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198-020
) Image Project Well History File Cover 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. _ 1 ø - 0 ~ Well History File Identifier Organizing (done) ~O-Sided 11I11111I" 11/11111 ~scan Needed REJCAN '(;i Color Items: o Greyscale Items: DIGITAL DATA ~iskettes, NO.~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: Helen ~aria .) o Other:: I '. .!) Date:D 10 05 /5/ ¥11' I - Project Proofing BY: Helen~ Date: 6 i C' 05' /5/ ~ Scanning Preparation BY: Hele~ {CJ x 30 = ~ ø 0 + I = TOTAL PAGES 1011 (Count doe!.. ", at irSIU. de cover sheet{ I/IA-i) Date: b Ie¡ 0$ /5/ r Vfl I. I . BY: Production Scanning Stage 1 Page Count from Scanned File: I c¡ ~(count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO Helen CMa~ ) Date: 6, t 7, os /5/ If NO in stage 1, page(s) discrepancies were found: YES NO .::; rn Stage 1 BY: Helen Maria Date: /5/ III III 'I Date: /s/ Quality Checked I1III1III1111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: Saved as M:/weepie/microfilm_marker.doc MICROFilMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE --------, 1'1 'I) ) ./ . ~'. ./ ,...:...~..,................'........,..,/ /..... GL II Ð I ~....\. ~..... ,........ ............~............... ...¡f. d,' 1 '. 'U¡ :...~.................'../' . ~. f" \, ) ) ') ----_._--_._----,.------._,,------~.._,---_.._----~,- ) Well Compliance Report _~__~____..___.,___ .___.__·_w___...______....._......_., "_._._...___.,._. .___.___"._.__..__._...,.__.______._..."._. '.-"-"_ -_,,,.,,,__.,.._., ..--.-_.._...__._____..____.._.___..._._. .._"._'__."...._'.__.___.____'_ _'.".n ,___...~___ __'''''''__''0'_'. _~ ...___"'_._."___."_.~. "" _,,____, ._..._n__ --.----..-...---....-...--...... .,.,,---.-.---.,.--..--.- .-...,-----., 50~ 103~20252-00 ARCO KALUBIK MD º_5Çj5Q ... TVD _Q~_(j~Q_/ Completion Dat~'. Interval -.~..~;~~...---. ... ----.--..----..--. 204 7;p~~~~~~P;~~~~~~·-· ~~900-5150 ~. 2526-5650 A· 2526-5650 ~AL 2505-5620 ç ~f ~~L 2505-5620 ~ 'l ~~0-5487 ~5650 L PEX-NDT/GR/MCFL FINAL ¿5627 FINAL ~2-5255 ~~5032 MD 198-020-0 2 T Name ",."....' J12t28. Completed Status: :e~A_._._ Current: Sent Received __ .___ ___._. _.__..._...____.___n_ .__._~_,~.._'n___._~._..____ ___...__.__".__ ___._,__ __.".~.._ OH OH 5 OH OH OH OH CH 5 OH 2 OH OH L CMRI-QC L DGR/EWR4-MD L DGR/EWR4-TVD L DSSI L DSSI L JUNK/OR/CCL L MUD L RFT R CORE DESCRIPT I R CORE DESCRIPT 2 ~2-5122 MD (Á'~50 OH R MWD SRVY R PROF PERM I ,.,(9'50-5027.25 MD R PROF PERM 2 ~-5097.25 MD R WELL RESUME ~) 110-5650 OH 2 R WELL SMMY ~1 TOPS 3270-7000 OH T 8341 I ~~UM PEX-DSVCMR/FMI OH Daily Well ops:).l~¿ftm ).·P/.Ç(¡} Are Dry Ditch Samples Required? yes ~. Was the well core~ no Analysis Description Received(~ no Comments: 4/9/98 4/9/98 4/2/98 4/3/98 4/9/98 4/9/98 4/9/98 4/9/98 4/2/98 4/3/98 4/2/98 4/3/98 4/2/98 4/3/98 4/6/98 4/7 /98 4/2/98 4/3/98 4/2/98 4/3/98 3/1 7/98 3/18/98 3/17/98 3/18/98 4/9/98 4/9/98 3/1 7/98 3/1 8/98 3/1 7/98 3/1 8/98 5/1 8/98 5/19/98 3/17/98 3/1 8/98 4/2/98 4/3/98 And Received? yeK'o' Sample Set #...._______u .. .------..-.----....-- ----,.. .------ ----.--., -..- ~-_. _.__._--~---- ..---- .- -----_._-~--,_._...__....._-_..-..._-_.- .- --t)-~..~~.::>--------~--~..-..--.-. .~...~--~--.-~-..-..._-.--.-.--..-.------.---..---.-.-.~._---.---..~------._.~---~_.~---..--.--.._.---~-----.