'~':..i::~':.::.:'i,.:ii!':;.:?i,.i?.,::'.::.,i.i'.:i':.? 1.O--L 491 ~alculated top of cement: CP: Bumped plug: Floats held: GOOD CEMENT TO SURFACE- 30 BBL EXCESS, NO Date:5/23/00 NO YES BROACHING. Time:0200 lemarks: Cement Company: Dowell IRig Contractor: NABORS IApproved By: R.W. SPRINGER Phillips Alaska Drilling Daily Drilling Report AFC No. '1 Date Rpt No I Rig Accept - hfs Days Since Accept/Est: 5.625 / AK0054 105/22/2000 6 105/17/0900 Rig Relase - hrs: Well: 2N-347 Depth (MD/TVD) 4220/2302 Prev Depth MD: 4078 Progress: 142 Contractor:. NABORS Daily Cost $132758 Cum Cost $ 582024 Est Cost To Date $ Rig Name: Nabors 19E Last Csg: 16' O 105' Next Csg: 7-5/8" Shoe Test: ?peration At 0600: R/D DIVERTER SYSTEM. Llpcoming Operations: NIPPLE UP BOPE, TEST BOPE, HOOK UP RIG TO HIGHUNE POWER. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL SPUD I N TST 05/17/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.2ppg 9.875 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 465qc STC N SPACE PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 25/15 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3916 4 / 7 / LX9485 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER 500 6.0 4220 05/22/2000 USED - BBLS HTHPWL TRQBTM DEPTH IN DEPTH IN ..~.....=...,, ,,.,. ,.~l''~i"' POTABLE WATER 100 0mi/30 min 105 i N~JE 0 .'.".. '"" USED- eeLs SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL "= ' ' '." '= ='.' :wEATHER:&.. i.' '''= '= i'"':. '"..i ' 13.0°/o 4115 2N-341 '..'.: :. '.'.': :: ':.".pE~$~:~I~i~I~:!DATA:.:....· :."",.." . HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 10 194bbl 2300 I I I 47.5/25.5 / 2N-347 MBT PUMP NO woe 2 woe 2 RATE (bpm) WIND SPEED 5 20.0 I I 2 I I 10- 20 - 1.5 3h LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 90° 8.0 6 I 6 [ ] 0-100 - 600 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 5.90 107.29% 60 1 60 1 I .SO4 Water Base Muds 300 PiT VOL GPM 2 JETS JETS Fresh Water PHILLIPS 1 460 5091 I I lO 1 lS 1 lS 1151 I I I I I I lOO PERSONNEL Diesel 30 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 28 $-8183 III 8214 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $53o87 I I I 416 I WTIA I I I 430 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 BAROID 10.21 I I E 11 I CT ITD I I I 3880 PERSONNEL TOTAL 49 i. ~,:,~:,,~ ;,,:..~,;, :,,~.., .,. ::.., :,: ,..,.,. ,~ ....,.,,~,, ,.,. :,,;: ............... :....1 I:~',~',~i~F~i'~!~i !~!!:!!: ?~ii!i~:;!i'?:?lBIT, NAVIDRILL MACH 1C(1.4 deg AKO) XO, NM DCLR, MWD, FLOAT SUB, NM STAB, 3 NM DCLR, XO, 4 HWDP, JARS, 24 HWDP, i~i~,'!~ ~. ::.!~.~i':; i!'! ~!i :~;ii¥:;:;,i i[i:'ii'?:~! ~ O . .:,.: .: ~..:: ,.:.:,~:~.., ,...~. ,.~.~ .,.,.:..... ....... ~ ~.:;,.:.~. :::; .,.. ,~::[X BHA NO I ;:! !.'.i:;';',i;i:ODii.':i,.!:!:;ii:;.i !:*:';:!i**'::;:i::,'ii!l~ii:i :': .'.'iPZ: i . :!:'Z i;;~t/E '~i i..z::i: i z ii"i~3~DE': i' :i;i . ~;~l~l~i~C~Ol~.':'! ~: i.i ::.'(~ j~... '::. :; ' :"~!~N~H.:'..: z' BHA LENGTH 1069.43 4 3.344 14.0 S-135 4" F.H. DATE LAST INSPECTED: HOURS ON JARS: ' '.?;~:;'::, .;Z!ZJ.":'i:ili;':~'~::!'.Z:.:'~!: i,.:':':;.:.:!!~:HD~;I~;~';".::*... ::I:..".":~I~:.C'ODE i.:.!i~:l.~:*;::~;!.B'O~;Si~~ ... ".:'l:*aAe~ oP~,,.': :.<: :.;I.."" '"' '.'" .:' "' O~E'R~I'0'~S FROM;~0~3..~ 0{j{~O":' ;.'".:..;i:.'Z;.:;:.i:':,'.}?,':::'.:,. *::::' 12:00 AM 02:30 AM 2.50 DRIL SURF Making Hole DRLD F/4078-4220', ART.5 HR. 02:30 AM 03:30 AM 1.00 CIRC SURF Making Hole PUMP HIGH & LOW SWEEPS, CIRC HOLE CLEAN. 03:30 AM 04:30 AM 1.00 WIPERTRP SURF WlperTrlp POH TO 3023', NO HOLE PROBLEMS. 04:30 AM 05:00 AM 0.50 WIPERTRP SURF WlperTrlp RIH, NO FILl 05:00 AM 07:00 AM 2.00 CIRC SURF Other CIRC & CONDITION HOLE, DROP SINGLE SHOT SURVEY. 07:00 AM 09:00 AM 2.00 TRIP_OUT SURF Casing and PUMP DRY JOB, POH SLM. Cementing 09:00 AM 11:30 AM 2.50 BHA SURF Other LAY DOWN BHA. 11:30 AM 01:00 PM 1.50 CASG SURF Casing and CLEAN UP RIG FLOOR & RIG UP GBR CASING Daily Drilling Report: 2N-347 05/22/2000 Page 1 01:00 PM 07:30 PM 6.50 CASG 07:30 PM 08:30 PM 1.00 CIRC 00:30 PM 10:30 PM 2.00 CIRC 10:30 PM 12:00 AM 1,50 CEMENT 24.00 SURF SURF SURF SURF Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing EQUIPMENT. PJSMRUN CASING. NO PROBLEMS RUNNING CSG TO BO'Fi'OM. MAKE UP LANDING JTCEMENTING HEADESTABLISH CIRC. CIRCULATE HOLECONDITION MUDRECIPROCATE PIPE. CIRC 3+ HOLE VOLUMES. PUMP 20 BBL WASH40 BBL SPACER430 SXS LEAD ASIII240 SXS G TAIL. DID NOT BUMP PLUGSFLOATS HELDCMT TO SURFACEFULL RETURNS THROUGHOUT. Supervisor: R.W. SPRINGER Daily Drilling Report: 2N-347 05/22/2000 Page 2 Phillips Alaska Drilling t^FC No.]Date I RptNo I Rig Accept- hrs I Days S,n~ Ac~p~st: 6.626/ AK00.4 105/2~000 17 105/17/0900 I Well: 2N-347 IDepth (MD~D) 4=0~302 ~ Prev Depth MD: 4=0 Contractoc NABORS ]Daily Cost $ ~2~ ~ Cum Cost $ 666228 ig Name: Na~m 19E ~Last Csg: 7~8' ~ 4210' ~ Ne~ Csg: 5-1~ X ~1~ ~ration At 0600: DRILLING CEME~ pcoming Operations: CHANGEO~ MUD. PERFORM LO.T., POH FIDRI~ING BHA Daily Drilling Report IRig Relase - hrs: Progress: 0 Est Cost To Date $ Shoe Test: MUD DATA DRILLING DATA ' BIT DATA EH&S DRILLS/BOP DATA MUD TYPE SPUD WEIGHT 9.6ppg VISCOSITY 38sqc PV/YP 14/6 GELS /3/ APl WL HTHP WL mi/30 rain SOLIDS % HOLE VOLUME 174bbl MBT DEPTH BIT NO. 2 BIT NO. ROT WT SIZE SIZE 6.75 PU WT MAKE SO WT AVG DRAG MAX DRAG MAKE STC TYPE TYPE SERIAL NO SERIAL NO LX9705 DEPTH OUT DEPTHIN TRQ BTM DEPTH OUT DEPTHIN ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG 05/23/2000 LAST BOP/DIVERT TST 05/23/2000 LAST BOP/DRILL 05/23/200 LAST H2S DRILL LAST FIRE DRILL LAST CONFINED LAST SPILL DRILL SPACE FUEL & WATER FUEL USED :3968 DRILL WATER 375 USED - BBLS 100 . . ' :' · POTABLE WATER .. ".?,iii~l;jE~iON'. .' "' USED- BBLS i'"' ":' . ' ': "...WEA;rRER'&::" .' .'::::P~R~:.~L:..~^. i'.;" :.' "';:.;. ' ' LGS % PIT VOL 5O DALLY MUD ;500 TOTAL MUD ;53587 COMPANY BAROID TRQ OFF PUMP PRES 2300111 PUMP NO 1211 LINER SZ 61611 SPM 1 6016011 GPM 2 6891 I I SPS1 III 422O FOOTAGE 0 ADT/AST I WOB 2 RPM 1 TFA JETS lS1161161 I I BIT COST 4209 FOOTAGE ADT/AST / WOB 2 RPM 1 TFA JETS BIT COST SPP 1 DULL DULL III III III MUD WT lO.21 I I GRADE III GRADE III INJECTION WELL 2N-341 SOURCE WELL 2N-347 RATE (bpi) 3 PRESSURE (psi) 800 INJECTION FLUIDS Water Base Muds 1350 Fresh Water 100 Diesel 30 0 0 TOTAL VOL (bbl) 1480 'rOT FOR WELL (bbl) 5360 TEMP °F 10 WIND SPEED 5 WIND DIRECTION 45° CHILL FACTOR °F 5.90 PHILLIPS 1 PERSONNEL CONTRACTOR 28 PERSONNEL MISC PERSONNEL 6 SERVICE 11 PERSONNEL TOTAL 46 sit SUB, NM COMPR DP, XO, 4 HWDP, JARS, 24 HWDP, XO BHA LENGTH I 978.5 4 3.344 14.0 S-135 4" F.H. DATE LAST INSPECTED: HOURS ON JARS: ~',~.:':':,'i~'~ :~.'.~,1~;:.::.:~:,:~,~:..;;::,~.~,1~? ;: :,,:.::~u~..:..?,:..:~,. :,::.1;,:~:.,,.:~,~.~¢~'.~ ~,:~::~1~:.:,.~:~:~'~,~.~.~. ::,..:.',:.. i,.~',,.xs~,,~>s: .:...;.:,.:....~,'..::.~?1.~,,.: .. ~.:'.;..:.:.~...:.,:~,::~:..'.: ??~'>En~IO~S'~,:~'=':O~:~.'. t '~: ~:~. ::~: :"~ 12:00 AM 01:00 AM 1.00 CMT_CSG SURF Casing and Cementing 01:00 AM 02:30 AM 1.50 CASG SURF Other 02:30 AM 07:00 AM 4.50 BOPE SURF Casing and Cementing 07:00 AM 09:00 AM 2.00 NU_ND SURF Other 09:00 AM 01:00 PM 4.00 NIl_ND SURF Other 01:00 PM 05:00 PM 4.00 BOPE PROD Evaluation DISPLACE CEMENT W/RIG PUMPS TO CALC AMOUNT PLUS TWO BBL, DID NOT BUMP PLUGS, FLOATS HELD, CIP ~0045 HR. CLEAN EQUIPMENT, R/D CEMENTHEAD & CASING EQUIPMENT, FLUSH FLOWUNE. PJD DIVERTER SYSTEM, SERVICE KNIFE VALVE. NIPPLE UP SPEED HEAD & TBG SPOOL. TEST SEAL. N/U BOP'S, CHOKE & KILL UNE, INSTALL MOUSE HOLE & PAJ TOOLS. M/U TEST JT AND INSTALL TEST PLUG. TEST BOP'S, CHOKE MANIFOLD, KILL LINE, KELLY Daily Drilling Report: 2N-347 05/23/2000 Page 1 05:00 PM 06:00 PM 1.00 OTHER 06:00 PM 07:00 PM 1.00 OTHER 07:00 PM 08:30 PM 1.60 BHA 08:30 PM 09:30 PM 1.00 RIGS 09:30 PM 10:30 PM 1.00 OTHER 10:30 PM 12:00 AM 1.50 OTHER 24.00 PROD PROD PROD PROD PROD PROD Other Other Other Other Other Other VALVES, FLOOR VALVES TO 250/3000 PSI, VALVE #13 IN CHOKE MANIFOLD FAILED- WITNESSED BY GRIMALDI, AOGCC. STAND KELLY BACK & BLOW DOWN UNE. INSTALL WEAR RING, BLOWDOWN CHOKE MANIFOLD, CLEAR RIG FLOOR. M/U BHA & RIHTO 1050'. CUT & SUP DRILLING UNE-ADJUST BRAKES- CHANGE OUT VALVE IN CHOKE MANIFOLD. RIH TO 3156'-TRIP DRILL 2MIN-36 SEC. PJSM-HELD MEETING ON STRIPPING IN HOLE CONDUCTED STRIPPING EXERCISE. Supervisor: R.W. SPRINGER Daily Drilling Report: 2N-347 05/23/2000 Page 2 Casing Detail 7-5/8" surface casing # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH - _ Nabors 19E RT to GL = 34.50' TOPS Above RKB 4.54 7 5/8*' ~.anding Joint (38.97 total) 34.50 4.54 - 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.45 39.04 its.78-101 7 5/8", 29.7#, L-80 BTC-MOD 982.41 41.49 Tam Port Collar 2.47 1023.90 jts 3-77 7 5/8", 29.7#, L-80 BTC-MOD 3096.50 1026.37- =., Gemeco Float Collar 1.34 4122.87 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 85.05 4124.21 Geme..co Float Shoe 1.50 4209.26 BTM OF SHOE @ ..... >>>>> 4210.76 .., ,,, TD of 9 7/8" hole = 4220'MD '. .. 41 TOTAL, Gemeco Bow spring Centralizers , 3, Centralizers in center of its. 2, 77 and 78 over stop collars S8 ,Centralizers over collars of its. 1, 3-12, 15, 18, 21, 24, 27, 30, 33 ~6, 39, 42, 45, 48, 51,54, 57' 60, 63, 66,.69, 72, 75,81, 84, 87, 90, 93 ., 96 , , · , . =. , ., , . . , . . ,,. Remarks: String Weights with Blocks: 125k Up, 55k Dn, .18k Blocks. Ran .101 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections. Three joints surplus including, one jt that' did not drift. ., WELL: 2N-347 PHILLIPS Alaska, Inc. DATE: 5/22/00 1 OF 1 PAGES STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Alter casing _ Change approved program __ Suspend_ .Operation Shutdown__ Re-enter suspended well_ Repair well _ Plugging __ Time extension _ Stimulate _ Pull tubing m Variance ~ Perforate_ Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory _ Strafigraphic _ Service 4. Location of well at surface 129' FNL, 1055' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 1211' FNL, 374' FEL, Sec. 5, T9N, R7E, UM At effective depth At total deplh 1233' FNL, 667' FEL, Sec. 5, T9N, R7E, UM 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) tree vertical Casing Structural Conductor Surface Intermediate Production Uner feet Plugs (measured) None feet feet Junk (measured) feet Length Size Cemented 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name K..U...P. aruk'R~ Unit ? 'Well numbe/ 2N-341.. '/ 9. P.enfiiJ,~umber -~8-~ 10. APl number 50-103-20263 11. Field/Pool Kuparuk River/Tam Pool Annular Injection feet Measured depth True vertical depth' Perforation dep~: measured NONE true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured dePth) r"l kl A I' RECEIVED 13. Attachments Description summary of proposal m Detailed operation program BOP sketch · Contact James Trantham at 265-6434 with any questions. LOT test, surface cement details and casing detail sheets ;X Suspended __ 14. Estimated date for commencing operation 15. Status of well classification es: .July 1998 Oil ~ Gas_ 16. If propOsal wes verbally approved Name of approver Date approved Service ~ 17. I hereby cmtily that the foregoing is true and correct to the best of my knowledge. Signed ~'"/-'~°-~,~,L~/v'~ ~~_ . Title Kuparuk Drilling Team Leader Date . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No~x-,,'/9 t~:)C",~l Plug integrity_ BOP~T, ss~---.....Locafion clearance .--. ___ ~. ,.,, ,,,., I Mechanical Integn ~ ~ · Approved by the order of the Com~~--~~--"~~~/~ ~'~,.., . Commi-eeioner ......... Dat, ~'~j~'l'~'//~ea. _ Form 10-403 Rev 06/15/88 ~~. SUBMIT IN TRIPLICATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-341 Supervisor: D.BURLEY Date: 6/27/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 8.5 PP9 Hole Depth: 2,311' TVD 7 5/8", 29.7 ppf, L-80, BTC 4,227' TMD 2,301' TVD EMW = Leak-off Press. + MW 0.052 x TVD 900 psi 8.5 ppg EMW=16.0 ppg LOT = (0.052 x 2,311') Fluid Pumped = 1.9 bbl Pump output = 0.1000 bps 3.000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,5O0 psi 2,400 psi 2,300 mi 2,200 mi 2,100 psi 2,(X)O psi 1,900 psi !,700 psi 1.600 psi 1.500 psi 1.400 psi 1,200 psi 1,100 psi 1,000 psi ~00 psi 80O psi 700 psi 60O psi 200 psi 100 psi 0 psi 0stks 2SlkS 4stks 6stl~ 8st~ 10 LEAK-OFF TEST --I~-CASING TEST 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 stksstksstksstksstksstksstksstkssl~ stksstksstksstksstksstks STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ! ............................ .q._s.L~.s. ..... i ...... .q_p_s.L ....... ........................... !._s_t..k.s. ..... i ..... .5.9_R.sj. ..... 2stks i 180psi ........................... .3_..s.t..k.s. ..... $ .... .2_.4_o_.R._s.! .... ~ ........................... .4.._s_t..k.s_ ..... ~ .... .3.9.o_.p._s! .... ............................ .5_..s!_k.s. ..... i .... .5..3_o_.R.s.l .... ........................... -6--s!-k.s- ..... i .... -6-.5-9-P-S! .... , , 7 stks !]. 790 Esi ............................ ~..s.t.k.s. ..... i .... .9_o_o_p..s! ..... .... ~ .-_9...m. Ln. .......... J..O.__s&k.s. .... ~ .... .8. ~ .O_.~...s.L .... 2.0min 11stks J 840 psi .... ._3..p_.mj.n_ .......... !.2...s!_k.s. .... i .... .8_2..o..R.s.L .... 4.0 min 13 stks i 810 Esi ..... .5_.._o...mj.n. .......... !.4.._s_t..k.s. .... i .... .8_O..O_.p._s! .... .... .6_..9...mj.n. .......... .1..5.._s. Lk.s. .... ,~ .... Z.9_.o..R.s.i .... ..... .7.:_.o_..mj.n. .......... .1..C.s. Lk.s. .... i .... .7..9_.o..R.s.L .... .... _8.:_o...mj.n. .......... 1Z..s. Lk.s. .... ~ .... Z.9_.o_.R.s.L .... ..... .9.:..o...m.!.n_ .......... .1..8_s. Lk_s. .... ! .... Z.9..o..R..s.L .... _.l.9:9_m_Ln. ......... !.9..s..tk_s. .... ~ .... Z.9_9.R.s.i. .... .......................................... ,4- 1 } .................... t .................... 'P .................... I I I i ! CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks i 0 psi ] .................... ! .................... i' .............. : .... , 2stks ~ 340pm [ 4stks ~ 640 psi 6 stks ! 920.Rsi ..................... 1 ..... '~%'i~ ..... T"i]66~["i 10stks ~ 1:290 Esi ] .................... 1 ..... .... .................... 1 ..... .... .................... i ..... .... ..... &..o.._.mj .n. .......... ~g ..s.t&s. .... L..J :~Ao.. P..s. Lj 3.0 min 24 stks i 1j940Esi 5.0 min 28 stks ! 1:930 Esi .................... 1 .................... 1 .................. 1 ..... .6.:9..m.j.n. .... 1 ..... .3..o_s. Lk..s. .... ~.._]:9.3..o..~..s.L.4 7.0min . 32stks ~ l~920Esi ] 9.0 min 36 stks i 1:920 Esi .... !o_:.o....mj.n. ......... .3..8...s.t.k..s. .... i...1.2.2..9.E.S.L.j .... !5.:.o..._mj .n. ......... .4..O...s.t.k..s. .... i._] :9.2.9. E.S.[..j 20.0 min 42 stks i 1:920 Esi ::::::::::::::::::::::::::::::::::::::::::::::::::::: 30.0min 46stks i 1:920 Esi ~ .................... i .................... r ................... i ! ! I I ! .................... .................... i' ................... 1 .................... i .................... T ................... CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-341 Supervisor: D. BURLEY Date: 6130198 Casing Size and Description: 7 5/8", 29.7 ppf, L-80, BTC Casing Setting Depth: 4,227' TMD 2,301' TVD Mud Weight: ~.hk~leO~pth: 9.5 PP9 EMW = Leak-off Press. + MW 0.052 x TVD LOT = 1,170 psi + 9.5 ppg EMW=I,~8'I~g (0.052 x Fluid Pumped = 6.6 bbl Pump output = 0.1000 bps · · [ I..=~..- LEAK-OFF TEST . ~ t i~CASING TEST 0 2 4 6 8 10121416182022242628303234363840424446485052545658606264666870 slk stk stk stk stk stk stk slk stk stk stk stk stk stk s'lk stk stk stk stk stk stk stk stk stk stk sfk stk stk stk stk stk stk stk stk stk stk S S $ $ $ S S $ $ S S $ S $ $ S S $ $ $ $ $ S $ $ $ S S $ S $ S $ S $ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ............................ .O.._s.t_.k.s_ ............ .O..E.s.i' ....... ............................ .4_..s.t.k.s. .......... ~.O..D._s.i_ .... ............................ .e...s.t..k.s_ ........... ~.5_o..p..sj_ ..... ........................... _l._2.__s_Lk_s_ ......... _6_1_.o..R.s! .... ........................... !.6...s!.~.s. ......... Z~.O...P..~.i. .... ........................... .2.9..s!_k.s. ......... 9-2_9.D.sj. .... ........................... 2..4_s_t.k_s. ........ 1._,..o.9..9_.p..s_ L .. ........................... .2.6...s..t.k..s. ........ 1..dZO..D.s.L_ ........................... .2__8...s_t..k.s_ .......... .6_1_ .O_ . D _s! .... ........................... .3._4...s.t..k.s. ......... .4_1.9.P..s! ..... ........................... .4_9..s.t..k.s. .......... .4..1.9.p..sj. .... ........................... .4.9.s_t.k_s. ......... .4_0.9.E..s! ..... ........................... ~..s.t.k.s. ......... Ag_9..D..sj_ .... .................... ~ ..... [[--~--~] .......... .3..9.9.~..Sjl .... .... .1....o....m. iD .......... .s.Z..s_t._k.s. ......... .S_~.O_.D..sj_ .... .... ..2_..O__._m.]p_ .......... .S._8...s_t..k.s. .......... .S.~.O..p..sj. .... ..... A.A._re.]P_ .......... .S_.9...s.t.~ ......... DJ_.O._D..s.i_ .... .... ?_:.O....m.]p_ .......... .6..O...~.t..k.s. ......... ~ J..O_.D._sj. .... ..... .s_...o....m._in .......... .63...~.Lk.s. ......... A!.o_.D._s.i. .... .... .6._..9..mid .... , ..... .6.~..s.t..k.s. .......... D.!.o..D...s.L .... .... Z._o__m.!p_ .......... .6..s._.s.t..k.s. .......... D.o..o..D..s.L .... 8.0 min 64 stks 300 g. si .... A..O._m._ir! .... , ..... .6..s...s.t..k.s. .......... ~.o_.o..p..s.l .... .... !o._._9_.m_j_n.._.: ..... ~D__s.t.Ks. .... ,.,. .... .3..o_.9.u.sj. .... .................... i .................... -i- .................... ' .................... 1 .................... ,'I' .................... .....................11 .................... -~-I .................... ..................... I .................... T .................... ! ! .i .4. ~ .................... I .................... ,"I" .................... I I f ....................I .................... ~, .................... I I I r ....................I .................... T .................... { ....................i .................... % .................... i i i [ .................... J .................... J- .................... CASING TEST DATA MINUTES FOR CSGTEST STROKES PRESSURE ..................... i ...... .O...s.t~.s. ..... i ...... .°3..si. ...... ..................... j ..... .-2...s.t~.s. ..... i .... .3.~.o.~..sj. .... { 4stks { 640 Es{ ..................... i ...... .6...s.tk..s. ..... i .... .9..2..o.~..sj ..... i 8stks ! 1,100 Dsi .................... t .................... -I ............. ' ....... i 10stks i 1~290p. si .................... j ..... .t~._s.~.s. .... i..2,.8.~.o._p..s.[._. ..................... l ..... !.7...s!k..s. .... ;...2..,.o..o..o...p..s.[..j .... !.P...m. Ln. .... j ..... -2..o...s. tk..s. .... L..!,.9..8_9.D.s.L.. 2.0min : 22stks i 1,960psi i .... .3....o_...m.!.n. .... i ..... .2..4...s.t.k..s. .... L!,.9_4--°..D-s-L.. .... .4...o....m. Ln. .... i ..... .2..8...s.t.k..s. .... ~....1.,.9..4..o..p.s.L.. ..... .5....o....m.!.n. .... i ..... .2..8_..s.t.k..s. .... L..1.,9..3..9.p..s.L.. 6.0min i 30stks ..... .8...9...re. iD .... { ..... ~.4_..s.t%s_ .... i..$.~.o..~..s.L.j ..... 8...9. .m_ Ln. .... { ..... .3..6...s.t.k..s. .... L..l.,9_2_o..D.s.L.i _.l_O....o...m. Ln....j ..... .3..8_..s. tk.~ .... LI.~A2..o..~.~[... 15.0min i 40stks .... .2..o_;.o._m!.n....j ..... .4..2...s.t.k_s. .... L-~*9--2-°--P-s-L. 25.0min i 44stks ~ 1~.920Esi ," ....i ..... ii'ii'ii .... ..................... 1 .................... T ................. 'i ..................... i .................... ! ..................... 1 .................... t ................... :,' I I ..................... i .................... f ................... :,' I I I ~ .................... I .................... .L ................... J r .................... I .................... T' ................... ,4t ARCO Alaska, Inc. Cementing Details Well Name: 2N-~41 Report Date: 06r26/~ Report Numbec 5 Rig Name: IX}YON 14t AFC No.: AK 9469 Fie! .............. rlJl~, I Jill casing S~e Heie Diameter. I Angle t~m KRU:I Shoe Der~: LC Dep~: 7 5/~' 9 7/8' 4227' 4101' I I Cehbaiizers State type used, intervels covered end spacing Commem: (42) 9 7/8" x 7 5/8" Gemeco be~v spring, placement detail on casing talley. ,, Mud Weight PV(prior cond): PV(after cond): YP(pdor cone'): YP(alter cone'): Comments: 10,1 26 21 20 t5 Gels before: Gels site: Total Volume Ci~culatad; __ 8/22 4/9 930 bbls 1 693bbls Wash 0 Type: Volume: Weight Comments: Spaoer 0 Type: Volume: Weight Comments: ARCO ~0 bble I ~0 bbls t0.5 ppg 1st stags 1 2nd stage , ,, Lead Cement 0 Type: Mix wfl' temp: No, of Sacks: Weight: Yield: Comments: AS III LW 65 1301402 10.5 ppg 4.42 1st stage 1 2nd stags Additives: , T~II Cement I~' Type: Mix wtr tamp: No. of Sacks: I Weight: Yield: Comments: 70 240 160I 15.8 115.9 t.t7 1 0.93 t st stage G cntt i 2nd stags AS1 cmt Additives: . t% St, 0.3% D65, 0.2% D46 III AS1 standard blend Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): SIT, Wt. Up: Comments: 8 9 95 , 1st stage I ?.nd stags Reciprocation length: Reciprocation speed: Str. Wt. Down: 15 30 fpm 55 Theoretical Displacement: Actual Displecemen'c Str. Wt. in mud: 193.$11"3.4 193.7 174,2 85 ' , , , , Calculat~l top of cement: I CP: Bumped plug: I Floats held: Surface thru stage collar ~ t598'.I Date:6/25/98 yes lyesI yes lyes Time:1201hrs 1 t505 hrs Remarks:Stage t: Pure pad 5 bbls water, 30 bbls of 10.5 ppg spacer, 10~ bbta of AS3 Iito st 10.5 ppg and 50 bbls of G cmt at t5.8 ppg. Displaced ',lth ~0 bbls of water, 75 bbls of t0.t ppg mud, 30 bbls of t0.5 ppg spacer and 55.7 bbls of t0.t ppg mud. Reclprocet~l ceslng untlll last 55 bbls of displacement, had.full returns .while ein:ulating and cementing. , Stage 2: Pumped 5 bbls of water, 30 bbls of t0.5 ppg spacer, 3t6 bbls Of AS3 lite and t0 bbls of AS1 cement. Displaced withe0 bbls of water and 44.2 bbls of 10.1 ppg mud. Had full returns while circulating and cementing wittt 93 bbls of t0.5 ppg cement back at surfaco. Cement Company: Rig Contractor: JApproved By: ' IX)YON J D.BURLEY ARCO Alaska, Inc. Casing Detail 7-5/8" Surface Casing WELL: TARN 2N-341 DATE: 6/24/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to Pad = 30.00' TOPS Above RKB 7 5/8" Landing Joint 34' OA. 30.00 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.75 30.00 its. 63-99 7 5/8", 29.7#, L-80 BTC-MOD 1522.80 32.75 Lock B 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) JT. #79 42.98 1555.55 2.80 1598.53 Lock A its. 3-62 its 1-2 Gemeco 7 5/8" Stage Collar (BAKERLOtg 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) JT. #105 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top of jr #3, BAKEI Gemeco Float Collar 7 5/8", 29.7#, L-80 BTC-MOD 42.92 1601.33 2498.98 1644.25 1.35 4143.23 and over casing collars on Jts. 3 thru 15 and over collars of its. 18,21,24,27,30,36,39,42,45,48,51,54,57,60, 66, 69, 72, 75, 78, 81 84,87,90,93,96.' Joints 100-104 (5 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 95K# Up, 55K# Dn, 20k# Blocks. Ran 10 joints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: D.P. BURLEY 42 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2, 105, 106 over stop collars 81.07 4144.58 Gemeco FloatShoe 1.42 4225.65 4227.07 Insefl baffle @ 4101'. Re: 2N 332 Plug Back - - - Permit To Drill #200-079 Subject: Date: From: Organization: To: CC: Re: 2N 332 Plug Back - - - Permit To Drill #200-079 Wed, 21 Jun 2000 15:26:44 -0800 Blair Wondzell <blair_wondzell~admin.state.ak.us> State of Alaska, Dept of Admin, Oil & Gas Tom J Brassfield <TBRASS~ppco.com> Chip Alvord <CALVORD~ppeo.com>, "Randy L. Thomas" <RLTHOMAS~ppco.com>, Nabors 19E Company Man <NABORSCM~ppco.com>, Tom Maunder <tom_maunder~admin. state, ak.us> Tom, Thanks for the data. These problems and your proposed solution fall within the "drilling problems" covered in the regulations. As such, you have our approval to proceed as outlined below. Thanks, Blair Wondzell, 6/21/00. Tom J Brassfield wrote: > Blair, per our telephone conversation today we are proposing to plug back the > current wellbore and redrill approximately 2633' of hole due to hole angles > exceeding 79 deg. The details are as follows: > Surface casing has been set and cemented at 3907' MD~2310, TVD. > Drilled to current TD at 8683' MD~3710' TVD with some directional > inconsistencies due to learning curve with new style 6-1/2"x7-1/2, bi - cent er > bit. Hole angle exceeded 79 deg in two areas and we feel that this is not a > useable wellbore for the life of the Tarn field. Planned tangent angle was 72 > deg. > No significant hydrocarbon zones have been penetrated. The top of the Bermuda > is estimated at 11365' MD/4863 ' TVD. > Plan on spotting a hi visc pill from approx. 6782' MD to 6416' MD and setting > an open hole cement kick-off plug from 6416' to 6050' MD. > Kick-off low side of the plug and drill wellbore as originally planned. > Thanks, Tom Iofl 6/21/00 3:28 PM Phillips Alaska Drilling Daily Drilling Report AFC No. I Date Rpt No I Rig Accept - hrs . Days Since Accept/Est: 4.75 / - AK0055 106/14/2000 6 106/10/0600 Rig Relase - hrs: _ Well: 2N-332 Depth (MD/~/D) 3917/2290 Prey Depth MD: 3917 Progress: 0 Contractor:. NABORS Daily Cost $115790 Cum Cost $ 596245 Est Cost To Date $ - Rig Name: Nat)om 19E Last Csg: 7-5/8 O 3907' Next Csg: 5-1/2 X 3-1/2" Shoe Test: - _ 3peration At 0600: DRIllING CEMENT & FLOAT SHOE. Llpcoming Operations: PERFORM LO.T., POH F/DRLG ASSY, RIH, SWAP MUD & DRILL AHEAD. - MUD DATA DRILENG DATA BIT DATA EH&S DR!! ! -__~BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL - LSND I 2RR1 N TST 06/14/2000 WEIGHT 'ROT WT SIZE SiZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.3ppg 9.875 6.75 06/08/2000 VISCOSITY ,PM WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 475qc HTC STC N SPACE 06/12/2000 D6/14/2000 PV/YP SO w'r' TYPE TYPE TYPE FUEL & WATER 19 / 14 MXC1 XR GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 2238 2 / 6 / FSOZS I.XP705 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER 266 6.5 3917 I)6/14/2000 USED- BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN "· : ' . '.' ' .. ' """ POTABLE WATER 100 0mi/30 Tin 113 3820 =i:". iNJECTiON..'..'ii.' .' USED-BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL :'" ', .:. '.:':..'i'.. ::WEATHER:&;':,.:.;.. ".5% 3804 97 :~N-341 '.. '..".,.'"." .:'ii~E~'~6N.~'i~L::i~AT~:· .':'. ...... '... HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 30 163bbl III 24.25/4.5 / 2N-332 MBT PUMP NO woe 2 WOB 2 RATE (bpm) I/VlND SPEED 5 15.0 I I 2 I I 10- 25 1.5 )h LINER SZ RPM 1 RPM 1 PRESSURE (psi) ~/IND DIRECTION 45° 9.0 6161 I o- 8o Boo LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F 26.91 37.58% III INater Base Muds PIT VOL GPM 2 JETS JETS Fresh Water PHILLIPS 1 10 I I I 101 151 151 151 I 151 151 151 I I ~oo PERSONNEL Diesel 25 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 ;21144 III 8747 0 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL a ;67169 III 2131WTIA III 925 COMPANY MUD WT GRADE GRADE TOT FOR WELL (bbl) SERVICE 17 BAROID I I I E II I ER I TD I I I 11795 PERSONNEL TOTAL 53 I:~.~.'.;;~;;"--'";;~.~A:.':'~" ?~:;'~;..'.,[~.~;,:.~:A';: :~:.~.':;;;. ::~.~:;..~:L -- BIT SUB 3 NM COMPR DP,XO,4 HWDP,JARS, 24 HWDP, XO BNA NO 2 ;::}.?:i:i:!;:iiii~i:!'?:.:'!';:~::..:'.:: ?::?::.'.';.;i~ ?,;'?,'::,.'i.;?::: :.'::i:,!;i::~,i~i~i~?:::.:;'::;:: :,:.;:::;::.'?~'~E?,.:'::;!i :i;~E~TiO~.;:,i: ~;;!;;::..i::i:,~;!2;i!?,,; !i;i, ;L::.;~i:: :: :.:i//' BNA LENGTH' 978.5 4 3.344 14.0 S-135 4" HT 38 :DATE LAST 4 2.563 28.0 HWDP 4" F.H. INSPECTED: HOURS ON JARS: '::;:",.. ',,,:1:',. :::. :.,:.'... :'17 '.:?,. '.': .:..' :: 12:00 AM 02:30 AM 2.50 CASG SURF Ceeing end CONTINUE RUNNING 7-6/8" CASING, MAJ HANGER AND Cementing LANDING JT, LAND CASING & MAKE UP CEMENTING HEAD. 02:30 AM 04:00 AM 1.50 CIRC SURF Ceslng and CIRC & CONDITION HOLE & WORK PIPE. STAGE UP TO Cementing 6.5 BPM O 500 PSI. 04:00 AM 06:30 AM 2.50 CEMENT SURF Casing and PJSM, TEST UNES, CEMENT W/304 BBL LEAD CMT, $0 Cementing BBL TAIL, DISPLACE W/RIG. FULL RETURNS THROUGHOUT, CEMENT TO SURFACE, DID NOT BUMP PLUGS, FLOATS HELD. CIP ~ 0630 HR 06/14/00. 06:30 AM 08:00 AM 1.50 OTHER SURF Casing and R/D CEMENT EQUIPMENT, L/D LANDING JT, FLUSH Cementing STACK, CLEAN AND FLUSH ALL UNES AND ANNULAR. Daily Drilling Report: 2N-332 06/14/2000 Page 1 ii" 08:00 AM 09:30 AM 1.50 NU_ND 09:30 AM 10:30 AM 1.00 NU_ND 10:30 AM 02:30 PM 4.00 NU_ND 02:30 PM 03:00 PM 0,50 BOPE 03:00 PM 04:00 PM 1,00 OTHER 04:00 PM 07:30 PM 3.50 BOPE 07:30 PM 10:30 PM 3.00 RIGS 10:30 PM 11:30 PM 1.00 BHA 11:30 PM 12:00 AM 0.50 TRIP_IN 24.00 SURF SURF SURF SURF SURF SURF PROD PROD PROD Other Other Other Evaluation Other Evaluation Other Other Trip In N/D DIVERTER. M/U WELLHEAD. N/U BOPE. R/U TO TEST BOPE. UFT DIVERTER F/SUB OVER PRODUCTION FLOW lINE W/APC CRANE & SPOT ON 2N-316. TEST BOPE- TEST HYDRIL TO 250/2500-RAMS TO 3500 PSI-PERFORM KOOMEY TEST-PULL TEST PLUG & INSTAll WEAR BUSHING. WITNESSING WAIVED BY SPAULDING- AOGCC. R/U KELLY SPINNER & HOSES. PICK UP SliCK BHA W/TRICONE TO DRILL CMT & FLOATS. RIH. Supervisor: R.W. SPRINGER Daily Drilling Report: 2N-332 06/14/2000 Page 2 Casing Detail 7-5/8" surface casino WELL: 2N-332 PHILLIPS Alaska, Inc. DATE: 6/13/00 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 19E RT to GL = 34.50' ToPS Above RKB 4.54 7 5/8" Landing Joint (38.97 total) 34.50 4.54 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.50 39.04. jts.70-93 7 5/8~, 29.7#, L-80 BTC-MOD 986.88 41.54 Tam Port Collar 2.47 1028.42 jts 3-69 7 5/8", 29.7#, L-80 BTC-MOD 2789.49 1030.89 Gemeco Float Collar 1.37 3820.38 , jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 83.67 3821.75 Gemeco Float Shoe 1.50 3905.42 BTM OF SHOE @ ..... >>>>> 3906.92 .... , . . TD of 9 7/8" hole = 3917'MD 39 TOTAL, Gemeco Bow Spring Centralizers 3, Centralizers in center of jts. 2, 69 and 70 over stop collars '... ~ ,Centralizers over collars of jts. 1, 3-12, 15, 18, 21, 24, 27, 30, 33 36, 39, 42, 45, 48,'51,54, 57, 60, 63,.66, 72, 75,81, 84, 87, 90 · , ., ,, . , , =~ !. .. , .. ,. . . , . , , . . . , , . · Remarks: String Weights with Blocks: ??? k Up, ?? k Dh, 18k Blocks. Ran 93'joints of. casing. ' Drifted casing with 6. 750' plastic rabbit. Used Best-o-Life ~ thread compound on all connections. Three joints surplus including one jt that did not drift. PHILLIPS AlaSka, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY NIP (51O-511, 0D:4.500) TUBING (0-11307, 0D:3.500, ID:2.992) Gas Lift landrellDummy Valve 1 (3410-3411, 0D:4.725) Gas Uft landrel/Dummy Valve 2 (7208-7209, OD:4.725) Gas Lift landrel/Dummy Valve 3 (9905-9906, 0D:4,725) SLEEVE (11074-11075, 0D:4,500) Gas Lift MandrelNalve 4 (11114-11115, 0D:4,725) {2N-332 NIF (11282-11283, OD:4.500) LINER (11280-12014, 0D:3.500, Wt:9,30) (11600-11630) KRU 2N-332 APh; 501032034000 ._~, ..... Well. Type:: PROD - A n g-le--~-~ -T S: .i -deg _~ ......... ;_____SSSV Ty. pe:, NIPPLE Orig CompletionS7/6/00 .... A~T._D: ~_~52 deg_(~_1.2.026_ . Annular Fluid: Last W/O:, Rev Reason: Cut paraffin, GLV ! ..................................... ' desig_~_b_y/mO ...... Reference Log: . Ref Log Date:. , Last .Update:,3124101 '~ ....... _Las__t__Ta'g:-~'~;~4'~' ................................ TD: 12026 ffKB ................................................ ..... _L.a_st .T a_ g_D_a t _ _e: 11/___29/__0_0.. _ ~. ".----~-i _ ~'__M._ax_.H_.o_l_e _A_n_gle: 76~__d._e.g..~. 4__21.8 ................. ---~-~ '-_-'_~ -_~-'~_-..~ -~_~ .i ...'.~-~... i Casing String - ALL ,=__D.e_.s_c_ri~tion ~ .......... CONDUCTOR ~ SURF CASING = _ ._S_iz_e .... ! .... ~_o.p ..... : Bottom ' 'I%/D Wt Grade ! Thread .,_ _!6.00____0... , 0 113 : 113 62.58 . H-40 "WELDED 7.625 I 0 3907 ~ ..... '~-1- ~ ........ 2--§.7--~-'.'" ' ' -~'-8---~ ...... -B~'~l~l- .... PROD CASING I 5.500 , 0 11280 ' 4852 ' 15,50 ' L-80 i LTCM LINER I 3.500 r 11280 12014 I 5243 9.30 ~ L-80~ EUE 8RD i Tubing String - ALL Size i Top. _~ Bottom ' TVD _. Wt , Grade I Thread ........ 3.50----0 ........... ~- ......... -~ ........ L 11307 I 4865 9.30 I L-a0 ! EUE 8RD Perforations Sum m _a_r,ry. ........ I-~-~'e rval ........ :I~/D' ........... [ '" "'~:~'~-' "-'['~-'B~-~[_P~][' '- ~'~'E~ ..... ['" ~_~-"] ........................ ~-~ ~ ~'~-~-t ............ .1._1_6p_0 11630 _- -5-~b~]-."i.~_~..2.~_"_-.j_'i'.~'~i~.-'.~."~.~'_~_~_..'' ....... I~]~_~.-_i _~..~o.-_o.~'.-.~.~.E.~.-~i...~.[~:~i'~;]~.~_,.-~'_-d_e_~_l~_~!_~g*. Gas Lift Mandrels/Valves I ...... ........ ,...-,..,.,-....,-,..,,,-,.-,..,-.,.,.,..,-,,,,-..,.....,,.,-.-.,..-,,,.-,-....-..,.,.,,-...,...,,,... / / Mfr j ~pe [ ] I / / I / Run |Cmnt '-'i--~'-'R410 215~-]-*~.--~-C~0 .... KBG29--I-~b-- I-- D-D-~---"I--~5--I-¥~¥' "I'-blbS5 "*l'-"-d'--1'-~72-3-/~'" I' ........... ..... 2-'~7208 3362~xa~b-'i;-'~'~'~'*.~i' ~-A M---C-O- r'-"-~-?-"' 1'--~-;~"* ;F-~"¥" 'I"' 0:b~'b'-i'"'"b'""" 1--3~ ¥-"F .... '~-'.L--i9905 42g-7-7~-~-~---~-C---O~.--I~-~-~--iI.-CAMCO L "-~_Y...~__I--~--~-i.I~-I.-~-o-[-'"'i~'-"i--6--~-~0~)-'T ............. Other (plugs, e.-'_q.'*uip.,..etC.), JEWELRY ; ' ' .' . ' . · . . "~-'-~- --~ ~- 5t}9 --- NI~- ...... [~-(~-D-~-J~'I-~-~- ....................................................................................... '-~¥~-~ 4762 '%~'~5~/-E".[-_B.'~J~P~-C-~-~'/~jSI-N'(~-~L-E~E~ ................................................................ -[-'~-1'-3- -~1-~-2 . 4853 .... ~l-P- ......... I b;~i~b-iS~-P-~£-r~ ............................................................................................. :Genb'ral Notes'..::.'.'"': ' · .. ;" ' .'.:.....' . .... :: .i.:'.[.'."=. '.'i'.'.=' ....... '. :=.=' .: ." : .:! '.. . .':: ' ..::; .... '. ' ..... · ..' ................. .: ......... ....:__. ~ ~ .................................................................................. Date Note 11/5/00 Scratched paraffin to 5000' SLM; drifted wl2..8.~g_a, ug_e__.ri_n_g_t_o.~5_0_00'._S_l.M_= ..................................................... 11/29i00 Cut pa_ra_ffi__n.._fr_.o.m__lTS___0'_.t_o_.2_350'__vy..L...M. ................................................................................................... ALASILA OIL AND GAS CONSERVATION CO~IlSSION Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 2N-332 ARCO Alaska, Inc. Permit No: 200-079 Sur Loc: 99'FNL, 924'FEL, Sec. 03, T9N, R7E, UM Btmhole Loc. 2256'FSL, 299'FEL, Sec. 32, T10N, R7E, UM Dear Mr. Alvord: TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 2N-332. Please note that any disposal of fluids generated from this drilling operation which'are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. 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 AA.C 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. 'Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 'Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE CQMMISSION DATED this ~_ ~-ff4 day of May, 2000 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILl. 20 AAC 25.005 la. Type of work: Drill [~ Redrill D I lb. Type of well. Exploratory r-~ Stratigraphic Test r'"] Development Oil [~] Re-entry D Deepen DI Service D Development Gas D Single Zone r~ Multiple Zone [~ ,.~~. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool laska, Inc. ,/~_ RKB 35 feet 3. Address 6. P.~(~L ~rt~ D__esjg~ =j -;~ ~'O7~,, Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 A b~1"~8 'ALK 4309 .,,~'~) Tarn Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 99' FNL, 924' FEL, Sec. 3, TDN, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2142' FSL, 172' FWL, Sec. 33, T10N, R7E, UM 2N 332 #U-630610 At total depth 9. Approximate spud date Amount 2256' FSL, 299' FEL, Sec. 32, T10N, R7E, UM May 26, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 299' @ TD feetI 2N-331 14.2' @ 280' feet 2560 12011 ' MD / 5162 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 250' MD Maximum hole angle 70.22 Maximum surface 1906 psig At total depth (TVD) 2400 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Wei~lht Grade Couplin~l LenCh MD TVD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' 9 cy High Early 9.875" 7.625" 29.7# L-80 BTCM 3772' 35' 35' 3807' 2300' 385 sx AS III L & 240 sx Class G 6.75" 5.5" x 15.5# L-80 LTC Mod 11046' 35' 35' 11081' 4768' 345 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 930' 11081' 4768' 12011' 5162' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) ,.e vertical feet ORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate ~'~%~ "~ '" Production ~ 22 2000 t'. Pertoration depth: measured A~a~ka C~,,!~' ~"~"" "' ', ' , ,~j~ true vertical 20. Attachments Filing fee L~J Property Plat E] BoP Sketch r~l Oiverter Sketch r~ Drilling program r~ Odlling fluid program r'~ Time vs depth plot DRefraction analysis D Seabed report E~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Tom Brassfie/d265-637; Signed .v~l~.~._~.. ~}'~*~ Title: orilling EngineeringSupervisor Date ~"/2-2.~i~0 Chip Alvord PreDared by Tom Commission Use Onl) Permit Number2..~_..~ --~)'7~ I APl .umber / ~)B - ~3 ('¢/~) '--~)I~) I Approval_dat.e~ . I See cover letter 50- ~'-'~;~ ~ ~) Ifor other requirements Conditions o! approval Samples required [~ Yes lZ[. No Mud log required r-] Yes ~ No Hydrogen sulfide measures r-1 Yes J~ No Directional survey required ~] Yes r-1 No .e.u red wo ,ng pressure for BOP. I--I M: I--i E3 I--I 10u:l--I ................. ,., . . ........................................... Other: ORIGINAL SIGNED BY by order of Approved by I'1 T~,,Inr .~rnn, ,nf Commissioner the commission Date '~'""~C;~ ~:~ "~ (~) (.~ ............. Form 10-401 Rev. 12/1/85 · Submit in triplicate ('i Phillips Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N-332 1. Move in and rig up Nabors 19e. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. 4. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface. If cement does not circulate to surface, a Top Job will only be performed after consulting with the AOGCC. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 5. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AA(3 25.030 (0.5 ppg less than the FIT or LOT EMW). 6. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AA(3 25.030(d)(3)(C). 8. Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembl¥~ Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. Set TWC, ND BOPE and install production tree. 12. Secure well. Rig down and move out. 13. Hydrocarbon intervals will be tested after the rig move. Phillips Alaska, Inc. Well Proximity Risks: The nearest well to 2N-332 is 2N-331. The wells are 14" from each other at a depth of 280'. Drillinq Area Risks: The primary risk in the 2N-332 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.5 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is possible lost circulation at approximately 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.0-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well through the reservoir. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Recent information has indicated an the presence of gas migration from the reservoir to a shallower sand interval. Log, tracer, pump-in test, and offest BHPBU evaluations indicate any migration has occurred outside of the wellbore interval and is most likely isolated below the TOC and/or below the Iceberg interval. In the event gas migration has occurred into the Iceberg interval at 4323' TVD, the highest required MW would be 10.7 ppg. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N-332 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, ARCO Alaska, Inc. will submit application for approval of 2N-332 for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the ~¢' '~'.',, ,,.¢;.~.~ ~.~,~. ,~;?,..,.~; ~ ~, f~ o~ ,~% surface casing shoe is estimated by: ['~' Phillips Alaska, Inc. Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 = (12.0 ppg) * (0.052) * (2,300') + 1,500 Max Pressure = 2,935 psi psi psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2'' 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). Phillips Alaska, Inc. (' DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N-332 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 __.10% Drill out to TD 9.0 - 11.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a reservoir pressure of 2400 psi at a target mid-point of 4936' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MAS P=((2400/4936)-0.1 )*4936 MASP=1906 psi Therefore ARCO will test the BOP equipment to 3500 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.49 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.9 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4936'. Target (Midpoint T2 T3) (2400+150)/(0.052'4936)=9.9. . LEAK OFF TEST PROCEDURE Tarn After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2000 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the AAI LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. . Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT 7. At leak off pump 3 bbls of mud into formation prior to shutting down the pump. . Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation, Record initial shut-in pressure, With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered, Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. TJB 5/19/00 o 450 90O 135o 2700 - - . J - V ~o50- 4950 IRKB ELEVATION: 153' 1.50 KOP 4.50 ~7.50 DIS: 3.00 deg per 100 f~ t 10.50 13.50 Begin Build 20.00 28.00 Por~ Collar of Perm~rost 44.45 w Sak 52.1;5 DLS: 4.00 deg per 100 ft 59.87 EOC BQSe WSak 7 5/8 Co--;ng IPHILLIPS Alaska, Inc. Structure: Tam Drill SHo 2N Well: .532 Reid: Tom Development Field l. o4mflon: Norlh Slope, Alaska 283.36 AZIMUTH 9731' (TO TARGET) **~Plane of PropeeaI*,, C80 MAXIMUM ANGLE 70.22 DEG TARGET ANGLE 65 DEG C50 C40 C37 Iceberg Begin Fill Drop irOC~_ ~ 67.42 -~r3.1 T3 ~ Target Mid Bermuda. , i , , , i i i i , i i i i i i i i i i . i . , . , . , , , , . i , , , , , , i . , , ! i i 450 90O 1550 1800 2250 2700 ~150 ,5600 4050 4500 4950 5400 ~ ~ 8750 7200 76,50 8100 8550 9000 9450 9900 10350 Vertical Section (feet) -> Azimuth 28;$.36 with reference 0.00 N, 0.00 E from slot #$32 384O ~80 2880 24OO 1920 144D 0 980 Z 48O 48O TD LOCATION: 2256' ISL. 299' FEL SEC. T32, TION, R7E Structure: Tom Drill Si'Jo ?.H Well: 33,2, Field: Tarn Developmenf F]eld Location: Norlh Slope, AMska 283.36 AZIMUTH 9731' (TO TARGET) ,~,~Plone of ITARGET LOCATION: 2142' FSL, 172' FWL SEC. ~, TION, R7E <- West (feet) 10060 9600 9120 8640 8160 7680 7200 6720 6240 5760 5280 4800 4320 3840 ~60 2860 2400 1920 1440 960 460 0 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 , a a ~ a ~ I f ~ I I I I I I I I I I I I I I I I I I I I J 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 10080 9600 9120 8640 8160 7680 7200 6720 6240 5760 5280 4800 4320 ~840 3360 2880 2400 1920 1440 gE0 480 0 <- West (feet) 364O 3360 288O 240O 1920 1440 960 48O 48O P H I. LLI _Al a s__ k a___Z' c__: Struofure: Tam Drill S~ ~ Well: ~ ~M: Tam ~lopment ~eld ~on: Nodh SM~, Hoiko PROFILE COMMENT DATA Point KOP Begin Build Port Collar Begin Bid/Tm Base of Permafrost W Sak EOC Base W Sak 7 5/8 Casing Pt C80 C50 C40 C37 Iceberg T7 Begin Fnl Drop EOC T3.1 T3 Target Mid Bermuda T2 C35 TD -- Casinq Pt MD 250.00 750.00 1023.33 1250.00 1259.59 1514.24 2183.61 2716.O7 3806.66 4329.80 7761.19 8692.19 8766.08 9785.74 0317,74 0906.42 1080.55 1256.89 1280.55 1476.93 1670.97 1711.20 2011.20 Inc Dir 'rVD North 0.00 0.00 250.00 0.00 15.00 275.00 744.31 5,67 25.93 275.00 1000.00 13.99 35,00 275.00 I 195.1 6 24.00 35.36 275.24 1203.00 24.49 37.40 276.54 1247,00 27.82 70.22 283.66 1750.84 187.27 70.22 283.66 1931.00 305.61 70.22 283.66 2300.00 548.00 70.22 285.66 2477.00 664.26 70.22 283.66 5658.00 1426.88 70.22 283.66 5953.00 1633.79 70.22 283.66 5978.00 1650.22 70.22 285.66 4523.00 1876.83 70.22 283.66 4505.00 1995.07 70.22 283.66 4702.18 2125.90 65.00 283.66 4768.48 21 63.91 65.00 283.66 4843.00 2201.66 65.00 283.66 4853.00 2206.72 65.00 283.66 4935.99 2248.75 65.00 283.66 5018.00 2290.28 65.00 283.66 5035,00 2298.89 65.00 283.66. 51 61.79 2563.10 East 0.00 -64.83 - 159.90 -274.27 -279.77 -512.01 -986.11 -1472.99 -2470.23 -2948.58 -6086.25 -6937.56 -7005.12 -7937.50 -8423.96 -8962.25 -9118.64 -9275.94 -9294.78 -9467.73 -9658.61 -9674.04 -9938.24 V. Sect 0.00 64.59 158.80 272.59 277.85 310.00 1002.69 1503.74 2550.00 5022.28 6251.25 7127 7196.86 8156.37 8656.98 9210.94 9571.88 9551.70 9553.14 9731.12 9906.98 9943.44 10215.35 Deg/1 O0 0.00 3.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 0.00 0.00 0.00 0,00 0.00 0,00 PHILLIPS Alaska, Inc. 300 290 310 320 330 340 TRUE NORTH 350 0 10 3O I I I 1 'lOe I l , ~,oo60 I I 7OO 7O 280 8O 270 9O 260 250 240 t ?-oo220 ! ,t 210 Normal Plane Travelling Cylinder - Feet 180 100 110 120 130 140 All depths shown ore Measured depths on Reference Well '! '""':,. ,',':"""" ~r;'"'~':, F,':" "" ;ii '~:' "' i:; ""'"'" ;:"-:"';~' ;::,.-:,~4~ !,' ........ ;... ~ ..-.., ;/' it;.~'~'"'~ 14 ~'~ IPHILLIPS Alaska, Inc. $tru~i-re: lorn Drill Silo ~ ~11: 35~ Field: Torn I)evelol)ment Field Loc~ion: Norlh Slope, Aloeka A I <- West (feet) 380 .~60 340 ~20 ~00 260 280 240 220 200 180 160 140 120 100 80 60 40 20 0 20 40 60 160 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 i i i i 0 ............. 200 200 -- '~299.gg 140 120 100 40 ~ 20 ~ %.700 20 -I'~'~ ..... ..%~ ~ ~ / % ~ - ' ~ ~ 11~ / 2100 -~ ~/ ~ ~ / f ouu / /1400 ~ 20~ 1200 g~ 7~ ~ _ 800 ....................... /.t. oo II__ f t,.l, U 0 1 O0 ~2o 240 220 200 '~0 t60 140 120 100 80 60 40 20 0 20 40 60 <- West (feet) 160 140 120 lO0 BO 6O A 40 I 2~ 413 . . 60 -" 'y. BO 100 ~...., 120 ?-. '.:: .' ,_. , . .. 4OO 350 32O 28O 24O 150 12o 120 160 I~ ~ ~, For: T B~g~ieldJ IPHILLIPS Alaska, Inc. Structure: Tarn Drill Silo 2N Well: Field: Tom Development Field Looatlon: No~h Slope, Alaska <- West (feet) 1150 1120 1080 t040 1000 950 920 880 840 800 750 720 680 640 600 560 520 480 440 400 360 .~2.0 2000 ~ 240 ~ - ~ 160 I ~... 17oo ~ -- ~ 1600 ~-- ~ ~ ~ 1400 1600 - ~ - - ~. ................ "' .... 1400 .......... -,, - 1300 .......... ,,- ...... 1200 - - ,- - _ _ 1100 0 -- - -e- 1000 ..... · -. - 900 .... · -- ---~m-- - - ,~ ...... --- . .., .......... e,- - -e- - - _ --m- .. . .. 80 :. . .. .'.' ~. .r"-~_3 ;. 120 .:~ ~. ,...j._:; 'C' ":' ' ¢'. , , j , , Ji , i i , , i i i i i , i , 160 · ;' i' 11~0 1120 10~0 1040 10~0 950 920 ~0 540 600 760 720 660 640 500 §60 ,520 460 440 400 360 320 ,_- ... <- West (feet) !.':: . [PHI____LLII S_ _Alas___ka, I__n_e_. Stru=hJra: Tarn Drill SJfo 2N Well: 332 FTeId: Tam Dovolopmoflt From Lo~aflon: Norlh Slopo, Alaska <- West (feet) 5400 5200 5000 48~0 4600 4400 4200 4000 ~ 3600 ~400 .,~200 3000 2800 2600 2400 2200 2000 1800 1500 1400 1200 1000 ~ I I s 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 ~ , l 100 "" .~ 0 0%'~% 1400 - 1400 ---. ,~0o . ~7oo '. looo I Z ~100 2900 ;;;-. _.. _;5~00. 2700 ~'~' ~ ;5.~00 3100 2900 2700 2~00 ' - ' ' -~,'~;00 ~ - -£9~' ......... : ~o~- ................. 2~o 2300 2oo ~.~ 2500 21 O0 ........... 2~00 .......... 1900 27OO .... a~o 3~00 3~00 2900 .... ~ ~ 4oo :~,A~L.:--.