----~-- - __. .._____ - _n.____..._ _ ___n ______~___ ....__~_____., ~ ._...."_ .______ .._ .._ __________._____. .n,._..__ ------.-- ~---_...._- --------..-- . .,.------- "------"-'- -..--.-'--'-- ~ ,'1 -----------.. .-.-------- ------~.._-_._--_.._-_.-..__.__.- --~.- --- -._.---- - ---- - .-- ~,------_._._-." _.~ -_._-_._----~--_. - -""--- -.-- --------_. .__.-. ...'-'- ...-. -...-- .-.- .... -- ---- ----..,---.--.---,.,,--.--- .------ Tuesday, April 04, 2000 -----.- -._' ---.----.-- . _..__..._, .,._ _....._.n_.. "_.._._ . ~'-_._.'--- -. ~ .....-..-. --- ____._........__~'___n.___ T/C/D Page I of I ) ) D ARCa Exploration Company <> D ARca ail and Gas Company Record Of Shipment Of Confidential Information ....... ...,. ŒJ ARC a Alaska, Inc. <> District: Alaska To: Alaska State Oil & Gas Conservation Comm. From: ARCO Alaska, Inc. 3001 Porcupine Dr. P. O. Box 100360 Anchorage, AK. 99501 AnchoraQe, Alaska 99510-0360 A T01440 Attn.: Howard Oakland (907) 793-1235 Attn.: Steve Benzler (907)265-1666 (X) Enclosed ( )Under separate cover Subject: Kalubik No.2 & 3 Wells 9~¡~b;).b ~I Quantity ( )Via ~ '18· OOS Map number & description 1 FINAL REPORT of Dean Stark Analysis for Arco Alaska Kalubik NO.2 & 3 Wells Note -'Pleasf;verrfy'snd 8ëkriowl8dqe'riéilp~'tiy'~8Iaï,'riQ¡nCl rëtumlnaä 'copy'õ"thlstransmlttai. Signed by -()~ Date C:r_ Sept. 23,1998 Received by Date Remarks: RECE\VED SEP 22. '\998 AI_a 0\1 &. Gas Coos. Commission Anchorage ') ) D ARCa Exploration Company <> D ARCa Oil and Gas Company <> Œ] ARCa Alaska, Inc. Record Of Shipment Of Confidential Information A V District: Alaska To: AK Oil And Gas Conservation Commission Attn.: Lori Taylor 3001 Porcupine Drive Anchoraqe, AK 99501 From: ARCO Alaska, Inc. Attn.: Joy Burk ATO-1455 Post Office Box 1 00360 AnchoraQe, Alaska 99510-0360 (X) Enclosed G\b/ O--ýJ ( )Under separate cover ( )Via KALUBIK #2 Mud Log Report Summary & Conclusions replacement page - Section 15- T13N-R7E, Colville Delta Kuparuk As presented by Epoch Well Lo~~in~, Inc. * Please replace the Kalubik #2 Final Mud Log Report Summary and Conclusion Page with the enclosed insert. Thank you. (' Note - Please verify and acknowledqe receipt, by siqninq and returninq a copy of this transmittal. Signed by ") Date Received by ,:1;_ UrN I tAL 6/8/98 Date Remarks: Please Note that all included information is CONFIDENTIAL. , -. ,........ ~: ~ \}; 7,,: :...... ..... .- ":'u.J ,\ Page 1 ~ :23r<.2 ;...¡~i ~\ ~,':J.3 l;nns. L~'~ r~~:·j¡·~SH~ '~r;~c·:::lqe PLUGGIN(~)& LtCATIiN CLEAF.JNCE REPORT State of Alaska . ALASKA OIL & GAS CONSERVATION COMMISSION . PTD No.9B -oCJ2v Lease IlD/J ~~,-"')-jb.3 h ~-1 e:m c =- al! ¿ 1.L-r:1 'T 0 F i 1 e: -~-P I No. ,"5V ?' /0,<: ....¿) 0 r2 f) c!) - 00 Well Na1I1e ¡¿¡qL,U~; /1... fi~ Op era tor j)fð;l 4¿J7!.;.')(.19} T NC!.. . Locat:'on [)t.Or~/-); //.$tV/ J27¿;; ¿JIÎ1 SP~d*/ 9.9. , 0ì~, Abnd Date 3/09/9f5 Completed 3/()9~(R TD: Note casing size, wt, dep~, c=t vol, & procedure. Sfc Csg: /fJlt Ý0.FJ III ))r¿:rUPN Long Csg: 90/;1/ .L.88 ~~/3 £23'1.9f/J.9 11.11- I~sx {!/.,ss Q,. Liner: 7 II .tOO ~b.-·~3 ~SOSX (lJASS c:, Per: interrals - ~cps: ~ Review t~e well file, and, comment on'plugging/ well head status, and location clearance - provide loe. clear. code. Plugs: Well head cut off:' ~~N'n Marker 'post or plate: ....¡..¡.. . t\}r1 . Location Clearance: ~ f\) ()) - Conclusions: ~~~~ ~ ::lEa, q!