-_;~' ~' .......... "" '~ 4100 ~900 ~,,~-u~ · _ 80O 0 Z 2O0 600 ~ i 2700 3100 2900 ~ 800 , , <- West (feet) lOOO 48OO ^ - I 2400- -l-- . ,~_ 2000- . 0 Z - 12.0o- 80o 40o 40o 80o IPHILLIP~ Alaska, Inc. SlrucJum: Tam Drill SHe 2N Weft: 332 FbM: Tam DeyoJoprnen~ F~eld Lo~rflon: #orlh Slopo, Alaska ..:. [-UL.~d <- West (feet) 12800 12400 12000 11600 11200 10800 10400 10000 9600 9200 8800 8400 8000 7600 7200 6800 6400 6000 5600 5200 4800 4400 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 I I I I I I i i i I 4800 4cJO(~'%-.. -.,. "'%"~100 3gC). '% %4100~4100F 4000 4~oo".. .--. % ~ - ~o0 '.. ~ ..~ "......oo ',' ._2_,., --',,~z~_. __ ~ . 4~o - .... --,. ~.oo '",4~ -~,o ""., "'"'~4100 ~ 5161 370~'"' ...... "~0 2400 -..4900 ~""~'&':..~4900 5500'"' '-- ' - - - ...~o.o_ .... -'"'-"----.-~oo ~ ~ - 2000 - ....350() .- - '"~700 4500 ~-zl~o~ 4.06 470o' - - 424oo 42000 l~rooo ri200 40800 'i0400 10o0o 9~0 92oo ~ 84oo aooo 76oo 7200 ~ 5400 6000 §§00 ~200 4800 4400 <- West (feet) 4O0 I Z PHILLIPS Alaska, Inc. Tarn Drill Site 2N 332 slot #332 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 332 Version #12 Our ref : Drop3760 License : Date printed : 17-May-2000 Date created : 6-Dec-1999 Last revised : 15-May-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 12.985,w150 18 59.530 Slot Grid coordinates are N 5911909.452, E 460669.273 Slot local coordinates are 98.57 S 923.64 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-10245'>,,337A,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <0-10520'>,,308,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-12'339'>,,341,Tarn Drill Site 2N PMSS <266'-l1061'>,,320,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PGMS <0-9175'>,,32iA,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Jun-1998 65.5 555 29-Ju1-1998 65.5 555 9-0ct-1998 194.6 260 28-Feb-2000 150.9 655 30-Mar-1999 344.2 250 8-Mar-1999 374.4 260 24-Feb-1999 360.1 0 21-Ju1-1998 129.4 1085 9-0ct-1998 86.3 622 27-0ct-1998 22.3 611 14-Aug-1998 225.0 260 21-Dec-1998 102.0 280 30-Sep-1998 123.5 644 9-Feb-1999 180.1 0 12-May-2000 133.5 290 10-May-2000 45.1 20 4-Aug-1998 284.7 270 16-May-2000 254.6 270 29-Feb-2000 162.9 280 21-Dec-1998 162.9 280 21-Dec-1998 162.9 280 10-May-2000 14.2 280 6 555.6 6 555.6 0 260.0 6 655.6 0 250.0 0 260.0 0 0.0 0 1085.0 2 622.2 I 611.1 0 260.0 0 280.0 4 644.4 0 8600.0 0 290.0 0 1960.0 0 270.0 0 270.0 0 280.0 0 280.0 0 280.0 0 1820.0 PHILLIPS Alaska, Inc. Tarn Drill Site 2N 332 slot #332 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ REPORT Your ref : 332 Version #12 Our ref : prop3760 License : Date printed : 16-May-2000 Date created : 6-Dec-1999 Last revised : 15-May-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 12.985,w150 18 59.530 Slot Grid coordinates are N 5911909.452, E 460669.273 Slot local coordinates are 98.57 S 923.64 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath 349(to312'sTgt)Ver%2,,349,Tarn Drill Site 2N 305 Version %l,,305,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <0-10655'>, 337,Tarn Drill Site 2N PMSS <7090-10245'> ,337A,Tarn Drill Site 2N PMSS <0-9134'>, 313,Tarn Drill Site 2N PMSS <0-7039'>, 319,Tarn Drill Site 2N PMSS <9483 - 9631'> ,343,Tarn Drill Site 2N PMSS <288-8750'> ,309,Tarn Drill Site 2N PMSS <0-8960'>, 307,Tarn Drill Site 2N PMSS <0-10520'>, 308,Tarn Drill Site 2N PMSS <0-7431'>, 345,Tarn Drill Site 2N PMSS <8085-8239'> ,339,Tarn Drill Site 2N PMSS <0-12077'>, 335,Tarn Drill Site 2N PMSS <0-8500'>, 317,Tarn Drill Site 2N PMSS <7387 - 8182'> ,325,Tarn Drill Site 2N PMSS <0-12339'>, 341,Tarn Drill Site 2N 347 Version %13, 347,Tarn Drill Site 2N PMSS <266'-11061'> ,320,Tarn Drill Site 2N PMSS <9235 - 10028'> ,32iA, Tarn Drill Site 2N PGMS <0-9175'>,,32iA,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance 23-Mar-2000 25-Feb-2000 10-May-2000 18-Jun-1998 29-Ju1-1998 4-Aug-1998 9-0ct-1998 28-Feb-2000 30-Mar-1999 8-Mar-1999 24-Feb-1999 21-Ju1-1998 9-0ct-1998 27-0ct-1998 14-Aug-1998 21-Dec-1998 30-Sep-1998 il-May-2000 9-Feb-1999 21-Dec-1998 21-Dec-1998 )62.7 )403.7 )12.2 )62.2 )62.2 283.3 193.3 146.1 342.5 372.9 359.5 117.3 )81.5 )18.3 223.6 100.0 119.5 144.0 179.1 160.8 160.8 M.D. Diverging from M.D. 1291.9 1291.9 260.0 260.0 300.0 8875.0 566.7 11725.0 566.7 10000.0 290.0 8350.0 270.0 270.0 675.0 675.0 260.0 9700.0 275.0 7800.0 200.0 11850.0 1125.0 1125.0 633.3 9320.0 622.2 11625.0 270.0 8825.0 290.0 290.0 655.6 11880.0 2200.0 2200.0 175.0 8575.0 300.0 11740.0 300.0 11350.0 PMSS <5303 - l1526°>,,321,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N 322 Version#28,,322,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N 314 Version #3,,314,Tarn Drill Site 2N 318 Version#2,,318,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N 316 Version#7,,316,Tarn Drill Site 2N 29-Feb-2000 12-May-2000 12-May-2000 10-May-2000 16-May-2000 il-May-2000 16-May-2000 16-Ma¥-2000 )160.8 )132.0 )148.5 )44.3 )268.7 )208.8 )253.1 )238.8( 300.0 300.0 355.6 240.0 260.0 260.0 290.0 275.0 11940.0 8275.0 4425.0 6650.0 260.0 260.0 11820.0 275.0 PHILLIPS Alaska, Inc. CLEARANCE LISTING Page 2 PHILLIPS Alaska, Inc. Tarn Drill Site 2N 332 slot #332 Tarn Development Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 332 Version #12 Our ref : prop3760 License : Date printed : 17-May-2000 Date created : 6-Dec-1999 Last revised : 15-May-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 12.985,w150 18 59.530 Slot Grid coordinates are N 5911909.452, E 460669.273 Slot local coordinates are 98.57 S 923.64 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North {' PHILLIPS Alaska, Inc. Tarn Drill Site 2N,332 Tarn DeveloDment Field,North SloDe, Alaska PROPOSAL LISTING Page 1 Your ref : 332 Version #12 Last revised : 15-May-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees DeDth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 250.00 0.00 0.00 250.00 0.00 N 0.00 E 0.00 0.00 KOP 300.00 1.50 275.00 299.99 0.06 N 0.65 W 3.00 0.65 400.00 4.50 275.00 399.85 0.51 N 5.87 W 3.00 5.82 500.00 7.50 275.00 499.29 1.42 N 16.28 W 3.00 16.17 600.00 10.50 275.00 598.04 2.79 N 31.86 W 3.00 31.64 700.00 13.50 275.00 695.85 4.60 N 52.57 W 3.00 52.21 750.00 15.00 275.00 744.31 5.67 N 64.83 W 3.00 64.39 Begin Build 775.00 16.00 275.00 768.40 6.25 N 71.48 W 4.00 71.00 875.00 20.00 275.00 863.48 8.95 N 102.26 W 4.00 101.56 975.00 24.00 275.00 956.18 12.21 N 139.57 W 4.00 138.62 1023.33 25.93 275.00 1000.00 13.99 N 159.90 W 4.00 158.80 Port Collar 1075.00 28.00 275.00 1046.05 16.03 N 183.23 W 4.00 181.98 1175.00 32.00 275.00 1132.63 20.39 N 233.03 W 4.00 231.44 1250.00 35.00 275.00 1195.16 24.00 N 274.27 W 4.00 272.39 Begin Bld/Trn 1259.59 35.36 275.24 1203.00 24.49 N 279.77 W 4.00 277.85 Base of Permafrost 1300.00 36.87 276.21 1235.65 26.87 N 303.47 W 4.00 301.46 1314.24 37.40 276.54 1247.00 27.82 N 312.01 W 4.00 310.00 W Sak 1400.00 40.64 278.34 1313.62 34.84 N 365.54 W 4.00 363.69 1500.00 44.45 280.16 1387.28 45.75 N 432.25 W 4.00 431.12 1600.00 48.28 281.76 1456.28 59.53 N 503.28 W 4.00 503.41 1700.00 52.13 283.17 1520.28 76.13 N 578.28 W 4.00 580.22 1800.00 55.99 284.44 1578.96 95.47 N 656.88 W 4.00 661.16 1900.00 59.87 285.60 1632.05 117.44 N 738.70 W 4.00 745.85 2000.00 63.76 286.67 1679.27 141.95 N 823.35 W 4.00 833.87 2031.93 65.00 287.00 1693.08 150.29 N 850.90 W 4.00 862.60 2100.00 67.34 285.47 1720.58 167.69 N 910.68 W 4.00 924.79 2183.61 70.22 283.66 1750.84 187.27 N 986.11 W 4.00 1002.69 EOC 2500.00 70.22 283.66 1857.89 257.59 N 1275.42 W 0.00 1300.42 2716.07 70.22 283.66 1931.00 305.61 N 1472.99 W 0.00 1503.74 Base W Sak 3000.00 70.22 283.66 2027.07 368.72 N 1732.62 W 0.00 1770.93 3500.00 70.22 283.66 2196.24 479.84 N 2189.82 W 0.00 2241.43 3806.66 70.22 283.66 2300.00 548.00 N 2470.23 W 0.00 2530.00 7 5/8 Casing Pt 4000.00 70.22 283.66 2365.41 590.96 N 2647.02 W 0.00 2711.94 4329.80 70.22 283.66 2477.00 664.26 N 2948.58 W 0.00 3022.28 C80 4500.00 70.22 283.66 2534.59 702.09 N 3104.22 W 0.00 3182.44 5000.00 70.22 283.66 2703.76 813.21 N 3561.42 W 0.00 3652.94 5500.00 70.22 283.66 2872.93 924.34 N 4018.62 W 0.00 4123.45 6000.00 70.22 283.66 3042.11 1035.46 N 4475.82 W 0.00 4593.95 6500.00 70.22 283.66 3211.28 1146.58 N 4933.02 W 0.00 5064.46 7000.00 70.22 283.66 3380.45 1257.71 N 5390.22 W 0.00 5534.96 7500.00 70.22 283.66 3549.63 1368.83 N 5847.42 W 0.00 6005.47 7761.19 70.22 283.66 3638.00 1426.88 N 6086.25 W 0.00 6251.25 C50 8000.00 70.22 283.66 3718.80 1479.96 N 6304.62 W 0.00 6475.97 8500.00 70.22 283.66 3887.97 1591.08 N 6761.82 W 0.00 6946.47 8692.19 70.22 283.66 3953.00 1633.79 N 6937.56 W 0.00 7127.33 C40 8766.08 70.22 283.66 3978.00 1650.22 N 7005.12 W 0.00 7196.86 C37 9000.00 70.22 283.66 4057.15 1702.20 N 7219.02 W 0.00 7416.98 9500.00 70.22 283.66 4226.32 1813.33 N 7676.22 W 0.00 7887.48 9785.74 70.22 283.66 4323.00 1876.83 N 7937.50 W 0.00 8156.37 Iceberg Ail data is in feet unless otherwise stated. Coordinates from slot #332 and TVD from }{KB (Nabors 19E) (153.00 Ft above mean sea level). Bottom hole distance is 10215.33 on azimuth 283.38 degrees from wellhead. Total Dogleg for wellpath is 77.57 degrees. Vertical section is from wellhead on azimuth 283.36 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ,~,i;::;:¢.~ ~,;~[:j~ ..~J:.~.. r...~;~m] i~ ,?~, ,.~, d;:,.~,,: ,.;:-,~,~ ':' ~ ':' ~' ~[i''~:: ~ ';~ ia ~ .... ~! N ~¢,,x :if ~ .~ , ~, .... ~ · PHILLIPS Alaska, Inc. Tarn Drill Site 2N,332 Tarn Development Field,North SloDe, Alaska Measured Inclin. Azimuth True Vert R E C DeDth Degrees Degrees Depth C 0 0 10000.00 70.22 283.66 4395.49 1924.45 N 10317.74 70.22 283.66 4503.00 1995.07 N 10500.00 70.22 283.66 4564.67 2035.58 N 10906.42 70.22 283.66 4702.18 2125.90 N 11000.00 67.42 283.66 4735.98 2146.51 N TANGULAR RDINATES PROPOSAL LISTING Page 2 Your ref : 332 Version #12 Last revised : 15-May-2000 Dogleg Vert Deg/100ft Sect 8133.42 W 0.00 8357.99 8423.96 W 0.00 8656.98 T7 8590.62 W 0.00 8828.49 8962.25 W 0.00 9210.94 Begin Fnl Drop 9047.03 W 3.00 9298.19 11080.55 65.00 283.66 4768.48 2163.91 N 9118.64 W 3.00 9371.88 EOC 11256.89 65.00 283.66 4843.00 2201.66 N 9273.94 W 0.00 9531.70 T3.1 11280.55 65.00 283.66 4853.00 2206.72 N 9294.78 W 0.00 9553.14 T3 11476.93 65.00 283.66 4935.99 2248.75 N 9467.73 W 0.00 9731.12 Target Mid Bermuda 11476.94 65.00 283.66 4936.00 2248.75 N 9467.74 W 0.00 9731.13 2N-332 Rvsd 23-Feb-00 11500.00 65.00 283.66 4945.74 2253.69 N 9488.04 W 0.00 9752.03 11670.97 65.00 283.66 5018.00 2290.28 N 9638.61 W 0.00 9906.98 T2 11711.20 65.00 283.66 5035.00 2298.89 N 9674.04 W 0.00 9943.44 C35 12000.00 65.00 283.66 5157.05 2360.71 N 9928.38 W 0.00 10205.18 12011.20 65.00 283.66 5161.79 2363.10 N 9938.24 W 0.00 10215.33 TD - Casing Pt Ail data is in feet unless otherwise stated. Coordinates from slot 9332 and TVD from RKB (Nabors 19E) (153.00 Ft above mean sea level). Bottom hole distance is 10215.33 on azimuth 283.38 degrees from wellhead. Total Dogleg for wellpath is 77.57 degrees. Vertical section is from wellhead on azimuth 283.36 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Tarn Drill Site 2N0332 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 332 Version #12 Last revised : 15-May-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 250 00 250 00 0.00 N 0.00 E KOP 750 1023 1250 1259 1314 2183 2716 3806 4329 7761 8692 8766 9785 10317 10906 11080 11256 11280 11476 11476 11670 11711 12011 00 744 33 1000 00 1195 59 1203 24 1247 61 1750 07 1931 66 2300 80 2477 19 3638 19 3953 08 3978 74 4323 74 4503 42 4702 55 4768 89 4843 55 4853 93 4935 94 4936 97 5018 20 5035 20 5161 31 5.67 N 64 00 13.99 N 159 16 24.00 N 274 00 24.49 N 279 00 27.82 N 312 84 187.27 N 986 00 305.61 N 1472 00 548.00 N 2470 00 664.26 N 2948 00 1426.88 N 6086 00 1633.79 N 6937 00 1650.22 N 7005 00 1876.83 N 7937 00 1995.07 N 8423 18 2125.90 N 8962 48 2163.91 N 9118 00 2201.66 N 9273 00 2206.72 N 9294 99 2248.75 N 9467 00 2248.75 N 9467 00 2290.28 N 9638 00 2298.89 N 9674 79 2363.10 N 9938 .83 W Begin Build .90 W Port Collar .27 W Begin Bld/Trn .77 W Base of Permafrost .01 W W Sak .11 W EOC .99 W Base W Sak .23 W 7 5/8 Casing Pt .58 W C80 .25 W C50 .56 W C40 .12 W C37 50 W Iceberg 96 W T7 25 W Begin Fnl Drop 64 W EOC 94 W T3.1 78 W T3 73 W Target Mid Bermuda 74 W 2N-332 Rvsd 23-Feb-00 61 W T2 04 W C35 24 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3806.66 2300.00 548.00N 2470.23W 7 5/8 Casing 0.00 0.00 0.00N 0.00E 12011.20 5161.79 2363.10N 9938.24W 5 1/2 Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-332 Rvsd 23-Feb-0 451214.000,5914206.000,0.0000 4936.00 2248.75N 9467.74W 3-Dec-1999 Phillips Alaska, Inc. Diverter Schematic Nabors 19e Flowline 21%" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16-3/4" 2M SOW Starting Head 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16-3/4" x 21-1/4" x 2M Psi DSA Flange 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) Phillips Alaska, Inc. Nabors 19e 11" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT i--j MANUAL GATE V KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / DSA 13-5/8" 5,000 psi WP -"~L x 11" 3,000 psi WP 11" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 11" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom L_ 1 3" 5,000 psi WP Shaffer GATE VALVE r_] ~raulic actuator 11" 5,000 psi WP L_~~ DRILLING SPOOL w/two 3" 5M psi WP outlets J SINGLE 11" 5,000 psi WP, I HYDRIL MPL BOP w/pipe rams Phillips Alaska, Inc. ( Post Office Box 100360 Anchorage, Alaska 99510-0360 May 19, 2000, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-332 Surface Location: 99' FNL 924' FEL Sec 3 T9N R7E, UM or ASP4, NAD 27 coordinates of X=460,669 & Y=5,911,909 Target Location: 2142' FSL, 172' FWL Sec. 33, T10N, R7E, UM Bottom Hole Location: 2256' FSL, 299' FEL Sec. 32, T10N, R7E, UM Dear Commissioner Christenson, Phillips Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-332, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Nabors Rig 19e will drill the well. If commercial, the well will also completed with Nabors 19e. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an appr. oved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, Phillips has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Doug Hastings, Geologist 265-6967 (20 AAC 25.071) If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 265-6120 in our Anchorage office. Sincerely, Chip'~ (~' Drilling Engineering Supervisor Attachments cc: KRU 2N-332 Well File 2 2 20O0 Phillips Alaska, Inc. is a Subsidiary of Phillips 66 ,~as~:a Oil & G~s Cor~s, CommissJ,m'~ ARCO Alaska, Inc. KUPARUK SATELLITE DISBURSEME{ P.O. Box 103240 Anchorage, AK 99510-3240 ACCT PAY TO THE ORDER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE ~,~.,~.~. 20{ 00203 MAY 16, 200O *** VOID AFTER 90 DAYS *** 62-28 311 0927473 EXACTLY *********** 100 DOLLARS AND O0 CENTS ~*********** 100.00 The First National Bank of Chicago-0710 Chicago, Illinois Payable Through FCC National Bank Wi Imington, Delaware TRACE NUMBER: 206000203 ,' 8Dr=DOD ;~O :!,,, ,:O 3, ~, :tOD ;:],El, :l,t: O ci ;= ? [, ? ~,' STATE OF ALASKA' A~-¥SKA OIL AND GAS CONSERVATION CO~,...~SSION APPLICATION FOR SUNDRY APPROVALS ' 1. Type of Request: Abandon _.. Alter casing __ Change approved program _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P, O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 61' FNL, 763' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 128' FNL, 713' FEL, Sec. 33, T10N, R7E, UM At effective depth At total depth 134' FSL, 842' FEL, Sec.28, T10N, R7E, UM 12. Present well condition summary Total Depth: measured · ' (eapmx) true verticel Effective depth: measured (eaprox) true vertical Casing Length 8tnJctund Conductor 90, Surface 3833' Intermediate Production 9282' Uner 691' Suspend _ Operation Shutdown__ Re-enter suspended well_ Repair well _ Plugging_ 'nme extension_ Stimulate_ , Perforation depth: measured true vertical , Variance _ Pull.tubing _ 5. Type of Well: ." Development X_. Exploratory ~ Stratigraphic -- Service ' -,_, 11,526' feet Plugs.