~~ -ff"AJ "'-~ ~¿j 47V. \ð,~~?OJ..~....¿7() I Code ~ . . Signed re/~ L/-/3r-~Y Date - . - -------. . ---- --"-'. . .' ..-. . - .--...- --- - - --"---.'-- f;,¡.th ~ ~ oJ.; ¥ J ') ) 1 Status of Well STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well OIL 0 GAS 0 2 Name of Operator ARCO Alaska, Inc 3 Address P,O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 1099' FNL 2124' FWL Sec. 15 T13N A7E. uJí~ï'h;:l~";,¡¡it¡ ~ ' , " it r~, " .~.-: ~ At Top Producing Interval ~3 /~di\,:!; q (7 ~ ' " "!~..':..I-~_<:J-L2.X_ ~ 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E. UMJ\';E1U~lEn ~ ' . '"" I '-.-r.i\ At Total Depth I ~".... ~. .., ,.' ' ¡. ", ", ,I 1 099' FNL, 2124' FWL, Sec. 15, T13N, A7E. UML:......:::::;::;:::;. .""..' ,Jf¡."" 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. SUSPENDED 0 ABANDONEŒ] SERVICE 0 7 Permit Number 98-0020, 398-043, 398-062 8 API Number 50-103-20252-00 9 Unit or Lease Name Kuukpik Unit 10 Well Number Kalubik #2 11 Field and Pool Kuukpik Unit Kuukpik Unit RKB 32' 12 Date Spudded 07-Feb-98 17 Total Depth (MD+TVD) 5650' MD & 5650' TVD 13 Date ToO. Reached 15-Feb-98 18 Plug Back Depth (MD+ TVD) 75' MD & 75' TVD ADL 355036 ALK 4539 14 Date Compo , Susp. or Aband. 09-Mar-98 19 Directional Survey YES ~ NoD 115 Water Depth, if offshore 116 No. of Completions 2' feet MSL N/A 20 Depth where SSSV set 21 Thickness of permafrost NA feet MD 1465' APPROX 22 Type Electric or Other Logs Run Gr/Res (MWD), DSI, CMR, FMI, RFT, PEX 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I BTM HOLE SIZE CEMENT RECORD CASING SIZE WT GRADE TOP 16" 151,5# X-65 SURF. 9.625" 40.0# L-80 SURF. 7" 26.0# L-80 SURF. 111' 20" Driven 2513' 12.25" 284 sx AS IIIL & 250 sx Class G 5633' 8.5" 250 sx Class G set retainer at 268' RKB I 24 Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25 SIZE N/A TUBING RECORD DEPTH SET (MD) PACKER SET (MD) NONE 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 Date First Production PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Date of Test N/A Hours Tested PRODUCTION FO OIL-BBL TEST PERIOI : CALCULATED OIL-BBL 24-HOUR RATE: N/A GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure GAS-MCF WATER-BBL OIL GRAVITY-API (corr) 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Refer to Attachment A OR~.G~'NAL :;') ~... ...... \- I \ " ..- n ~,,~ t {", t I / it: L) n~. (,~ lqOQ . '. ...J ...... ..........~'.' Form 10-407 Rev, 7-1-80 ~'\¡aska OJ¡ D, Cas Cons. COffimissi)r! Anchorage Submit in duplicate CONTINUED ON REVERSE SIDE ) ) 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. C-80/K-10 C-40/K-5 C-35/K-3 K-2 2942' 3163' 4155' 5130' 2908' 3129' 4121' 5096' NO TEST TAKEN 31, LIST OF ATTACHMENTS Summary of Dally Drilling Reports, Directional Survey, As-Builts, Core Descriptions and P&A Wellbore Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,j~.l ¡.Lc Title .1Ate;.. é,A/¿,'A,. DATE r /8 j1 f1 Prepared by Name/Number Sharon Allsup-Drake7263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc,). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 FLOAT COLLAR AT 5550' TVD(MD) 7" PRODUCTION CASING AT 5633' TVD(MD) ESTIMATED CEMENT TOP: 4400' TVD(MD) 9-5/8" SURFACE CASING AT 2513' TVD(MD) 9-5/8"x7" ANNULUS CMTD DOWN TO +/-18001 CEMENT PLUG IN 9-5/8" CSG 2681-325 .~...'.'..."....'.."'..;'.;..'...................'............................... ~ 10.3 LB/GAL MUD iv ~ TD AT 5650' TVD (MD) PBTD AT 5487' TVD(MD) CSG CUTOFF AT 3251 16" CONDUCTOR 761 BML SURFACE CEMENT PLUG 751-2681 CEMENT RETAINER AT 2681 9-5/8" SURFACE CASING CUT OFF AT 551 RKB (201 BML) 16" CONDUCTOR CUT OFF AT 501 RKB (151 BML) ) ) KALUBIK #2 ACTUAL P&A WELLBORE DIAGRAM 3/15/98 Well Name: API #: Rig: Elevation: Total Depth: Completion Status: Geolog ical Tops: C-80/K-10 C-40/K-5 C-35/K-3 K-2 Total Depth ) ) WELL SUMMARY ARCO Kalubik #2 50-103-20252-00 Doyon 141 G.L. = 4.7' K.B. =34' 5650' MD (-5616' SS) driller Plugged & Abandoned MD 2942' 3163' 4155' 5130' 5650' SSTVD 2908' 3129' 4121' 5096' 5616' Conventional Cores: Aluminum barrel 4" inner diameter Core #1 - Cut 4950'-5032' Recovered 4950'-5027.25' (82'/77.25') Core #2 - Cut 5032'-5122' Recovered 5032'-5098.25' (90'/66.25') Sidewall Cores: none .~ ,,"~ ;',~~ ~~, ~, :J ',ti ::.::uw, '. ~," :\.. ;;, ·'1 ('~' " \ " '. ARca Alaska, Inc. ) ) Core Chip Description .AIi.. -.-" Operator and Well Name: Section of ARCO Alaska, Inc. Kalubik 2 11 Location: Date 70.484882 deg N, 150.306061 deg W March 17, 1998 Core #1: 4950-5032' MD Recovered: 77.25 of 82 ft Depth Rec, Description Oil Oil Fluor Cut Cut Show ft in, Stain O:tr % Intensity Color color fluor Summary 4953 Sampled 100% frozen fill @ btm of destructively drilled 8.5" hole 4956 Sits: tan-It gry, crs sit, qtzose, minor scat brn Strong 80 dull gold dk straw fast strmg Good lithics, sbang, w srt, mod indur, p por. mod mlky wht 4959 Slts-Ss: It brn, crs slt-vfL, qtzose, even brn Strong 100 dull gold It amber fast strmg V Good minor lithics, sbang, mod w srt, mod mod mlky indur, p por. wht 4962 Sits: It gry, qtzose, sl carb, minor even It Strong 90 dull gold pale slow strmg Fair lithics, sbang, w srt, mod indur, p por, brn straw wk-mod lam. mlky wht 4964 Ss: brn, vfU, s&p, micac, ang-sbang, even dk Strong 100 dull gold amber fast strmg Excellen W srt, mod indur, f-g por. brn strong mlky t yel-org 4967 Sits: It gry, qtzose, tr carb debris, even It Strong 95 dull gold pale slow strmg Fair minor lithics, sbang, w srt, mod indur, brn straw wk-mod p por, lam. mlky wht 4970 Ss: It brn, vfL, s&p, micac, ang- even Strong 95 dull gold It amber fast strmg V Good sbang, w srt, mod indur, f por. med brn mod mlky yet 4973 Slts-Ss: It brn, crs slt-vfL, qtzose, even It- Strong 100 dull gold straw slow strmg Fair minor lithics & carb debris, sbang, med brn wk-mod mod w srt, mod indur, p por, ripple mlky wht xlam. 4976 Slts-Ss: It brn, crs slt-vfL, qtzose, even It- Strong 100 dull gold straw slow strmg Fair minor lithics, micac, sl carb, sbang, med brn mod mlky mod w srt, mod indur, p por. wht 4979 Slts-Ss: It brn, crs slt-vfL, qtzose, even It- Strong 100 dull gold straw fast strmg Good minor lithics, micac, sl carb, sbang, med brn mod mlky mod w srt, mod indur, p por. yel wht Remarks Described by P. L. Decker, J. D. Corrigan AH3t3-2389-B ARca Alaska, Inc. .;I... ), } Core Chip Description "'I"" Operator and Well Name: Section of ARCO Alaska, Inc. Kalubik 2 2 13 Location: Date 70.484882 deg N, 150.306061 deg W March 17, 1998 Core #1: 4950-5032' MD Recovered: 77.25 of 82 ft Depth Rec. Description Oil Oil Fluor Cut Cut Show ft in. Stain Q:tr % Intensity Color color fluor sum 4982 Ss: med brn, vfL-vfU, s&p, sl micac, even brn strong 100 dull gold amber v fast strmg