(measured) - 5241' feet 9904' feet-' Junk(measured) '4478' feet None Perforate Other X Annular Iniection 6. Datum elevation (DF o.r KB) .. .- 28' RKB feet 7. Unit or Property name - '- .-. Kuparuk Riv.~er_F_teL.d/- Tam Oi1' Pool 8. ' R - ' /' 2N-321A J 9. P it~ ' ^., .ur. o Ill.Field/Pool. ' ' Kuparuk River Field/Tam Oil Pool ..' · Size Cemented Measured depth True veWcal depth 16' 10 CY High Early 118' 118' 7.625" -110 sx AS111/254 CI (3 ' 3861' 2295' 238 Class Cd60 AS I . ' 5.5"x 220 ex Class (3 9310' 4259' 3.5' 10001' 4516' ._ .' DUPLICATE Tubing (size, grade, and measured death) 3.5", 9.3~, L-80 · 9324' Packers and SSSV (type and measured depth)' Baker CSR 0 9310' RECEIVED . 'SEP 2 2 1998 Alaska Oil &-Gas Cons. commission ^n¢oraqe 13. Attachments DescripUon summary of proposal m . Detailed operation program BOP sketch ~ Contact Paul Mazzolini at 265-4603 with any questions. LOT test, surface cement details and casing detail sheets' X 14. Estimated date for commencing operation. 15. Status of well classification as: -. September 1998 Oil X Gas_' SUspended _-. 16. If proposal was verbally approved Name of approver Date approved ServiCe '- · · 17. I herebycerUfythattheforegoingistrueandcorrecttothebast0fmyknqwledge. - ' ,~. Signed "p~.- ~,~j'~~--"-"~ Tiff. Tam Drilling Team Leader Data ."//1~'/,m.' . -. ·~ FOR COMMISSION USE ONLY Conditions of approval: Notify Co~missi_on_ so_o~.ei:Ea.s.e.~ntab.'ve m_..m.~L~.th. .' ' - . !Approval No..,,~/,3. Plug integrity_ ~.~-~ast__ ~~'le~ .-. -. ' · I'- Approved by the order of the Commiasi -"~ .' :-- Commleeioner Data. Form 10-403 Rev 06/15/88 L .'~ ~ ' ' "' '! ' SUBMIT IN TRIPLICATE . · -. · . . CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-321 Supervisor: D.P. BURLEY Date: 8/19/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 2,309' 'rVD 7 5/8", 29.7 ppf, L-80, BTC 3861 TMD 2,295' TVD EMW = Leak-off Press. + MW 0.052 x 'TVD 830 ps! + 9.1 ppg EMW LOT = (0.052 x 2,309'~ = 16.0 ppg Fluid Pumped.= 1.1 bbl Pump output =. 0.1000 bps ~.~o r~ -'"'-~ OREN IINU!-': C . . . . . . ~.~ '1,~ .~ I' ~ ~.~ /' .. /'' '1 [ ~.~ ~ ..... ~ ~C~ING TE~ ~m ~ ~ LOT SH~ IN TIME ~ F ~ ~ ~ ~ e ~C~ING TE~SH~ IN TIME jr . lm~ . . . , , ~ , , 0 2 4 6 8'1012141618~~~~~~~747678~.~ ~OGS . LEAK-OFF DATA 'MINUTES FOR LOT STROKES PRESSURE 0 stks 0 psi ..... ! 1 stke 40psi .__ ] .... -2stks- ..... '~-~ ps--i--" ..... l-:~ ~i~"-" --"~-b'*p%i-", ...... ~l---~-~,~.--~--i o-,~..;~ .... ----.7_--~~~ ~-- ..... l._~z.~,~-~. _T~.a~.;,~- i i 9 stke j 640.p_s_i I-r: ...... ! ...... -r I - ; 10stks i 750 psi ......... = .... i----____....~. .... ----.__.... I. 11 ~t~ d.--8--a-°~-! .... ! ! r- ...... 4 ......... -----_q ....... t::::::::::: /- ...... ~j.- ................ ! · : ........ !- ....... f ................ i SHUT IN TIMEj SHUT IN PRESSURE 0.0 rain 1.0 min 2.0 min ' 3.0 rain 4.0 min j 5.0 min ~ 6.0 min 7.0 min l 8.0 rain I: 9.0 min 10.0 rain [ .... LZ74o_ps_L_j CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 4 stke 8 etke .................... .tg._~!.k..s.__ ...................... 1.?.~!.k.?.._. 14 stke .................. 1.6..~!.k..s._.. 18 stks ' 20 stks j .................. .2. ?_ ~_k... .... ......................... ..2...4...st k__s. ..... 26 stks ......................... .2..,.~t..~. .,__... SHUT IN TIME SHUT IN PRESSURE 0.0 min '-'~','~T6-.~..'[.~ '"~;~)~'~[i.j __.l..._O...m. Jn_2.0 rain ......................... i~i)]~'p~--I_.~ =================================== :.-.)'..,.ii:ii.~:~,."-., ' -- '- 4.0 min .................. 5.0 min .., ._:m._,~_~P_l~L. 6.0 rain ....1..,.9..8_0.. p._ sL .... _7._o_ .mjn_ ..... ~.,.9.~o.p..,~. .... §._o .~Ln. ....... _~ ,_9Z.o..E~Z, 9.0 min __1.,_9.7.~O.p_s.L 10.0 rain 1,960 p. si ....~.~:o__m~.,.... ' ................ 20.0 min 1,950.~si 25.0 min .................. ~,~'~ p.~i-' 30.0 min ................. NOTE:-sTRoKES TURN TO MINuTEs DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY -CASING TEST and LEAK OFF TEST Well Name: 2N-321 SuperVisor: . D.P.BURLEY. Date: 8/22/98 Casing Size and Description: 7 5/8", 29.7 ppf, L,80, BTC . Casing Setting Depth: 3861'TMD Mud Weight: 9.2 ppg Hole Depth'.' - ~/572 -TVO 640 psi + 9.2 ppg - LOT = (0.052 x~) -. · / 5q~- .- Fluid PU~p~d = S.S b~l Bled back 1.5 bbls after te~. 2,295' TVD EMW = Leak-off Press. + MW 0.052 x TVD EMW =.l~l~pg ·: = II.q f_~_ _ Pump output-- 0.1000 bps - . ~11111111111-11111'1_1111111111111111111111~ '~1~ ~ I ~ II I ~ ~ IIl.l.l.l.l.l,l,l.l.l.l.l-,I.I.-I.l.i.l.l.l.l.l.l.l.l.l III ~111111 l~!l!!!lllllllll~l~-rl-i~~lllllllllll-Illlllllllll /,~lllllllllllllZlllllllllllllllll-IIIIIIIIIIIIIIl. llll l'~llllllllllll~llllllllllllllllllllllllllllllllllllll| i~0~llllllllllJ/rlllll, llllllllllllll, llll![!!!l.!!!!!lll!l! ~a. lllllllllJ/l'lllllll-IIIIIIIIIIIIIIIIl~l~l~~,~l ~ i.~lll.lllllJ/rllllllllllllllllllllllllllllllllllllllllll ~/~m2llll-IIII/f'lllllll-II.lllllllllll.lllllllllllllllllllllll 11~1111111~11111111111111111111111111111111111111111111 ~ '~111111~111111111111111111111111111111111111111111111 .~1111.11~ IIIIIIIIIIIIIIIIIIIIIIIIIIIlllllllllllllll_lll ~ I III I~1 l I Ill III I IIII IIIIIIIIIIII -e--LEAK~FF~ ILL .-~11 I I I/[I I I]~+~I u~ I~111111111 II '-~'-C^$1N~ ~lll I~11.b4rl' I |1 IITTI I I ITT~I I Il --~.,- LOT SH~ IN TIME IH'- ~111 ~1 I.d*'TI I I I I I I I I I I I I I I I I I I I~ III ..-,~--~A,S~I~'I'E~ SHUT IN TIME ~m~lJ~rrllllllllllll.llllllllll.llllll-IIIIIIIIl'llllllllll-II -O~I/FIII'I:IIII.IIIIIIIIIIIIIIIIIIIiltlIIIlIIIIIIIIIIIIIII, 0 2 ~ 6 8 101~141616~~~~~~76~~~101010 -.kkkkkkkkkkkkkkkkkkkkk'kkkkkkkkkkkkkkkkkkkkkkkkkkkkk~M~ kkk NOTE: STROKES TURN TO MINUTES DURING "sHuT IN TIME":see time line above' LEAK-OFF DATA . MINUTES FOR LOT STROKES PRESSURE i I°arks -°--esi--i- . ..... 9o..p_s.i : l' 220~.ei .! ~0 s~ke _.~..6..0.9.?.i- ~ ~2 aks 14 etks -SO0~i Ii~ ......... !~ ....... i! ...... 19 etks ._...5~.O_.P__S! ~a ,tk~ _s~.L- 2o ~tke,_6.3_.0.p~_ .... 22 ~tke_ e.._4._o_e_~.L- 24 stke _._6_3..o_p_.si.L.. 28 stks _. 61___O_p.s] 2s stk~. ~_eo_o. ~.p_~L_ 30 etk~ __.60_0_~..~_~_ 600 pei 2 stks '4 stke 6 stks .. 35 st__k_s_. SHUT IN TIME 40 stks 50 stks 55 stke I SHUT IN PRESSURE 0.0 min i L. 5---~4-°-p--?i-=- 1.0 rain ! J~O_...p..s_.i_.~ 2.0 min 370psi 4.0 ~ni~ .... 360 psi - s;o min. . . . ~5.o, p.~_~_ 6:o __mi~ : 7.0rain' 340pei,._ 8.0 min 340 ps_i.~.. 9.O-m~n ' 340 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 2 stks 6 etke 12 stke 14 stks 16 stks 18 stks 20 stke 22 stks 24 slim 26 stk$ 28 Irks SHUT IN TIME SI~UT IN PRESSURE 0.0 min 1.0 min 2.0 rain 3.0 min 4.0 min 5.0 min 1,990 psi 1,990 Esi ::..-Z:::::.-_Z .................. _1 ,.,_9.e_O..p~_ 6.0 min 7.0 min 8.0 min 9.0 min 10.0 min 15.0 min 20.0 min 25.0 min 30.0 min D..,~.~_.P_~L ._.1,940._p81 NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Cementing Details Well Nan~: 2N 321 Report Date: 08/2t/98 Report Number. 8 Rig Name: DOYON 141 AFC No.: AK9477 Field: Tam Casing Size Hole Diameter. Angle ~m KRU: Shoe Depth: LC Depth: 16 washout: 7-5/8 9-7,'8 n/a 386t 3737 Ceat~alizers Sta~e ~pe used, iniewe/s coveted and spacing Comments: 42 Gemeoo Bow Spring centralizers, placement on casing detail. _ Mild Weight PV(prior cond): PY(after cond): YP(prior cond): YP(aftar cond): Comments: 10.2 28 28 2t t5 Oels before: Gels after. Total Volume Circul,d~d: 5/t7 3/4 780 bbls Wash 0 Type: Volume: Weight: Comments: __ Spacer 0 Type: Volume: Weight: Comments: ARCO 30 bbls I 30 bbls t0.5 1 t0.5 1st staOe/2ed sta~e Lead Cement 0 Type: Mix wb' temp: No. of Sacks: Weight: Yield: Comments: AS III LW 70 t t 0 1254 t0.5 4.42 1st stage/2nd stage Additives: standard bleed Tall Cement 0 Type: Mix wtT temp: No. of Sacks: Weight: I Yield: Comments: 70 238160 t5.0 1 t5.7I 1.t7 10.9~ 1st st~el2ed ~ 6 Additives: 2nd stage tall, ardc set t. " Displacement 0 Rate(before tail at shoe): Rate(tell around shoe): SIT. Wt. Up: Comments: 8 bpm 16 bpm 8 bpm 14 bpm 1st stage 1 2nd stage Reciprocation length: Reciprocation speed: Str. Wt. Down: 20 tSfpm Theoretical Displacemeol: Actual Displaceme~ SIT. Wt. in mud: t7t.5 1 68.6 t 72.21 67.5 Caloulated top of cement: I CP: Bumped plug: Floats held: Surface thru stage collar ~ 1496'.I Date:5/5/28 yes yes ~me:0268 hrs Remarks:1 st stage: Staged pumps up to 8 bpm and cond mud, pumped 5 bbls warm','30 bi)Is of spacer, 86.5 bbls of lead and 49.5 bbls of tail cement. Displaced with 25 bbls of wash up water, 7~ bbls of mud, 28 bbls of spacer and 41.2 bbls of mud. Opened stage tool with 2660 psi, had full returns while circulating and cementing. · 2ed stage: conditioned mud at 8 bpnl, pumped 6 bbls of watar, 30 bbls of spacer, 200 blls of lead and 10 bi)Is tall cement. Displaced 25 bbls of wash up water and 42.5 of mud. Had 80 bbls of t0.5 ppg cement returns at surface, full returns throughout. Cement Company:, I Rig Contractor: IApproved By: DS IDOYON iD.BURLEY , ARCO Alaska, Inc. Casing Detail 7-5/8' Surface Casina WELL: TARN 2N-321 DATE: 8/16/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES I~:EMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doy°n 14i RT to LR = 29.10 29.10 7 5/8" Landing Joint 34' OAf 29.10 , FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.39 29.10 ' 58-91 7 5/8", 29.7#, L-80 BTC-MOD 1424.39 31.49 Jt #57 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 39.39 1455.88 Gemeco 7 5/8" Stage Collar (BAKERLOtC) 2.78 14,95.27 Jr. #56 7 5/8", 29.7#, L-80 BTC-MOD ~Thread Locked Collar) 42.43 1498.05 its. 3-55 7 5/8",29.7#, L-80 BTC-MOD.(shutoff baffle on top of jt #3, BAKEI 2234.86 1540.48 Gemeco Float Collar 1.33 3775.34 · , its 1-2 7 5/8", 29.7#, L-80 BTC-MOD 82.86 3776.67 Gemeco Float Shoe 1.50 3859.53 3861.03 ' insert baffle @ 373~.06 '" . , . · , . . , 42 Gemeco Bow Spring CE. NTRALIZERS Run. centralizers in Center of Jts. 1, 2,. over stop. Collars ., . eve~ collar thru Jt. # 15=every 3rd col!ar.to surface. . 1 above & 1 below stage collar. , . , . . . · , , . ~ . . . , . ,' . , . .. . . . · , ,, , , , ~ , . . , , , · Remarks: String Weights with Blocks: 100K# Up,65K# Dn, 12k# BloCks. Ran 91 joints of casing. Drifted casing with 6.750 plastic rabbit· Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. ! D°yon. 141 Drilling Supervisor'. M.C. HElM ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Alter casing __ Change approved program _X_ Abandon m Suspend __ Operation Shutdown _ Reenter suspended well Repair well __ Plugging __ Time extension _ Stimulate ~ Pull tubing m Variance ~ Perfomte~ Other__ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 137' FNL, 1084' FEL, Sec 3, T9N, R7E, UM At top of productive interval: At effective depth: At total depth: 1488' FNL, 2243' FWL, Sec 4, T9N, R7E, UM 12. Present well condition summary 5. Type of Welh Development ..= Exploratory ~ Stmtagmpic ...., Service X..~ 6. Datum of elavation (DF or KB feet): 149' RKB 7. Unit or Property: Kupamk River Unit 8. W?.number'.~,,,, ('" 2N-343.,,..,,~ 9. ~S~'~sr: 98-92 10. APl number:. 50.0103-20260 1t. Field/Pooh Kupamk River Field/Tam Oil Pool Total Depth: measured 9612' feet true vertical 5473 feet Effective Depth: measured 9414 feet .. true vertical 5330 feet Plugs (measured) Junk (measured) Casing Length Size Conductor 108' 16" Surface 3340' 9-518" Production 961Z 7' X 4-1/2' Liner Cemented 9 cu. Yds High Early 386 sx/~SIII, 350 sx Class G, 60 sx ASI 725 ~x Class G & :>,,. 16" lo~ ' Measured depth 108' 3340' 961Z True vertical depth 108' 2325' 5473' Perforation Depth None Tubing (size, grade, and measured depth) 4-1/Z', 12.6~, L-80, Tubing ~ 8859' MD. Packers and SSSV (type and measured depth) Baker Casing Seal Assby ~} 8859' MD RECEIVED S£P G 19g &eas Cons. comm sion Anchorage 13. Attachments Description summary of proposal _X Detailed operations program ~ BOP sketch _ 14. Estimated date for commencing operation Week of 1015 16. If'proposal was verbally approved Name of appmver Date approved t5. Status of well classification as: Oil _ Gas__ ' . Service:. MI Inlector ' Suspended 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify comission so mpmsentitive may witness . Plug Integrety4~"'"''"'~ test m ~ion clea[~n,'~.^. Approved by order of the Commissioner ~ ~.~._ Commissioner T-orm 1 u-4u~ Rev uu/1D/uu - Date ~/~C~/g~ . Date ' [ ' --/ ~SUUMI i iN ! I'(IHLIL;/~l b CASING TEST and FORMATION INTEGRITY TEST Well Name: TARN 2N-343 Date: 5111/98 Supervisor: David Burley Casing Size and Description: 9 5/8,,, 40 ppf, L-80, BTC Casing Setting Depth: 3,340' TMD 2,325~ TVD Mud Weight: Hole Depth: 8.9 ppg 2,339' TVD EMW = Leak-off Press. + MW 0.052 x TVD 860 psi + 8.9 ppg LOT = (0.052 x 2,339') = 16.0 ppg Fluid Pumped = 1.6 bbl lied back 1.5 bbls at end of FIT test, Pump output = 0.1010 bps j~ ,~o p~ '-~ ~ ~" I~ LEAK-OFF 'I'ESf ~OOp~ .~. ~,,', ~I--a--CASING TEST o,,,,~"' -. I I I I Osl~ 2stks 4stk:s 6itk8 8StkS 10 12 14 16 16 20 22 24 26 28 30 32 34 36 38 40 STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE i I I I t ............... ..... i 0 stks i 0 psi ......... ..... ..... ! 4 stks .__.1_9_0 ~.s.! ..... i 6 stks , ............... 'r,,'--~i'l~' ..... I 10 stks i 12 stks I 14 stks i 16 stks 1.0 min i 2.0 min ~ 3.0 min 4.0 min -f I 5.0 min | 6.0 min i - 7.0 min ! 86o ~.sj .... ,i .... 800~j ....~ i 790 .p.s.L.~ ~ 760_p..sj ..... '__7.5_.9.£.s.! .... ' 740 j;.s.! .... ' 8.0 min 9.0 min 10.0 min 11.0 min[ 12.0 min i 13.0 min i 14.0 min[ ..... 15.0 min i 16.0 min I 17.0 mini i I ! , 7002si .... l..._6_..9.9._p.s.! ..... , 690 ~o. sj ..... ;_._.6..9..o__p.s.!.__ ; 690,p_jj .... I iI i I i IL ~__~ ........................ CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ZZZZZ;EZ(:,;; . ;,.'E3ZZEEEZJ ......................... ..2...s.t.k_s. ........... J..4..O_p..sj .... J ........................... .4_s.t~.s. ........... ~.o..o..t:,_.s.~ .... .......................... ..S..sj.k..s. ........... s_ j..o_p, sj .... j ......................... _8..s..t~.s. ........... .83.o..EsL...~ ........................... .t 9...sJ.k..s. ....... j ,.o..o..o.. p...s!..j 12 stks 1,200 p. si .......................... .t.6..s..t.k..s. ....... j,.s..s..o..p.~..j .......................... L8..sJ.k..s. ....... J,.gJ.°..P_S.L..j 20 stks 2,010 Esi J .... .1.:o_..m. Ln' ......................... 2,000p. si ! .... ~...o..~[._. ..................... "':.~;~:®:~;i"! ..... ....................... ..... 4..o_.mj..n. ........................... j.,.9..s..o..p..s.L..i ..... .%.o._.mj_n. ............................. j,...97._.o.p..s.[..j 6.0 min 1,970 Esi ..... 7_.P_.mj_.n. .......................... j,.9.Z.O..p, sL.~ 8.0 min 1:970 Esi .~ ,. .... .9_ .0_ _.m.i_n. ......................... 1j970p. si ! 15.0 min 1.,.960 p. si .... .2_o.:.o..mLn. ........................... j.,_9..6..o._p._s[...i .... .2..s.:p_.mj..n. .......................... j.9..6..o..p..s. Lj .... .3_o.:.o....mj.n. .......................... j.,.9.Ao..p_.s!.~ i i 6 CASING TEST and FORMATION INTEGRITY TEST Well Name: TARN 2N-343 Date: 5113198 Supervisor: D. Burley Casing Size and Description: 9 518", 40 ppf, L-80, BTC Casing Setting Depth: 3,340' TMD 2,325' TVD Mud Weight: 9.3 ppg _l:~31e'O~th: EMW = Leak-off Press. + MW 0.052 x TVD 1,170 psi + 9.3 ppg LOT = ' (0.052 x ~ = ~ Fluid Pumped = 6.0 bbl Pump output = 0.1010 bps ' Shut Down pump after 48 strokes, total bled back at cOmpletion of test 3.5 bbls. 