Excellen sl carb, ang-sbang, w srt, mod indur, f mod-strong t por, fnt lam. mlky yel org 4985 Slts-Ss: It gry-brn, crs slt-vfL, qtzose, Ss:even strong 100 dull gold straw fast strmg Good minor lithics, micac, sl carb, sbang- brn mod mlky yel subrnd, mod w srt, mod indur, p-f por, Sltst: tr- wht interlam. none 4988 SIt: It gry, qtzose, sl micac, sbang, w trace weak trace dull gold none v slow strmg Poor srt, w indur, w lam. wk-mod pale grn wht 4991 Slts-Ss: It brn, crs slt-vfL, qtzose, even strong 100 dull gold It amber fast strmg V Good minor lithics, micac, sl carb, sbang- brn mod-strong subrnd, w srt, mod indur, f por, lam. mlky yel 4994 Sh: It gry, sl slty, firm, w lam, subfiss. none weak? 5 dull gold It amber slow strmg Fair wk pale grn 4996 Ss: It-med brn, vfL, s&p, micac, carb, even strong 90 dull gold It amber mod fast Good sbang, w srt, mod indur, f par, fnt lam. med brn strmg mod- strong yel wht 4999 Ss-Slts, It brn-gry, crs slt-vfL, qtzose, Ss:even strong 100 dull gold straw - slow strmg Fair- minor lithics, sl micac, tr carb, ang- brn pale straw mod mlky yel Good sbang, w srt, w indur, fine sh intbds, wht ripple xlam. 5002 Ss: brn, vfL, qtzose wI fine lithic-rich even brn strong 100 dull gold amber fast strmg V Good interlams, w srt, w indur, f por. mod-strong mlky yel org 5005 Ss: It brn, vfL, qtzose to s&p, micac, even It strong 100 dull gold It amber slow strmg Good ang-subang, w srt, w indur, f por, fnt brn mod mlky yel lam. wht 5008 Sh: It gry, sl slty, firm, w lam, subfiss. none none 0 v slow v wk Trace pale grn Remarks Described by P. L. Decker, J. D. Corrigan AK3B-2389-B ) ) ARCa Alaska, Inc. A.... Core Chip Description ~,. Operator and Well Name: Section of ARCO Alaska, Inc. Kalubik 2 3 13 Location: Date 70.484882 deg N, 150.306061 deg W March 17, 1998 Core #1: 4950-5032' MD Recovered: 77.25 of 82 ft Depth Rec. Description Oil Oil Fluor Cut Cut Show ft. in. Stain O::b' % Intensity Color color fluor sum 5011 Sh: It gry, sl slty, firm, w lam, subfiss. none none 0 none v slow wk Trace pale grn 5014 Sh: It gry, outsize micac, carb flakes, none strong 35 faint gold pale slow strmg Fair firm, w lam, subfiss. straw wk-mod yel wht 5017 Sh: It gry, sl slty, firm, w lam, subfiss. none mod 5 none v slow strm Poor v wk pale grn 5020 Ss: It brn, vfL, qtzose to s&p, micac, even strong 100 dull gold amber fast strmg V Good ang-subang, w srt, w indur, f por, fnt med brn mod mlky lam. yel org 5023 Slt-Sh: sit It brn gry, qtzose, micac; SIt: even strong 15-20 faint gold pale slow strmg Poor- sh It gry, firm. v brn; straw mod yel Fair Sh: wht none 5026 Slt-Sh: sit V It brn, crs sit, qtzose, sl SIt: even strong 90 dull org- straw mod fast Good micac; sh It gry, subfiss, sl micac, fnt It brn, brown mod yel ripple interlam. Sh: tr wht Remarks Described by P. L. Decker, J. D. Corrigan AH31:3-2389-B ), ) ~ Y'r~LA Profile Permeability Data i J.. J~. J ARCa Alaska, Inc. Well: Kalubik #2 Core # 1 4950.00 - 5027.25 ft. 1;1::::'ili:"g~Û}li¡I,:i:,.II:,::I: il~p.::I:ili::,':,~i,,'(mWi¡,i.li'IIKI':ift~~..,ii. 1 4950.17 0.54 0.36 44 4958.62 0.25 0.15 2 4950.30 5.96 4.82 45 4958.75 1.44 1.06 3 4950.48 0.18 0.10 46 4959.06 0.09 0.04 4 4950.59 0.61 0.42 47 4959.20 1.74 1.31 5 4950.78 2.90 2.26 48 4959.57 0.02 0.01 6 4950.91 3.63 2.86 49 4960.05 0.06 0.02 7 4951.29 1.53 1.14 50 4960.24 0.35 0.22 8 4951.63 0.07 0.03 51 