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,S00mi 2,400 psi 2,3O0 psi 2,200 psi 2,100 psi 1,900 psi 1,800 psi 1,700 psi 1,500 psi 1;400 psi 1,300 psi 1,200 ~ 1,00o psi 900 psi ,800 psi 700 psi 5OO psi 4OO psi 200 psi 100 psi Omi, 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 ~ LEAK-OFF TEST '~""CASIN~ TEST ,, . Ir ..,il ~" - ~ .... ' 0 2 4 6 8 10 12 14 16 18 20 22 24 26' 28 30 32 34 36 38 40 42 44 46 46 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 stk stk stk stk stk stk stk stk stk stk stk stk stk 'stk stk stk stk stk stk stk stk stk stk stk stk stk slk stk stk stk stk stk stk stk stk stk stk stk stk stk stk S S S S S S S S S S S S S S S S S S S S S S S S $ S S S S S ,S S S S S S. $ S S S S STROKES ,db, ARCO Alaska, Inc. Cementing Details Well N&,~e: 2N-343 Report Date: 05/t0/98 Report Numbec 3 Rig Name: DOYON 14t AFC No.: AK9381 Field: Tam .......... ,-. Centralizel~ Sta~e type used, infervels covered and spacing Comments: , t2 t/4' x 9 5/8" Gemece Bow Spring (40) placement on Casing Detail. Mud Weight PV(p~or cond): PV(aRer cond): I YP(p~or cond): YP(alter cond): Commen~s: 10.5 26 t 6 33 t 8 I Gels before: Gels after. · Total Volume Circulated: 13/t7 71t0 t020 bbls/t250 Wash Type: Volume: Comments: Spacer Stage' tlStage 2 Type: Volume: Weight Comments: ARCO 30130 10.5 Lced Cament Stage t/Stage 2 Typs: I Mixwtrtemp: No. of Sacks:I Weight Yiold: Comments: ASIII 70 t t 0/276 t 0.5/I 0.5 4A214A2 Used A$3 Lil~ Additives: ,, , , ,, Comments: 70 350/60 15.3/t 5.7 t.t Stage t-G cmtfStage ,, , 2a,AStcmt. Additives: Stage I-G w/l'/,S~, 0.2/, 046, 0.3/, D93 $tage2,,A$t standard blend _ , , , Displacement Stage t/Stage 2 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: t 0 t 0 t 35 , Reciprocation length: Reolprc~-'aUon speed: Str. ~ Down: t0 t5 fpm. 75 , Theoretical Displacement Actual Displacemen~ Str. ~ in mud: 244.4/113 248.3/113,8 1 t3 ' Calculated top of cement .' ' ' ~P: Bumped plug: Flcet~ held: Surface through stage =ollar ~ 1488'. ~laga t ~ 2~ hrs ~ ' yes/y~i Stage 2 ~ 0436 hrs on Remarks:Sta~a 1, ~lxed and pumped 93.5 hbl$ A~3 Iit~ at 10.5 ppg Followed by 7t.7 bbls of G+adc~ at t5.8 ppg. preceeclecl ~nt with 5 bbls of water anti 30 bbL~ of Arco Spacer at t 0.5 ppg. Displac~cl with 10 ~ G cmt + 20 bbls wash water + 2t6.34 bhls of t 0.5 ppg mud. Reolprocared casing untlll last 93 hbls of displacement. Had furl rntums while ¢lrculaUng and cementing. Opened stage tool with ~t00 psi, circulated out spacer and 20 hms of cement to surface. . i ~taga 2, Mlxecl and pumped 217 hbls of A~ IIt~ at 10.5 pph followed by 9.8 hhls of A~t at t5.7 ppg. Pmceeclecl =ement with 5 I~1~ of wat~ and ~0 bbls of Arco 'spacer at t 0.5 ppg. DIspla~KI cement with 20 'bbLs wash wator and 93.8 bbls of t0.5 ppg mud. Had full returns during Job, 121 bbls of t 0.5 ppg cemant returns at , Cement Company: I Rig Contractor: , I Appmved By: DS IDOYON iD.BURLEY Casing Detail 9-5/8" Surface Casin.q ,,,~"~ ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: TARN 2N-343 DATE: 519198 I OF I PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LR = 29.91' TOPS Above RKB 9 5/8" Landing Joint 29.91' FMC GEN V- Prudhoe 9 5/8" Csg Hgr 1.73' 29.91' jts. 48-84 9 5/8", 40#, L-80 BTC 1419.17' 31.64' jt. 89 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 37.64' 1450.81' Gemoco 9 5/8" Stage Collar (BAKERLOK) 2.82' 1488.45' it. 88 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 40.37' 1491.27' its. 4-47 9 5/8", 40#, L-80 BTC 1691.53' 1531.64' it. 3 9 5/8", 40#, L-80 BTC (shutoff baffle on top of jt #3, BAKERLOK) 37.19' 3223.17' Gemoco Float Collar 1.47' 3260.36' its 1-2 9 5/8", 40#, L-80 BTC 76.06' 3261.83' Gemoco Float Shoe 1.70' 3337.89' 3339.59' 40 Gemoco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, 88, 89 over stop collars and over casing collars on Jts. 3-14 and over collars of jts. 17,20,23,26,29,32,35,38,41,44,47,50,53,56,59,62,65,68,71,74,77,80, 83 and 84 Joints 85-87 (3 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 11OK# Up,7OK# Dn,2Ok# Blocks. Ran 86 joints of casing. Drifted casing with 8.679 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: Robert L. Morrison Jr. CO~EHVAI~/O~V - 7ONY KNOWLES, GOI~JWO/i 1998 Drill Site .D~c~opmeat Supervisor - .ARCO A]eske, Inc. P.O, BOx 10O360 Ancl~orage, 'AK 995 ]0.0~60 Tan] wells Deer Afr. 2N-32~N-"343 annular, disPOSed requests" Punuant to revi~ng the eddition~l Seo]ogic inronmtioa, ieak--o3test data.~ -' cementing information prose, hied today, the Commission jl.satisficd that sU~cicnt data has been submitted to determine that the waste will be contained in a suitablc reocivin~ zone." end die dJsjx~sai w'dl not contaminate fl'csbwater, ~use dnlling waste to sur~=oe, impair the mcebanlcM Integrit7 of the well used for disposal, damage a pmduc~ or potentially. produoing formation ot impair the recovery of_ca or gas .from a pool;. " Therero~;e,, your.request for a~muler injection into wells 2N-323; 2N-329 and 2N'-343 is' approved. cAsING TEST and FORMATION INTEORITY TEST . . · · Well Neme:' TARN 2N421) .. -. -. ' 8Ult., Rol~,rt.L M ,or~, ,Jr. - · Ca,ing 8iz® ,nd DNcri.ption: _9 S/B", 40 pPf, L-80, .BT¢ -. Cuing setting Depth: _ 3,Z~1' TMO- Mud'Weight _~ '!,OPPg... :" Hole Depth: _ ~.,Zg,' .TVD 4' . -i'.' . i' LOT = (0.052 . Fluid. PumPed - 4.6 bM ' ' _ 2,298' TVD · EIdVV =. L~ak-off.p. res, .~: +'MVV. 0.052 x TVD ' - . - . '. .'- .. -. "12.4 ppg - -. . · - pump output =' 0dO10 bps ; '.Oib2db4ill-8il. lill 10' '12'-14 '-.11 10 I. n" ii: ii .~1 .~0 ii ii x '31' ,e. -. , . · · .. '- LEA,K-OFF. DATA - MINUTES " FOR FIT STROKE8 PRESSURE CASINO TEST DATA i , ,, MINUYES FOR ceo TEST STROKES PRESSURE ARCO Alaska, Inc. Cementin9 Details Well Name: 2N429 Report Date: ~ Report Number. 0 Rig Name: DOYON 141 AFC No.: AKg~9 F. dd:. KRU i - .p_,(~mmentS~. .. Ran 40 Gemeco Baw Spring centralbml. See Daalng Datall for plKeflleof. -- Mud . ' We~h~ PV(p~x con~: PV(e~er concQ: YP(pdor cohoS: YP(e#or con~:' ~enl.: ' .. :: 10.4 20 21 ~.4 18 Sta~ 11 Stage 2. Gels before: Gels altec. Total Volume Circ.lated: -- S/1S 6/14 1070 bbl./634 hMo .. .. ,. , Wamh . 0 - · Type: Volume: Weigh~ Comments:' ', ARCO B..4S SPACER ' 10/0 8.3 Sp'w . '.o. ' ' "' Type: Vmme: ,Comments: " ARCO 30/30' 10.6 stbm"l~Stpg, a. ' ~.' .-. -.. md Content. :.0 ' · ' Type: Mix wtr teml~ . No. of ~ Weight: ' Yield: C0mn~. ' . . A~, '. 70 11W201 lOA/lU ' 4.42/4.42 U.dd ASS.Uk:" , '.., ,. · . . · . . commh~': . . . 70 a20~o 16J/16.7 1.17/I.17" S~i'.~/S~.h ';.., ' ~'.~: G.c.*/.$..,,,.'=., ~' ~d,,~. ' 1 ~ · ' · . . . 5~ng~ 1 - G+OA% D65.1.0~ 601. I## Stng~ 2 · A61 at~nd~rd b~ , '0" .... ' ' ~' Ra~e<bekre tall et ehce): Rag<mil around ahce~ ' ' ~r. W~ Ur. .... ' ''.'".' ' .' 10 10 t06 ~_.1.~..~.__..=. . :.~ . 10 10FPM .. '. Theore~al D~p~cenmnt: A~ual DMp~cemen~ . . ~r. WL h mud. · '.. . ". ' 240.36/109.38 ' 243.TII 110.40 . 6udl~e through lingo cel~ at 143~'. Da~.'4/2Wg~ . yom/yce ylm/yce Tkne:&~gel .0~.68 . Remarks:Stage 1, mixed end pumped BLS bole. AS3 lite at 10.S ppg. Followed by 62.6 bl)l& G + acids at 1S.8 ppg. Prm:eednd cement with S bble water, 10 I)blL . preflU~Jl.at 6.0 wld ~0 bble. epK~r at 10.S ppg. Dieplacnd with 10 hblL G ~ + 20 bble. Wluih water .+ 210.71 bide. 10.4 ppg mull I~d ccelng until 161.S bi)is, of displacement haci been pumpuci. Had full ratum8 while elrculofing and cementing. . Stage 2, mixed end pumped 198 bbls. AS3'Ute Bt 10.S ppg. Followed by 63 bble. AS'I .at 16.7 ppg. Proceeded cement with S bbI.. water md 30 bblB. Arco SFac:er' at 10.S ppg. Displaced with 20 bl~l. 8. wMh water enci 90.46 bbb. 10.4 ppg. mud. Had full tatum8 while dr~ulating amcl c~..' · .. , ., Cement Company: ' DS I Rig Contractor: ., I Approved BY:- DOYON ' · ' I Robert L. Morrison Jr. Casing Detail 9,625' Surface Casino_ ARCO Alaska, Inc. WELL: TARN 2N-329 DATE: 4128198 Subsidiary of Atlantic Richfield Company t OF 1 PAGES - # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEP ~'~-! Doyon 141 RKB to Pad = 29.5' ToPs. - Above RKB -7.06 - 9 5~8" Landing Joint $5.00 -7.06 FMC GEN V- Prudhoe 9 518" Csg Hgr 1.56 27.94 -its. 50-85 9 518", 40~, I.-80 BTC 1368.79 29.50 it. 49 9 518", 40~, L-80 BTC (Thread Locked Collar) 37.60 1398.29 - Gemeoo 9 5~8" Stage. Collar (BAKERLOIO · 2.82 1435.89 - jt. 48 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 38.79 14:38.71 its. 3-47 9 5~8", 40~, L-80 BTC (shutoff baffle on top of it #3, BAKERLOK) 1724.38 14~.50 · - Gemeco Float Collar 1.47 3201.88 - its 1-2 9 5~8", 40~,. L-80 BTC.' 78.00 3205.35 - Gemeco Float Shoe 1.69 3281.35 - 3283.04 _ , , · , . -- ,. , , __ , . - 40 Gemeco Bow Spring CEN i reaLIZERS - Run centralizers in center of Jts. 1,2,. 48, 49 Over stop collars .. - and over casing collars on Jts. 3-14 and over collars of j~s. - 17,20,23,26,29,32,35,38,41,44,47,50,53,56,59,62,65,68,71,74,?? ,80, - 83 and 84 ,' · ,. _ ,. .. --. Joints 86-87 (2 joints) will remain in the pipe shed. . __ . . , ' , . .. ,, · · . , . , · , __ , , . , . · , i , , : __ _ Remarks: String Weights with Blocks: 105K# Up,80K# Dn,20k# Blocks.. Ran 85 joints of casing. - .Drifted casing with 8.679 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. . , . Doyon 14 I' Drilling Supervisor:Robert L. Morrfson Jr. Ilfil · 'TONY CO/~$~RVA~I O~ CO~~IO~ · · .i ]Vlay. 14, 1998 DI~I She Development ARCO Alaska, Inc. · P~O. Box 100360 Purmant to reviev~ng the addi6ona] geolol~c information, leak-off test data,and cememin$ information prcsentcd today, the CommissiOn iS' satisf~d that sut~c~ent data 'has 'been aubrnitt~ to dctmninc that the 'waste will be conta;ne, d in a suitable rec~'ving 3one. and die d~.spdsal will no! contaminate ~cshwater, cause dn'lling waste to SOrfaoe, impair the meehardcal inte~rJt7 oftbe well used. for disposal, damage a produ~ or potentially· producing formation or impair the recov .~ ofoll or gas from a pool,'.. .. ,. · Therefor:e, your..r~lucst for annular injection imo wells 2N-323, 2N-329 .and 2N-343 is' '. ,. '. . ' - CA~ING ANI~ LI;AK-~]FF FRACTURE TF_RT-~ W~ll Name: TARN 2N-323 Date: 4/17J98 Supervisor. R.W. SPRINGER Casing 81ze ,.nd Des~dpt. IQl9 5~8', 40~, L-80~ BTC · Casing 8edln~ Depth: 3461' TMD 2318' - TVD Mud Welghl. 9-50 ,ppg 'EMW., Leak-off F'rassum (Pi+MW LOT., 390 pal / (0.052 x 2310 fl} + 9.Sppg = 16.0ppg . HolaDapth(rnd)=3530' Fluid Pumped..8 bbls Fluid bled bar, k- .8 bbb. 'Pump output..101 bps . STROKES · · . LEAK-OFF DATA MBIUTE8 I:OR FIT STROKE8 PRESSURE lO ; 18 time. lOmln I . . t CASING TEST DATA MINUTE8 FOR CSQ TEB' 8TROKE8 PRESBURI i 4 i e .. ! i i ; ! i ! ! ! 1 · ! i i i i ! ! · ll ~ · CASING AND I-;AK-OF; I=RA_P-TURI= TI;STP Well Name: TARN 2N-328 'Superdsor:. R.W. SPRINGER Date: 4/17/~a - Ca~lng 81ze end Deecdptlorc _ . 9 5/8", 40#7 L-80~ EITC Casing 8qtting Depth: 346]' TIVlD 2316'- TVD . . Mud Weight: 9.50 Ppg EMW, L~ak-off Pre~t~re-~PLO) + MW 0.052 x TVD LOT ,, 1110 psi I (0.052 x 3010 fl) + 9.6ppg, 16.6 ppg Hole DepUt (md),, 4009' Flutt~ Pumped, 2.42 bbb. Fluid bled beck- 2.25 bbb. Pump output, .101 bps 0 2 4 & & 10 12 rd-t6 I~ 20 ~ ~1 26 28 ~Q ~ ~ ~6.~ dO 4 ~' d6 ~'~0 ~2 ~d ~6 ~ ~0 STROKES LEAK-OFF DATA MINUTE8 FOR IqT 8TROKEG PRE~URE 4 :. lO- ; 650 i 760 18 22 ; 111o CASING TEST DATA i ... I MINUTEG FOR C~G TES' STROKE8 PRE~URE i ' :. 2 I o i 640 i 3 0 ; 640 4 - 0 ~ · 640' ~ 5 0 'i 640 :. 0 o i 040 ~. e 0 i e4o i · o [ 640 i lO o !64o · ; ! - i' 1 · ! 1 ! i ! ! ! ! · C:A-~IN~. AN~ Li;;AK-OI=I= I::RACTURI= TI;_=T,~ . Well Name: TARN 2N-323 Date: 4J16,~i ' ..supervisor: R.W. SPRINGER CaMng 81ze and Oesr~lpt. bt 9 5/8", 401, L-80; BTC 'Ceding 8etll~g Depth: 3461' TMD 2310". TVD - Mud Weigll 9.5.___._~__0 ppg EMW = Leek-off Pressure (Pt+MW . .0.082 x LOT, 3g0psl/(0~052xZ310ft) + O.Sppg. 16.0 ppg H01oDepth (md)='3500 Fluid Puml:~d - 2.42 blFluld bled.back. 1.5 bbls. Pump output- .101 bps -0 2 d 6 8 10121d'1618 ~ ~2 24 26 28 30 3~ ~4 36 ~ 40 42 d4 46 dS ~O 62 8d ~6'M ~ SmOkES LEAK-OFF DATA IIINUTE8 FOR FIT SI'ROKE8 PRESSURE I o i o I 2 .'. IT 4 i ~so I_ s ; 3oo I ' 'i I ~o =. 420 - 14 !'530 -~s .-"'s70 . la .= e40 .~'_{ 7,o ;4 ~ 'i - time. ~On~ . CASING TEST DATA MINUTES FOR CSG'[ES' 9TROKES PRESSURE i. · 0 ." ! ilO ': 14 . i- f l' ,i ANNULAI:I INJECTION Ti;ST_ PRESSURE DATA . Well Name: TARN 2N-323 Date: 4/26/98 8upewlsor. R.W. SPRINGER . -. . . Casing 81ze anti Descdptl0n9 6/8"r40~L-80~BTC x 7"~26~ L-80~BTC-MOD ANN ' Casing Setting Depth: 3461' TMD 2316' ' TVD Mud WelgI~.ssW/6.SD8 ppg EMW = Leak-off Pressure (PL,+ MW - 0.052 x TVD · LOT - · /~ ?'~ ,,/~'L ' ' DO\ . . . . . ·.~:~,.~ ~_- Hole Oepth (md)-- 4'999' ' Fluid Pumped %,.~,/bbiRuld bled back= 0.00 bbb. Pump OUtput ,- ,25 -2.0 BPld · . ) t' /--e-, ~ II HE( [101 I i · . . ' 0 2 4 6 a 10 12 14 16 -la 20 22 24 2& 26 30 MINUTES RATE MINUTE8 PRESSURE 0 ; 0 .26 BPM I i 250 _ ' [ s .: :30o ~ . 7 i 4,60 ~ 8 | 450 · 0 ! 450 · lo. i 450 _ 1.0 BPM 11 j 650 - · -- 1.50BPM 16 i ' 875 · 17 ! 675 · 10 i 676 20 ,, i 675 2.0 BPM 21 i ' ' gOO ,- i ' 2~ ~ gOO = 24 i gOO. ..'- 25 ~ gOO ... . ! ! ARCO Alaska, Inc. Cementing Details ,'~;~,o,-; D&~ 04/1~,,~;. Repmt Numbs:. 1 -- Ri~ Na. me: DOYON 141 AFC No.: AKM~ ............... , -------'- TARN .. . . Comments:. .* WEATHE~FORD BOW TfPE, F~ST 14 JTS & Evp.~' ~ ,ITS FROM ~1' 1~' TO SURFACE. · , Commem~' ' -.-~-- ~(er~r =nu)i · .. · , : ~ ~,;~,,-&: GE~ alt~. ToWI Voluml CkculMed: · · . · · 14/11 1~17 ,W0 BBL · . ~,,,. '"..~. "' ~ w,,, w,~ · ~. m~ht~:.. · ARC= B-45 SPACER 10 BBL I~0,10 BBL SPACER GASWlLI~:AL.LOY/... ~._-;~.~. :.'..0 . ~'~; Volume: ~"'!..', , .' ,,Ac= I"0EDL W.~: I'",' ':.::..'""';' ::' ",' . [., · . '14.0 ~ --'='~' r-±'--'~"'" ' : ' ~'*"' T~-~; I IMixwe~"~¢ ,.~.,,..... : ' · 1U. 1.17 · . .... ' .'... . · ~ ........ ,, ...'". · '..' :. ' '.. . .... , .. ... ,':.!,' :'"'": '.'" '"'...' 1%CACI. E~%D85,.~E, D4~. .,~.,.~;;::...:: .. :... :, .: '. ~..~ . , ~ ~ ,. ~ :i!:. 'f.(.. :.:....; :..'2.~ ,': ~ ' .~.~ :......,:' ') &_'__-r.-..~ .:!~.: .,, ..:~..:; , '..... . ,~: '.~ ......~. ~_:/.-::._:..~!.':.i.,'~; '. .... :'"' "':: '": ~;~* ~ '~ ~): ~, ~.':':':... :[' .' ",.':..' ':/""i ' .I~'UM~D~.'U~.. SON ~ ::. :e BFM , . 's A ' i .' ' ,'.-..'., · .~ , ~, :'::".,.~ .; .."..i...:','" ;:i',i'i..':':.~,. '"', '.':i'... 1T,,~-al ~q:,,,~,~-;;; Actual DWenI: ' ' i,'.'~ "'"':. '::. ~ :'. "i. ~., :..'J'.. :~, ' */."' ? ".?' :* .8Ir..WI. in mud: · . C-_-._'c.::.:::~ top'M ~,,,,~;: CP: Sump~l plug:.' Iqo~tm held: .. CMl' TO SURFACE. ON 2ND STAGE. Da~,I/14/II VE~ YE~ . Time:~S0 ' , , . . G~,T,~kS:AS WITH ~tt 2 STAGE CMT ,JOBS THE Ulmi~JG FACTOR I~ PACKOFF AT THE MANDREL HANGER, REDUCED CIRCULATION'RATE Jr DISPLAOEMEI~I'- RATES WERE NECESSITATED ON THE SECOND STAGE~ CEMENT TO sURFACE ON 2ND .. , DS, . i DOYON I R.W. SPRINGER " TARN PARTICIPATING AREA - 2N-323 2N-323 Rot Date 08:Apr-g8 09-Apr-98 10-Apr-g8 10-Apr-g8 10-Apr-98 10-Apr-g8 10-Apr-g8 10-Apr-g8 10-Apr;98 11~Apr-98 . 11-Apr-98 11-Apr-g8 11 -Apr-98 .11-Apr-98 11-Apr-98 '11 -Apr-98 12-Apr-98 12-Apr-98 · . 12-Apr-98 12-Apr-98 12-Apr-98 12-Apr-98. .12?Apr-98 - 12-Apr-98 12-Apr-98. 12-Apr-98 13-Apr-98 mart' 'End 15:00 24:00 .Hole Section MOVE 00:00 24:00 MOVE 00:00 09:00 ·MOVE 09:00 12:00 SURF 12:00 14:00 SURF 14:00 15:00 SURF 15:00 16:00 -SURF . . . 16:00 20:00 SURF 20:00 24:00 SURF 00.'00 02:00 SURF 02:00 02:30-. SURF 02:30' 03:30 SURF 03:30 21:30 SURF 21:30 22:00 SURF 22:00 22-:30 SURF 22:30 24:00 SURF 00:00 03:00 'SURF 03:00 04:30 SURF 04:30 06:30 SURF 06:30 07:00 SURF TvDe Op MIRU . MIRU MIRU MIRU MIRU MIRU-' MIRU MIRU MIRU RIGS· -BHA BOPE DRIL CLN_OUT WIPERTRP DRIL DRIL PRB_WC- pRB_WC .D. RIL · 07:00-10:00 SURF PRB_WC - 10:00 11:30 SURF · PRB_.WC 11:30 13:00 SURF PRB_WC 13:00 13:30 _SURF._ DRIL 13:30 1'4:00 SURF PRB_W{3 . 