4960.52 0.46 0.30 9 4951.77 0.23 0.14 52 4960.68 0.05 0.02 10 4951.95 1.21 0.89 53 4960.93 0.17 0.09 11 4952.11 3.13 2.45 54 4961.06 0.11 0.06 12 4952.26 1.10 0.80 55 4961.60 0.17 0.10 13 4952.38 0.50 0.33 56 4961.73 0.19 0.11 14 4952.50 0.04 0.02 57 4962.06 0.09 0.04 15 4952.64 0.11 0.06 58 4962.17 2.49 1.92 16 4952.73 4.30 3.41 59 4962.26 0.45 0.30 17 4953.33 2.26 1.73 60 4962.50 2.64 2.04 18 4953.53 0.32 0.20 61 4962.64 1.77 1.33 19 4953.82 0.11 0.05 62 4962.91 1.11 0.80 20 4953.91 0.74 0.52 63 4963.07 0.79 0.55 21 4954.06 0.40 0.26 64 4963.16 2.56 1.98 22 4954.30 0.13 0.07 65 4963.41 0.61 0.42 23 4954.38 0.16 0.09 66 4963.65 2.90 2.27 24 4954.47 0.49 0.32 67 4963.77 1.77 1.33 25 4954.62 0.19 0.11 68 4963.90 0.15 0.08 26 4955.16 9.59 7.97 69 4964.05 0.36 0.23 27 4955.34 0.65 0.44 70 4964.23 1.05 0.76 28 4955.40 1.03 0.74 71 4964.61 0.01 0.003 29 4955.55 0.79 0.55 72 4964.86 0.01 0.002 30 4955.65 0.14 0.07 73 4965.13 0.02 0.004 31 4956.22 0.06 0.03 74 4965.62 0.49 0.32 32 4956.45 0.10 0.05 75 4965.89 0.35 0.22 33 4956.56 2.24 1.71 76 4966.00 0.10 0.05 34 4956.68 0.04 0.01 77 4966.11 3.74 2.95 35 4956.76 4.14 3.28 78 4966.28 0.53 0.35 36 4957.09 7.75 6.35 79 4966.45 0.26 0.15 37 4957.29 0.07 0.03 80 4966.67 0.78 0.55 38 4957.63 0.07 0.03 81 4966.79 1.11 0.80 39 4957.71 0.31 0.19 82 4967.05 0.78 0.55 40 4957.79 0.23 0.14 83 4967.19 0.18 0.10 41 4957.93 0.95 0.68 84 4967.28 0.54 0.36 42 4958.02 4.90 3.91 85 4967.61 1.10 0.79 43 4958.24 0.55 0.37 86 4967.83 0.26 0.15 Page 1 ) I '( I'"'" ~ LAB J J ~. J Profile Permeability Data ARca Alaska, Inc. Well: Kalubik #2 Core # 1 4950.00 - 5027.25 ft. :;'!i:'[:I!:@lfij~::!i:,i!!¡il!':,:::!'.,iIIP~~,:,¡;!i:!,IJ:t~~,.:~m~:l!:!iili::i:i:~""lm~~;,:'i, ii¡:i'!,!i!,~Qiôt:!:::!:¡ I ",""" I I " , :';"':""""~""""""1Jj::""''''' """1<(' "":"'("'''''''''\1l''': """"':'Kl':' tm\1J""'" ,¡ii,,:::: ,Ill';'::: :':Jt,: OJ,' ,j, ):'ii'V ',,', ,',':!: 87 4968.07 0.11 0.05 130 4976.83 0.40 0.25 88 4968.35 0.05 0.02 131 4977.06 0.29 0.18 89 4968.76 1.28 0.94 132 4977.26 0.87 0.61 90 4968.83 38.6 34.7 133 4977.40 0.32 0.20 91 4969.08 0.16 0.09 134 4977.56 0.16 0.09 92 4969.23 1.21 0.88 135 4977.68 0.42 0.27 93 4969.39 0.16 0.09 136 4977.88 0.21 0.12 94 4969.56 0.10 0.05 137 4978.37 1.82 1.38 95 4969.70 0.84 0.59 138 4978.45 2.34 1.79 96 4969.93 0.45 0.29 139 4978.62 1.82 1.38 97 4970.05 0.52 0.34 140 4978.87 0.27 0.16 98 4970.29 0.36 0.22 141 4979.04 0.09 0.04 99 4970.44 0.79 0.55 142 4979.22 0.09 0.04 100 4970.59 0.33 0.20 143 4979.36 0.29 0.17 101 4970.84 0.17 0.10 144 4979.49 3.35 2.64 102 4970.88 3.06 2.39 145 4979.74 6.12 4.96 103 4971.14 93.8 86.7 146 4979.93 3.52 2.76 104 4971.18 36.6 32.7 147 4980.09 1.08 0.78 105 4971.32 104 96.2 148 4980.35 0.58 0.39 106 4971.45 70.5 64.5 149 4980.47 0.62 0.42 107 4971.57 1.53 1.14 150 4980.80 0.10 0.05 108 4971.83 0.14 0.07 151 4980.97 0.80 0.56 109 4971.90 0.96 0.69 152 4981.35 0.09 0.05 110 4972.07 0.07 0.03 153 4981 .44 0.26 0.16 111 4972.37 0.53 0.35 154 4981.62 0.11 0.06 112 4972.56 0.11 0.05 155 4981.98 0.28 0.17 113 4972.72 0.31 0.19 156 4982.09 0.04 0.01 114 4972.93 0.54 0.36 157 4982.26 0.17 0.09 115 4973.04 0.23 0.13 158 4982.45 0.14 0.08 116 4973.33 0.18 0.10 159 4982.82 0.08 0.04 117 4973.60 0.14 0.08 160 4983.12 0.64 0.44 118 4973.92 0.12 0.06 161 4983.29 0.44 0.28 119 4974.06 0.56 0.37 162 4983.57 0.46 0.30 120 4974.24 0.25 0.15 163 4983.78 0.08 0.03 121 4974.57 0.75 0.52 164 4984.01 0.89 0.63 122 4974.74 20.8 18.1 165 4984.41 0.19 0.10 123 4974.91 0.12 0.06 166 4984.59 0.08 0.04 124 4975.09 0.37 0.24 167 4984.73 0.86 0.60 125 4975.30 0.15 0.08 168 4984.92 0.13 0.07 126 4975.55 0.71 0.49 169 4985.14 0.65 0.45 127 4975.86 0.06 0.03 170 4985.38 0.49 0.32 ¡..... R \ ." ,- 128 4976.10 0.11 0.06 171 4985.60 0.51 0.34 0" ~- 129 4976.44 0.18 0.10 172 4985.91 0.43 0.28 ',("\'" , 'i Page 2 ,l~'ons~ «~e:G'~;::'Ü;:~~c~," ,'nCfQge ) ') i 1'1 ";~I' ~LAB ; J II ... ~~ J Profile Permeability Data ARca Alaska, Inc. Well: Kalubik #2 Core # 1 4950.00 - 5027.25 ft. 173 4986.10 0.16 0.09 216 4994.075 0.09 0.04 174 4986.29 1.12 0.81 217 4994.231 0.13 0.07 175 4986.54 0.13 0.07 218 4994.455 0.07 0.03 176 4986.81 0.08 0.04 219 4994.775 0.07 0.03 177 4987.04 0.30 0.18 220 4995.142 0.16 0.08 178 4987.34 0.81 0.56 221 4995.328 0.09 0.04 179 4987.56 0.05 0.02 222 4995.575 0.17 0.10 180 4987.75 0.63 0.43 223 4995.891 0.53 0.35 181 4987.91 0.45 0.29 224 4996.00 0.66 0.46 182 4988.24 0.18 0.10 225 4996.245 0.66 0.45 183 4988.34 1.02 0.73 226 4996.416 0.56 0.38 184 4988.42 0.10 0.05 227 4996.66 0.12 0.06 185 4988.56 0.99 0.70 228 4996.909 0.07 0.03 186 4988.66 0.85 0.60 229 4997.285 0.14 0.07 187 4988.87 1.30 0.96 230 4997.375 0.72 0.50 188 4989.04 0.59 0.40 231 4997.595 0.04 0.02 189 4989.27 0.18 0.10 232 4997.767 0.46 0.30 190 4989.45 0.44 0.29 233 4997.946 0.27 0.16 191 4989.61 0.08 0.04 234 4998.086 0.10 0.05 192 4989.69 0.07 0.03 235 4998.211 0.57 0.38 193 4989.79 0.14 0.07 236 4998.471 0.02 0.01 194 4989.88 0.13 0.07 237 4998.579 0.33 0.20 195 4990.15 1.30 0.95 238 4998.841 0.26 0.16 196 4990.25 0.11 0.06 239 4999.028 0.47 0.31 197 4990.41 0.52 0.34 240 4999.187 0.40 0.26 198 4990.55 0.10 0.05 241 4999.569 0.02 0.01 199 4990.71 0.19 0.11 242 4999.732 0.001 0.0001 200 4990.97 0.44 0.29 243 4999.884 0.37 0.23 201 4991.10 0.09 0.04 244 5000.115 0.65 0.44 202 4991.24 0.06 0.03 245 5000.264 0.19 0.11 203 4991.42 0.14 0.07 246 5000.40 0.19 0.11 204 4991.63 1.42 1.05 247 5000.53 0.23 0.13 205 4992.11 0.35 0.22 248 5000.75 0.29 0.17 206 4992.36 0.23 0.14 249 5001 . 117 0.06 0.03 207 4992.48 0.11 0.06 250 5001.30 0.46 0.30 208 4992.61 0.28 0.17 251 5001.459 0.33 0.21 209 4992.76 0.56 0.38 252 5001.54 0.34 0.21 210 4993.19 0.48 0.31 253 5001.728 0.59 0.40 211 4993.31 0.09 0.04 254 5001.894 0.19 0.11 212 4993.46 0.14 0.07 255 5001.993 0.04 0.02 213 4993.59 0.36 0.23 256 5002.14 0.53 0.35 214 4993.72 0.08 0.04 257 5002.379 0.40 0.26 215 4993.88 0.06 0.03 258 5002.475 0.13 0.07 Page 3 ) '} ,''', · ~~ · ':t : I,¡! ,I. L, fLAB Profile Permeability Data ARca Alaska, Inc. Well: Kalubik #2 Core # 1 4950.00 - 5027.25 ft. :i"':<!!:::'irqiQ~ii:.;:¡~'i:I:·I;i!:':~¡pW[,!!:::1iJiKí!i:jmij);irli'!i:~'::(m~I¡'¡!:!" 259 5002.66 0.20 0.11 302 5011.60 0.06 0.03 260 5002.85 0.15 0.08 303 5011.73 0.08 0.04 261 5003.00 0.09 0.04 304 5012.00 0.07 0.03 262 5003.05 0.16 0.08 305 5012.20 0.02 0.01 263 5003.23 0.25 0.15 306 5012.57 0.04 0.02 264 5003.41 0.23 0.13 307 5012.83 0.17 0.09 265 5003.57 0.10 0.05 308 5012.93 0.15 0.08 266 5003.73 0.02 0.005 309 5013.27 0.80 0.56 267 5004.10 0.10 0.05 310 5013.32 0.66 0.45 268 5004.40 0.88 0.62 311 5013.48 0.06 0.02 269 5004.64 0.32 0.20 312 5013.67 0.21 0.12 270 5004.78 0.23 0.13 313 5013.98 0.38 0.24 271 5004.88 0.06 0.02 314 5014.20 