14:00 24:00 SURF DRIL '00:00 00:30 SURF- DRIL ' Ooerations Tear ·down rig, mo~e camp and pipe-shed from CD2-35 to 2N-323. Remove windwails f~om derrick and lay down derrick. Move subbase, derrick, motor complex, pits, pumps, motors and boilers from CD2-35 to 2N-323. Spot.and Connect components and raise derrick. Install Windwails. Spot pipe shed, place windwalls, R/U rig floor, N/U diverter system. R/U pipe shed, skate and mud pumps. Commence mixing mud. Add additional 15" length 'to diverter riser. RAJ Epoch and Sperry Sun. Charge Koomey unit, function test diverter and accumulator. Tests witnessed by AOGCC's larry'Wade. ' ' ' 'J~aan'~'~lU kelly. Hold pre-spud mestinD w/riD crews, ARCO Projects, EnVironmental, SBfsty and Construction personnel and APC support equipment operators. Finish M/U kelly,.P/U handling tools, N/U riser, set mouse hole. · M/U, orient and Initialize BHA. Mix kill weight mud, continue weighting up active mud · system. Install data and corn cables between rig and camp. Cut and slip 380' of drilling line.. P/U kelly, xo, stb and tag bottom at 108' RKB. Pdme pumps, fill stack, check for. leaks. Spud well and directionally drill 12.25' hole from 108' to 1096'. ' . Pump hi-vis sweep around, observe well. Make 7-stand short trip to' collars and observe well. Hole in good condition. RIH. Drill from 1096' to 1188'. Directionally drill 12.25' hole. from 1188' to 1337'. Background gas inCreased to 1800 units. Cimulate out gas and raise MW from 10.5 to 10.7 ppg. Gas level remained between 325 to 520 units. Circulate out gas and raise MW to 10.9 ppg. Gas level steadied out between 300 and 400 units. Drill from 1337' to 1351'. BU gasWentup to 2000 units, then gradually steadied out between 475 and 550 Units. Circulate out gas and raise MW to 11.1 ppg. Drill from 1351' to 1373'. Circulate out gas. Gas level remained at approx. 1400 units. Circulate and raise MW to 11.3*ppg. Gas level would not come out of 1300 to 1400 unit range. : Drill from 1373' .to 1404'. -CBU to check gas level in mud. No apparent additional gas loading from drilling ahead w/bgg of 1400 units in mud. · Control drill 0 100 fph from 1404' to 2085'. Gas level gradually fell to 150/250 units bgg. Control drill 12.25" hole from 2085' to 2116'. Friday, January 05, 2001 - 1 13-Apr'.98 13-Apr-98 - 13-Apr-98 13-Apr-98 i4-A..pr-98 .14-Apr-98 14-Apr-98 14-Apr-98 14-Apr-98 14-Apr-98 14~Apr-98 14-Apr-98 - 14-Apr-98 14-Apr-98 14-Apr-98 14-Apr-98 14-Apr-98 14-Apr-98 14-Apr-98 14-Apr-98 15-Apr-98 15-Apr-98 15-Apr-98. 15-Apr-98 15-Apr-98 15-Apr.-98 15-Apr-98 -15-Apr-98 15-Apr-98 15-Apr-98 16-Apr-98 16-Apr-98 16-Apr-98 ' 18-Apr-98 16-Apr-98 16-Apr-98 16-Apr-98 16-Apr-98 16-Apr-98 16-Apr-98 16-Apr-98 16-Apr-98 00:30 · 03:00 13:00 -.13:30 00:00 00:30 02:00 03:00 07:00 08:30 10:00 11:00 13:00 14:00 17:00 18:00 19:30 22:00 23:30 00:00 00:30- 02:00 04:00 05:30 07:30 12:00 16:00 18:00 22:00 00:00 ' 00i30 01:30 04:00 06:00 - o~i3o 08:00 08:30 · 10:30 15:00 1'6:00 '17:00 03:00 SURF '13:00 SURF 13:30 SURF 24:00 SURF 00:30 SURF 02:00. SURF 03:00 SURF-' 06:00 SURF 07:00 SURF 08:30 SURF . 10:00 SURF 11:00 SURF 13:00 ' SURF 14:00 SURF 17:00.. SURF '.18:00 SURF. 19:30 SURF -22:00 SURF 23:30 SURF WIPERTRP DRIL PRB_wc DRIL OTHER DRIL CIRC- WIPERTRP WIPER'I'RP CIRC TRIP_OUT ClRC TRIP_OUT CASG · CASG ClRC CASG CASG CASG . 24:00 SURF' 00:30 SURF 02:00 SURF 05:30 07:30 12:00 16:00 18:00 22:00 24:00 00:30 01:30 04:00 06:00 06:30 08:00 08:30 10:30. 15:00 16:00 17:00 20:00- CIRC CASG- Rs_c 0B SURF SURF .SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF-- SURF SURF SURF SURF SURF SURF CAsG CASG . CASG NU_ND NU_ND. NU_ND NU_ND BOPE OTHER 'BOPE -BHA · -BHA ClRC DRIL: DRIL TRIP-IN DRIL CIRC TRIP.OUT - - SURF .BHA- - TARN PARTICIPATING AREA - 2N-323 1 !'stand-wiper trip. Hole tight from 1304' to 1509'. Wiped until free. Control drill from 2116' to 2704'. Cimulate out gas.'Max gas 1900 units. Control drill from 2704' to 3386'. Reduce mud weight to 11.0 ppg. PJSM planned operations - service rig. Drilled from 3386' to 3480'. PumP hi-vis sweep & circ h01e clean. Observe well, pump dry job, POH to 378' - SLM no corr. - RIH to 3480'~ Pump hi-vis sweep &'cim hole clean max gas 2700'. Observe well - dry job - POH to 1575'. Circ .well clean, observe well - pump dry job. Max gas 1200 units. POH - stand back BHA. Rig up to run Casing. PJSM - run casing to 1550'. M/U cim head - CBU -.max gas 369 unite. Cont. RIH w/casing. M/U casing hanger and landing joint. MAJ cement head. R/U &. cim to 6 bpm. PJSM. Test lines to 3500#. Cement as per.p_rogrem - bump plug ~} calc stks ~ floats held - load plug - shear out stage tool ~ 2950#. CBU prep f/2nd stage. PJSM - planned operations r cementing. . . cBu O 1516' - stage collar - lost circ'- packed off ~ casing hanger - flowline and riser plugged wlclabbered mud; unplug same. .Circ and cond mud to 10.9 ppg & 55 vis. Cement as per program, bump plugs, close stage tool ~ 1400 psi Rig down cement head - landing joint & wash out riser. NU diverter system.- Clean surface equip and drip pan of cement - clean out cellar & cellar area. M/U speed head - tbg Spool - APC construction helped orient same-for pipelines. MU adaptor flange --N/U BOPE. Change rams to 5". R/U and test BOPE 250/3500 psi. · PJSM - planned operations.' . Finish testing BOPE - install wear ring.- Lay down BHA &.doWnload MWD. PU BHA & RIH to-1472'.. ' Break circ and test casing to 2000# for 10 min. Drilled cement and stage tool from 1502'-1520'. Test casing to 2000# for 10'min. RIH to 3125'. Break oiro and drilled cement from 3125'_.~3460' float shoe. Displace wl9.5 mud - observe well - pump. dry job. POH f/BHA. M/U bit-mtr-mwd-orient-initialize-load soumes. -Friday, January 05, 2001 - 2 .16-Apr-98 20:00 21:00 16-Apr-g8 21:00 21:30 16-Apr-98 '21:30 22:00 16-Apr-98 22:00 23:00 .16-Apr-98 23:00 23:30 16-Apr-98- 23:30 - 24:00 17-Apr-98 00:00 00:30 17-Apr-98 00:30 01:00 17-Apr-98 01:00 13:30 17-Apr-98 13:30 14:30 17-Apr-98 14:'30 15:30 .17-Apr-98 15:30 22:30 1.7-Apr-98. 22:30 23:00 - 17-Apr-98 23:00' 24:00 18-Apr-98 00:00 00:30- .18-Apr-98- 00:30 05:00- 18-Apr-98 -05:00 06:00 -18-Apr-98 06:00 06:30 18-Apr-98 06:30 21:30 18-Apr-98 21':30 22:30 18-Apr-98 22:30 24:00 19-Apr-98~ 00:00. 00:30 19-Apr-98 00:30 01:30 19-Apr-98 01:30 02:30 · 19-Apr-g8 02:30. 17:30 19-Apr-98 17:30 18:30 · 19-Apr-98 18:30 19:30 19-Apr-98 19:30 24:00 .20-Apr-98 00:00 00:30 . 20-Apr-98 00:30 09:30 20-Apr-98 09:30 10:00 20-Apr-98 10:00 11:00 20-Apr-98 - 11-:00 24:00 21-Apr-98' 00:00 '00:30 21-Apr-98 00:30 07:00 21-Apr-98 07=00 08:00 ' 21'~Ap.r-98-. 08:00 12:30 21-Apr-98 12:30 14~.30- 21-APr-98 14:30 18:00 21-Apr-98 18:00 '19;30 -21-Apr-98 19:30 20:00 21-Apr-98 20:00 21:00 . 21-Apr-98 -21:00 24:00 22-Apr-98 00:00 00:30 SURF SURF SURF SURF SURF SURF SURF SURF. SURF SURF SURF SURF 'SURF. SURF . SURF 'SURF SURF ' SURF SURF SURF SURF -SURF SURF SURF SURF SURF . SURF SURF SURF SURF SURF SURF SURF. .SURF SURF SURF .SURF SURF SURF SURF ~URF SURF SURF SURF' TRIP_IN- BHA. DRIL CIRC OTHER DRIL ' ClRC - .OTHER DRIL _ClRC WIPERTRP DRIL CIRC DRIL OTHER DRIL ClRC W_IPERTRP DRIL ClRC WlPERTRP OTHER - RIGS -TRIP_IN DRIL ClRC WIPERTRP DRIL . OTHER- DRIL OTHER WIPERTRP -DRIL OTHER -DRIL CIRC . WlPERTRP CIRC . TRIp_OUT. 'BHA BHA EVAL EVAL OTHER.- TARN PARTICIPATING AREA - 2N-323 RIH. Kelly up - fill pipe - test MWD O 3465'. Drilled from 3465-3500'. Cim well clean. ~ FIT !6-0 ppg EMW .O 3500'. Drilled from 3500'-3530', 2330' TVD.' ' ' Cim well clean ~ 5030'. Perform FIT 2313' .TVD - 16.0 ppg EMW. Drilled from 3530' to 4473'. AST 2 hr ART 5.2 - Pump Io & hi vis sweep - CBU - observe well - pump dry job. Short trip to shoe ~ 3460' - observe well - RIH. Drill from 4473'- 4999'. AST .5 - ART 3.9 hr. CBU _- perform LOT ¢~ 3o21' TVD to 16.6 ppg EMW. Drilled from 4999'-5092' ART .5 hr. PJSM - planned operations working w/new hands 4 new DoYon roustabouts in training. Drilled from 5092'-5494'. AST .2 ART 2.9 hrs. Sweep hole w/lo-hi vis sweep. Short trip to 4450'. Drillec from 5494~-6515' AST .9 ART 8.8 hr. Pump hi vis sweep - CBU - Observe well - Pump dry job. POH to shoe - most drag occurring in casing. PJSM ~ cutting drilling line. Slip' and cut drilling line. - RIH f/wiper trip. Drilled from 6515' to 7473'. Pump hi - vis sweep - cim hole clean - observe well ~ pump pill. ' Short trip to 6500~ - observe well' RIH. Drilled from 7473' to 7906'. Total day ART 10.1 AST ;9 h'r. PJSM - planned operations - moving on pad. Continue ddlling from 7906-8462' AST 2.4 ART 4. hr. Sweep hole. Short trip to 7423'. Drilled from 8462'-9175' AST 3 ART 4.5 hr. Anticipated TD -9553'. PJSM - tailing pipe. Continue drilling from 9175'-9553'. ART 5.2 hr. -Sweep-hole. Short trip to shoe, monitor well &*RIH to-bottom - no fill. Pump hi:viS sweep -'ciro hole. clean - observe well.- pump pill. -POH - drop rabbit--SLM - no correction. PJaM - unload sources -'lay dn MWD & motor, Clear & olean floor area. ... R/U Schlumberger - M/U logging tools. 'RIH wlFMS-DSI-GR-SP. PJSM - wireline operations. Friday, January 05, 2001 - 3 22-Apr-98 22-Apr-98 22-Apr-98 22-Apr-98 22-APr-98 22~Apr-98 ' 22-Apr-g8 22-Apr-98 22-Apr-98 22-Apr-98 22-Apr-98 22-Apr-98 23-Apr-98 23-Apr-98 23-Apr-98 23-Apr-98 · 23-Apr-98 23-Apr-98 23-Apr-98 24-Apr-g8 24-Apr-98' 24-Apr-g8 24-Apr-g8 24-Apr-98. '24-Apr-98 00:30 05:00 SURF OTHER 05:00 .06:00 SURF OTHER' 06:00 07:00 SURF BHA 07:00 -10:00 .SURF TRIP_IN. ' 10:00 12:00 SURF ClRC 12:00 12:30 SURF OTHER 12:30 18:00 SURF. TRIP_OUT 18:00 18:30 SURF. OTHER- 18:30 20:00 .SURF CASG 20:00 21:00 SURF CASG 21:00 22:30' SURF CASG 22:30'24:00 SURF CASG 00:00 00:3'0 SURF OTHER 00:30 02:00 SURF CASG. 02:00 02:30 SURF CIRC 02:30 08:00 SURF CASG _ 08:00 15:00 SURF ClRC 15:00 18:00 SURF. CASG _ 18:00 24:00 SURF CAS_G 00:00 00:30 SURF OTHER 00:30 01:00 SURF CEMENT" -01:00 02:00 SURF .CEMENT -. 02:00 04:00 SURF NU_ND 11~00 . 14:30 04:00 11:00 SURF RUN_COMP SURF RUN-COMP 24-Apr-98 14:30 15:30 SURF BOPE' 2.4-Apr-98 15:30 20:30 SURF AINJ 24:00 20:30 24;Apr;98. SURF· NU_ND. . TARN PARTICIPATING AREA - 2N-323 Continue Schlumberger lOgs FMS-DSI-GR-SP. Lay down logging tools, R/D Schlumberger. M/U BHA #4. RIH to TD no fill. Sweep hole - drop single shoe ~ pump slug. PJSM - planned operations - sewice rig.. POH laying down:DP & BHA. Clear and clean floor area. Pull wear ring~ Install test plug. Install 7" rems .- test to 2500#. Rig up to run casing. PJSM-'run 4.5' casing tail. Rig down tubing tools. Rig up casing tools. M/U and RIH w/7" casing. PJSM - planned.operati0ns - running casing. Run 7' x 4.5' tapered casing string.. Cim casing volume O shoe. Continue running casing. Circ & condition mud, cut mud Wt f/10.0+ to 9.4 ppg. High initial mud loss O 4 bpm stopping w/lower mud weights and slower pump rates. PJSM - test lines - cement w/420 sx, did not bump plugs, bled pressure off, floats did not -hold. Shut in. ' Wait on cement. Load piPe shed w/tbg and Completion equipment. PJSM~ WAIT ON CEMENT.. -CHECK FLOATS - HELD - R/D CEMENTING HEAD - LANDING JT AND CLEAR FLOOR. INSTALL 9-5/8" X 7' PACKOFF AND TEST TO 5000#, CHANGE TOP RAMS TO 4-1/2" -AND'TEST. -' RIG UP AND Rill W/4-1/2' COMPLETION TBG. TAG UP AND RIH W/SEAL ASSY,'PUMP DOWN BACK SIDE TO vERIFY, P/U AND SPACE OUT - ENGAGE SEAL ASSY AND LAND TBG HANGER. CHANGE OUT 4-1/2' RAMS TO 5'. UNSTING SEAL ASSY-FLUSH 4-1/2" X 7' ANNULUS W/SEA H20,' FREEZE PROTECT TO 2100' W/DIESEL TEST TBG TO 1500 PSI F/10 MIN (DID NOT ATTEMPT TO GO -HIGHER) 4-1/2' X7 ANNULUS T/3500 PSI - INSTALL TWO WAY CHECK. N/D BOP'S - N/U TREE - INSTALL BPV; TEST HANGER TO 5000#. Friday, January. 05, 2001 -4 CSG DETAIL 9.5/8" SURFACE CSG WELL: 2N-323 DATE:. 4/13/98 ARCO ALASKA, INC. 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGYH DEPTH TOPS 9-5/8" Landing Joint wi adapter . 35.00 -2.50 1 FMC 9-5/8" Csg Hgr 1.60 32.50 44 JOints 9-5i8;~, 40#, L-80, ~TC Casing (Jts 51 - 88) 1443.43 .34.10 1 Baker-locked Joint of 9-518", 40~ L-80 Casing (Lock Joint "A' 38.67 14/f.53 1 Weatherford 9-518" '751E' Stage Tool 2.?b 1516.20 1 Baker-locked Joint of 9-5~8", 40~ L--80 Casing (Lock Joint "B" 38.75 .1518.98 41 Joints 9-5i8;, 40~, L-80, BTC Casing (Jts 4 thru 50) 1785.93 1.557.73 I Collar Joint 9-518", 40~ L-80 Casing (Jt #3) 38.11 3343.66 1 Float Collar 1.47 3381. ~' / 1 Baker-locked Joint of 9-518", 40~ L-80 Casing (Jt #2) .39.06 3383.24 1 Shoe Joint, 9-518", 40#, BTC Casing (Jr #1) 36.68 3422;30 1 Float Shoe .1.70 3458.98 Bottom of casing stiln§ .3460.68 , i u ,. i ., .. ii i . , ,. · . , . · . i i " . . ... ...... ,. ,. i ., · · · , , . ; ., , . ,. · . i , , . , .. , Remarks: Baker-Locked float shoe, float collar and. first 3 joints. Ran cen[,alizers 0,3 ;~,-s[ 14 ca'~x-ns, one on every third joint above that to surface, and one each above and below s~,ge tool. , Baker, Locked stage tool and 1 jt each above and below iL . , · i i , DO YON 141 Drilling Supervisor. R. W. SPRINGER WELL PERMIT CHECKLIST FIELD & POOL t./.~(,'~ / ~:~---- COMPANY ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. AP~ DATE 12. " ~_ 7,.~- c~..~ 13. ENGINEERING DATE --~~ WELL NAME 2.J~-3 _~ Z. PROGRAM: exp Permit fee attached ....................... Lease number appropriate.-'~"..,G..c-.~-(~,.~.'~././.~. --.~,./. Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is we,bore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~d_..~-'~ psig. 27. Choke manifold complies w/APl RP-53 (M~'y-84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable .................. dev l/reddl serv wellbore seg ann. disposal para req GEOL AREA ~'4:~(~ UNIT# ~///,~'~ ON/OFF SHORE N N N N N GEOLOG~Y 30. Permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential overpressu~.~.zone~:) ....... 32 Seismic analysis of sh~llnw nas znn~[~ AP~R DATE _ 33. Seabed condition suwey (if off shore) ............. ~ ~,Z~.~34. Conta~namelphoneforweeklyprogressrepods[~plorato~onJy~Y ANNULAR DISPOSAL35. W~th proper cementing records, th~s plan ( ) wdlconta,nwaste,na sultablerece,vmgzone; ....... 'APPR DATE (B) will not contaminate freshwater; or cause drilling waste. to sudace; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Y N Y N Y N Commentsllnstrucfions: m c:~msofficetwordian~diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN. DIXi No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Dec 26 08:51:33 2000 Reel Header Service name ............. LISTPE Date ..................... 00/12/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/12/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit (Tarn Pool) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 3 AK-MM-00069 B. HENNINGSE R. SPRINGER 2N-332 501032032000 Phillips Alaska Inc. Sperry Sun 26-DEC-00 MWD RUN 4 AK-MM-00069 B. HENNINGSE D. GLADDEN MWD RUN 5 AK-MM-00069 J. MARTIN D. GLADDEN 3 9 N 7 E 99 924 153.10 DERRICK FLOOR: 151.77 GROUND LEVEL: 119.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 114.0 7.500 7.625 3907.0 lST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY, AND IS NOT PRESENTED. 3. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4(EWR4), COMPENSATED NEUTRON POROSITY(CNP), AND STABILIZED LITHO DENSITY(SLD). 4. DUE TO A SURFACE-COMPUTER CRASH, THERE IS A DATA GAP OF APPROXIMATELY 18 FEET, LOCATED AT 7920'MD +/-. SEE LOGS FOR EXACT LOCATION. 5. RAPID SAMPLE MEMORY (ON T~IE SLD TOOL) FILLED DURING RUN 3. CONSEQUENTLY, CONVENTIONAL BULK DENSITY AND STANDOFF ARE PRESENTED FROM 10389.5'MD/4472'TVD TO 10957 ' MD/4711 ' TVD. 6. MWD IS CONSIDERED PDC PER E-MAIL DATED 9/28/00 FROM D. SCHWARTZ, PHILLIPS ALASKA, INC.,TO R. KALISH, SPERRY-SUN DRILLING SERVICES. 7. MWD RUNS 1-4 REPRESENT WELL 2N-332 WITH API# 50-103-20340-00. THIS WELL REACHED A TOTAL DEPTH OF 12026'MD/5250'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT~DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBDC = SMOOTHED CONVENTIONAL BULK DENSITY SCOR = SMOOTHED CONVENTIONAL STANDOFF CORRECTION SNPE = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: 9.4-9.7 PPG 400 PPM CHLORIDES 19,149 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE ROP NCNT FCNT NPHI PEF GR RPX .5000 START DEPTH 3800 0 3811 0 3811 5 3813 0 3820 0 3835 5 3841.0 STOP DEPTH 12020 0 11934 0 11934 5 11934 0 11949 5 11971 0 11978.0 RPS 3841.0 11978.0 RPM 3841.0 11978.0 RPD 3841.0 11978.0 RHOB 3904.0 11949.5' DRHO 3904.0 11949.5 FET 3918.0 11978.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 3800.0 6235.0 4 6235.0 11040.0 5 10942.0 12020.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 3800 12020 Mean Nsam 7910 16441 First Reading 3800 Last Reading 12020 ROP MWD FT/H 0 1323.49 GR MWD API 44.5 216.4 RPX MWD OHMM 0.05 23.86 RPS MWD OHMM 0.06 2000 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.02 2000 FET MWD HOUR 0.47 137.01 NPHI MWD PU-S 10.34 60.41 FCNT MWD CNTS 104.4 949.6 NCNT MWD CNTS 13305 30934.9 RHOB MWD G/CM 1.669 3.602 DRHO MWD G/CM -0.215 1.333 PEF MWD BARN 0.08 17 109.79 16441 120.889 16236 4.38101 16238 6.572~9 16238 14.1642 16238 14.7185 16238 1.67653 16084 35.5539 16205 236.545 16210 19284.5 16209 2.27003 16054 0.0765385 16054 3.06478 16222 3800 3835.5 3841 3841 3841 3841 3918 3813 3811.5 3811 3904 3904 3820 12020 11971 11978 11978 11978 11978 11978 11934 11934.5 11934 11949.5 11949.5 11949.5 First Reading For Entire File .......... 3800 Last Reading For Entire File ........... 12020 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 3800.0 NCNT 3811.0 FCNT 3811.5 NPHI 3813.0 PEF 3820.0 GR 3835.5 STOP DEPTH 6235 0 6235 0 6235 0 6235 0 6234 5 6235 0 RPX 3841.0 RPS 3841.0 RPM 3841.0 RPD 3841.0 DRHO 3904.0 RHOB 3904.0 FET 3918.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6235.0 6235.0 6235.0 6235.0 6235.0 6235.0 6235.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 20-JLrN- 00 Insite 4.15 Memory 6235.0 64.9 79.6 TOOL NUMBER PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 7.500 LSND 9.70 46.0 9.1 500 4.6 .800 .529 1.600 1.200 75.0 117.0 75.0 75.0 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD020 GR MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 NPHI MWD020 FCNT MWD020 NCNT MWD020 RHOB MWD020 DRHO MWD020 PEF MWD020 FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU-S 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 G/CM 4 1 68 44 12 G/CM 4 1 68 48 13 BARN 4 1 68 52 14 Name Service Unit Min DEPT. FT 3800 ROP MWD020 FT/H 0 GR MWD020 API 44.5 RPX MWD020 OHMM 0.05 RPS MWD020 OHMM 0.06 RPM MWD020 OHMM 0.06 ,. RPD MWD020 OHMM 0.02 FET MWD020 HOUR 0.72 NPHI MWD020 PU-S 16.12 FCNT MWD020 CNTS 104.4 NCNT MWD020 CNTS 13305 RHOB MWD020 G/CM 1.807 DRHO MWD020 G/CM -0.11 PEF MWD020 BARN 2.2 Max Mean Nsam 6235 5017.5' 4871 1323.49 128.303 4871 158.73 107.868 4800 14.57 4.65164 4789 2000 11.6429 4789 2000 36.8581 4789 2000 38.6433 4789 3.84 1.57985 4635 60.41 40.0848 4845 565.3 186.7 4848 27337.5 17567.7 4849 2.803 2.19412 4663 0.632 0.0372012 4663 17 3.87466 4830 First Reading 3800 3800 3835'.5 3841 3841 3841 3841 3918 3813 3811.5 3811 3904 3904 3820 Last Reading 6235 6235 6235 6235 6235 6235 6235 6235 6235 6235 6235 6235 6235 6234.5 First Reading For Entire File .......... 3800 Last Reading For Entire File ........... 6235 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. 4 .5000 BIT, RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE PEF RHOB GR RPX RPS RPM RPD FET NPHI NCNT DRHO ROP FCNT $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 6235.0 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11040 0 11040 0 10979 0 10986 0 10986 0 10986 0 10986 0 10986 5 10941 5 10941 5 10957 5 11035 0 10942 0 28-JUN-00 Insite 4.15 Memory 11035.0 63.8 74.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 7.500 LSND 9.60 53.0 9.8 40O 4.0 .750 .480 1.300 1.000 75.0 121.0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 NPHI MWD030 PU-S 4 1 68 FCNT MWD030 CNTS 4 1 68 NCNT MWD030 CNTS 4 1 68 RHOB MWD030 G/CM 4 1 68 DRHO MWD030 G/CM 4 1 68 PEF MWD030 BARN 4 1 68 28 32 36 40 44 48 52 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 6235 11040 ROP MWD030 FT/H 0 584.74 GR MWD030 API 59.39 216.4 RPX MWD030 OHMM 1.59 10.63 RPS MWD030 OHMM 1.74 10.87 RPM MWD030 OHMM 1.91 12.78 RPD MWD030 OHMM 2.01 12.85 FET MWD030 HOUR 0.47 137.01 NPHI MWD030 PU-S 13.14 54.46 FCNT MWD030 CNTS 131.5 788.7 NCNT MWD030 CNTS 15882.8 30500.7 RHOB MWD030 G/CM 1.669 3.602 DRHO MWD030 G/CM -0.215 1.333 PEF MWD030 BARN 0.08 4.83 Mean 8637.5 107.019 125.782 4.05122 4.23469 4.47095 4.48969 1.28949 34.4438 246.513 19743 2.28125 0.103345 2.73676 Nsam 9611 9600 9452 9465 9465 9465 9465 9466 9375 9377 9375 9572 9407 9573 First Reading 6235 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235.5 6235 Last Reading 11040 11035 10979 10986 10986 10986 10986 10986.5 10941.5 10942 10941.5 11040 10957.5 11040 First'Reading For Entire File .......... 6235 Last Reading For Entire File ........... 11040 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ..... ~ ...... zSTSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10942 0 11934.0 NCNT 10942 0 11934.0 FCNT 10942 5 11934 5 RHOB 10958 0 11949 5 DRHO 10958 0 11949 5 GR 10979 5 11971 0 RPX 10986 5 11978 0 RPS 10986 5 11978 0 RPM 10986.5 11978 0 RPD 10986.5 11978 0 FET 10987.0 11978 0 ROP 11035.5 12020 0 PEF 11040.5 11949 5 $ LOG HEADER DATA DATE LOGGED: 01-JUL-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.15 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 12026.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE:. 52.3 MAXIMUM ANGLE: 65.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01428NL4 EWR4 ELECTROMAG. RESIS. 4 PB01428NL4 SLD STABILIZED LITHO DEN PB01428NL4 CTN COMP THERMAL NEUTRON PB01428NL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 7.500 DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 400 FLUID LOSS (C3) : 3.U RESISTYVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.700 66.0 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ........................ Datum Specification Block sub-type...0 .936 1.650 1.900 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1. 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 I 68 52 14 125.4 66.0 66.0 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU-S FCNT MWD040 CNTS Min 10942 0 78.65 1 38 1 42 1 38 1 49 0 55 10 34 164.2 Max Mean Nsam 12020 11481 2157 181.96 77.5163 1970 181.7 129.081 1984 23.86 5.30108 1984 26.02 5.48399 1984 25.95 5.62878 1984 25.99 5.76652 1984 45.49 3.75011 1983 50.25 29.7377 1985 949.6 311.198 1985 First Reading 10942 11035.5 10979.5 10986.5 10986.5 10986.5 10986.5 10987 10942 10942.5 Last Reading 12020 12020 11971 11978 11978 11978 11978 11978 11934 11934.5 NCNT MWD040 CNTS RHOB MWD040 G/CM DRHO MWD040 G/CM PEF MWD040 BARN 15333.4 30934.9 21313.2 1.693 2.731 2.40663 -0.113 0.431 0.0418931 1.16 4.02 2.64056 1985 10942 11934 1984 10958 11949.5 1984 10958 11949.5 1819 11040.5 11949.5 First Reading For Entire File .......... 10942 Last Reading For Entire File ........... 12020 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/12/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/12/26 Origin ........... ~ ....... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File oo-o7 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 14 08:04:06 2000 Reel Header Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPEPd%TOR: LOGGING COMPANY: TAPE CREATION DATE': JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-00069 B. HENNINGSE R. SPRINGER 2N-332PB1 501032034070 Phillips Alaska Inc. Sperry Sun 14-DEC-00 3 9 N 7 E 99 924 153.10 DERRICK FLOOR: 151.77 GROUND LEVEL: 119.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 114.0 7.500 7.625 3907.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY, AND IS NOT PRESENTED. 3. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4(EWR4), COMPENSATED NEUTRON POROSITY(CNP), AND STABILIZED LITHO DENSITY(SLD). 4. MWD IS CONSIDERED PDC PER E-MAIL DATED 9/28/00 FROM D. SCHWARTZ, PHILLIPS ALASKA, INC.,TO R. KALISH,SPERRY-SUN DRILLING SERVICES. 5. MWD RUNS 1 AND 2 REPRESENT WELL 2N-332 PB1 WITH API~ 50-103- 20340-70. THIS WELL REACHED A TOTAL DEPTH OF 8684'MD/3712'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: 9.4-9.7 PPG 400 PPM CHLORIDES 19,149 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NCNT 3811.0 8561.0 FCNT 3811.5 8561.5 NPHI 3813.0 8561.0 GR 3835.5 8598.0 RPD 3897.0 8605.0 RPM 3897.0 8605.0 RPS 3897.0 8605.0 RPX 3897.0 8605.0 PEF '3917.0 8577.0 DRHO 3917.0 8577.0 RHOB 3917.0 8577.0 ROP 3918.0 8684.0 FET 3918.0 8605.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 3811.0 8684.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD PU-S 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 3811 8684 ROP MWD FT/H 0.91 1323.49 GR MWD API 44.5 187.08 RPX MWD OHMM 0.05 14.57 RPS MWD OHMM 0.06 15.97 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.02 2000 FET MWD HOUR 0.72 7.53 FCNT MWD CNTS 104.4 612.2 NCNT MWD CNTS 13305 28135.7 RHOB MWD G/CM .1.428 3.043 DRHO MWD G/CM -0.288 0.878 PEF MWD BARN 0.79 9.43 NPHI MWD PU-S 16.12 60.41 Mean 6247.5 104.063 112.492 4.2822 4.51848 6.85358 6.26378 1.95274 214.655 18597.4 2.20974 0.0448173 3.46767 37.3667 Nsam 9747 9533 9526 9417 9417 9417 9417 9375 9501 9501 9321 9321 9321 9497 First Reading 3811 3918 3835.5 3897 3897 3897 3897 3918 3811.5 3811 3917 3917 3917 3813 Last Reading 8684 8684 8598 8605 8605 8605 8605 8605 8561.5 8561 8577 8577 8577 8561 First Reading For Entire File .......... 3811 Last Reading For Entire File ........... 8684 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. 2 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR RPD RPM RPS RPX PEF DRHO RHOB ROP FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 3811.0 3811.5 3813.0 3835.5 3897.0 3897.0 3897 0 3897 0 3917 0 3917 0 3917 0 3918 0 3918 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : STOP DEPTH 8561 0 8561 5 8561 0 8598 0 8605 0 8605 0 8605 0 8605 0 8577 0 8577 0 8577.0 8684.0 8605.0 20-JUN-00 Insite 0.41 Memory 8684.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 64.9 79.6 TOOL NUMBER PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 7.500 7.6 Water Based 9.70 46.0 9.1 4O0 4.6 .800 .529 1.600 1.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 75.0 117.0 75.0 75.0 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 FCNT MWD020 CNTS 4 1 68 NCNT MWD020 CNTS 4 1 68 RHOB MWD020 G/CM 4 1 68 SC02 MWD020 G/CM 4 1 68 PEF MWD020 BARN 4 1 68 NPHI MWD020 PU-S 4 1 68 16 20 24 28 32 36 40 44 48 52 5 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 3811 8684 ROP MWD020 FT/H 0.91 1323.49 GR MWD020 API 44.5 187.08 RPX MWD020 OHMM 0.05 14.57 RPS MWD020 OHMM 0.06 15.97 RPM MWD020 OHMM 0.06 2000 RPD MWD020 OHMM 0.02 2000 FET MWD020 HOUR 0.72 7.53 FCNT MWD020 CNTS 104.4 612.2 NCNT MWD020 CNTS 13305 28135.7 RHOB MWD020 G/CM 1.428 3.043 SC02 MWD020 G/CM -0.288 0.878 PEF MWD020 BARN 0.79 9.43 NPHI MWD020 PU-S 16.12 60.41 First Last Mean Nsam Reading Reading 6247.5 9747 3811 8684 104.063 9533 3918 8684 112.492 9526 3835.5 8598 4.2822 9417 3897 8605 4.51848 9417 3897 8605 6.85358 9417 3897 8605 6.26378 9417 3897 8605 1.95274 9375 3918 8605 214.655 9501 3811.5 8561.5 18597.4 9501 3811 8561 2.20974 9321 3917 8577 0.0448173 9321 3917 8577 3.46767 9321 3917 8577 37.3667 9497 3813 8561 First Reading For Entire File .......... 3811 Last Reading For Entire File ........... 8684 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. · Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 14 08:04:06 2000 Reel Header Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-00069 B. HENNINGSE R. SPRINGER 2N-332PB1 501032034070 Phillips Alaska Inc. Sperry Sun 14-DEC-00 3 9 N 7 E 99 924 153.10 DERRICK FLOOR: 151.77 GROUND LEVEL: 119.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 16.000 114.0 2ND STRING 7.500 7.625 3907.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY, AND IS NOT PRESENTED. 3. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4(EWR4), COMPENSATED NEUTRON POROSITY(CNP), AND STABILIZED LITHO DENSITY(SLD). 4. MWD IS CONSIDERED PDC PER E-MAIL DATED 9/28/00 FROM D. SCHWARTZ, PHILLIPS ALASKA, INC.,TO R. KALISH, SPERRY-SUN DRILLING SERVICES. 5. MWD RUNS 1 AND 2 REPRESENT WELL 2N-332 PB1 WITH API# 50-103- 20340-70. THIS WELL REACHED A TOTAL DEPTH OF 8684'MD/3712'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMpENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: 9.4-9.7 PPG 400 PPM CHLORIDES 19,149 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NCNT 3811.0 8561.0 FCNT 3811.5 8561.5 NPHI 3813.0 8561.0 GR 3835.5 8598.0 . RPD 3897.0 8605.0 RPM 3897.0 8605.0 RPS 3897.0 8605.0 RPX 3897.0 8605.0 PEF 3917.0 8577.0 DRHO 3917.0 8577.0 RHOB 3917.0 8577.0 ROP 3918.0 8684.0 FET 3918.0 8605.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 3811.0 8684.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD PU-S 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 3811 8684 ROP MWD FT/H 0.91 1323.49 GR MWD API 44.5 187.08 RPX MWD OHMM 0.05 14.57 RPS MWD OHMM 0.06 15.97 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.02 2000 FET MWD HOUR 0.72 7.53 FCNT MWD CNTS 104.4 612.2 NCNT MWD CNTS 13305 28135.7 RHOB MWD G/CM 1.428 3.043 DRHO, MWD G/CM -0.288 0.878 PEF MWD BARN 0.79 9.43 NPHI MWD PU-S 16.12 60.41 Mean 6247.5 104.063 112.492 4.2822 4.51848 6.85358 6.26378 1.95274 214.655 18597.4 2.20974 0.0448173 3.46767 37.3667 Nsam 9747 9533 9526 9417 9417 9417 9417 9375 9501 9501 9321 9321 9321 9497 First Reading 3811 3918 3835.5 3897 3897 3897 3897 3918 3811.5 3811 3917 3917 3917 3813 Last Reading 8684 8684 8598 8605 8605 8605 8605 8605 8561.5 8561 8577 8577 8577 8561 First Reading For Entire File .......... 3811 Last Reading For Entire File ........... 8684 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. 2 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR RPD RPM RPS RPX PEF DRHO RHOB ROP FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 3811.0 8561.0 3811.5 8561.5 3813.0 8561.0 3835.5 8598.0 3897.0 8605.0 3897.0 8605.0 3897.0 8605.0 3897.0 8605.0 3917.0 8577.0 3917.0 8577.0 3917.0 8577.0 3918.0 8684.0 3918.0 8605.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : 20-JUN-00 Insite 0.41 Memory 8684.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 64.9 79.6 TOOL NUMBER PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 PBO1543FGRV4 7.500 7.6 Water Based 9.70 46.0 9.1 400 4.6 .8O0 .529 1.600 1.200 75.0 117.0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 FCNT MWD020 CNTS 4 1 68 NCNT MWD020 CNTS 4 1 68 RHOB MWD020 G/CM 4 1 68 SC02 MWD020 G/CM 4 1 68 PEF MWD020 BARN 4 1 68 NPHI MWD020 PU-S 4 1 68 16 20 24 28 32 36 40 44 48 52 5 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 3811 8684 ROP MWD020 FT/H 0.91 1323.49 GR MWD020 API 44.5 187.08 RPX MWD020 OHMM 0.05 14.57 RPS MWD020 OHMM 0,06 15.97 RPM MWD020 oHMM 0.06 2000 RPD MWD020 OHMM 0.02 2000 FET MWD020 HOUR 0.72 7.53 FCNT MWD020 CNTS 104.4 612.2 NCNT MWD020 CNTS 13305 28135.7 RHOB MWD020 G/CM 1.428 3.043 SC02 MWD020 G/CM -0.288 0.878 PEF MWD020 BARN 0.79 9.43 NPHI MWD020 PU-S 16.12 60.41 First Last Mean Nsam Reading Reading 6247.5 9747 3811 8684 104.063 9533 3918 8684 112.492 9526 3835.5 8598 4.2822 9417 3897 8605 4.51848 9417 3897 8605 6.85358 9417 3897 8605 6.26378 9417 3897 8605 1.95274 9375 3918 8605 214.655 9501 3811.5 8561.5 18597.4 9501 3811 8561 2.20974 9321 3917 8577 0.0448173 9321 3917 8577 3.46767 9321 3917 8577 37.3667~ 9497 3813 8561 First Reading For Entire File .......... 3811 Last Reading For Entire File ........... 8684 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/12/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File