0.32 0.20 272 5005.24 0.24 0.14 315 5014.32 0.74 0.51 273 5005.29 0.19 0.11 316 5014.39 0.14 0.08 274 5005.50 0.24 0.14 317 5014.60 0.53 0.35 275 5005.72 0.51 0.34 318 5014.71 0.05 0.02 276 5005.94 0.17 0.09 319 5014.86 0.10 0.05 277 5006.05 0.25 0.15 320 5015.00 0.03 0.01 278 5006.30 0.18 0.10 321 5015.19 0.07 0.03 279 5006.44 0.21 0.12 322 5015.28 0.04 0.02 280 5006.67 0.49 0.32 323 5015.50 0.11 0.05 281 5007.27 0.66 0.45 324 5015.62 0.07 0.03 282 5007.56 0.22 0.13 325 5016.07 0.06 0.02 283 5007.66 0.60 0.41 326 5016.30 0.04 0.02 284 5007.78 0.85 0.60 327 5016.60 0.13 0.07 285 5007.92 0.23 0.13 328 5016.76 0.94 0.67 286 5008.03 0.47 0.31 329 5016.97 0.24 0.14 287 5008.29 0.25 0.15 330 5017.10 0.19 0.11 288 5008.44 0.34 0.21 331 5017.18 0.09 0.05 289 5008.58 0.16 0.09 332 5017.24 0.37 0.23 290 5008.88 0.46 0.30 333 5017.38 1.00 0.72 291 5009.07 0.01 0.003 334 5017.67 0.07 0.03 292 5009.32 0.04 0.02 335 5018.03 0.02 0.01 293 5009.46 0.01 0.004 336 5018.25 0.06 0.03 294 5009.73 0.02 0.005 337 5018.49 0.07 0.03 295 5009.81 0.10 0.05 338 5018.70 0.14 0.07 296 5010.16 0.02 0.01 339 5019.12 0.05 0.02 297 5010.70 0.06 0.03 340 5019.43 0.44 0.29 298 5010.87 0.12 0.06 341 5019.52 0.12 0.06 299 5011.04 0.02 0.01 342 5019.70 0.37 0.23 .""" :_.~ E ~ \,/ 1~ 300 5011.15 0.32 0.20 343 5019.86 0.26 0.15 301 5011.38 0.17 0.10 344 5020.00 0.11 0.06 Page 4 1 S :~,; .~~ \ f:.~ :'~,:,::, '3 c::; CDns. CG1:missic p.,"::+¡i')r:1n~1 ') r(~;~'?LAB j ~ . ~ ~j :J Profile P ARca Alaska, Inc. Well: Kalubik #2 Core # 1 4950.00 - 5027.25 ft. ..,...,' ,...., ·,··,',·,··,"'·"'1"·'·"···· '.".,."""".' ,·,·······'·'1'·"· .' ....,........ ·,·,··,·,····,······'···'·1·'······ ,. ,., ..,.,.."." ,..", . ',,·,"'·'··D~¡·r;¡..+·····~·,·,··,'· . """"".F\"" ,,······+b··'·· .,..... ..,.,...,.... """"'('m" . 'AI""'" ""'" '·lll"·I> .. ';;.1,\..", :);::ir;':!~¡!:;¡i!¡< ¡!':'?"\~i~\'I~!·';'!i'¡1~'+'~'I:.:.. '..., '~..;i:i "\:'ri.'¡+m~i)) 345 5020.17 0.13 0.07 346 5020.51 1.13 0.82 347 5020.63 0.06 0.02 348 5020.79 0.87 0.61 349 5020.89 0.46 0.30 350 5021.25 0.22 0.12 351 5021.53 0.23 0.13 352 5021.76 0.12 0.06 353 5021.90 0.13 0.07 354 5022.16 0.18 0.10 355 5022.35 0.13 0.07 356 5022.52 0.08 0.04 357 5022.83 2.56 1.98 358 5022.90 0.08 0.04 359 5023.02 0.05 0.02 360 5023.32 0.99 0.70 361 5023.57 0.55 0.37 362 5023.72 0.04 0.01 363 5024.09 0.11 0.05 364 5025.09 0.28 0.17 365 5025.56 0.03 0.01 366 5025.69 0.07 0.03 367 5026.07 0.07 0.03 368 5026.48 0.13 0.07 369 5026.56 0.55 0.37 370 5026.94 0.06 0.03 371 5027.20 5.78 4.67 ") Page 5 ARCO Alaska, Inc. ') ') Core Chip Description .;III. ~y Operator and Well Name: Section of ARCO Alaska, Inc. Kalubik 2 1 13 Location: Date 70.484882 deg N, 150.306061 deg W March 17, 1998 Core #2: 5032-5122' MD Recovered: 66.25 of 90 ft Depth Rec. Description Oil Oil Fluor Cut Cut Show ft in. Stain O:tr % Intensity Color color fluor Summary 5035 Sh: It gry, sl slty, firm, w lam, subfiss. none none tr dull green none slow wk Trace pale grn 5038 Ss: med brn, vfL-vfU, s&p, sl micac, 100% v 100 bright gold dk amber inst strong Excellen sl carb, ang-sbang, w srt, mod indur, med-dk strong mlky yel t f por, fnt lam. brn org 5041 Ss: med brn, vfL-vfU, s&p, sl micac, 100% v 100 mod gold brown inst strong Excellen sl carb, ang-sbang, w srt, mod indur, med-dk strong mlky yel t f por, fnt lam. brn org 5044 Ss: med brn, vfL-vfU, s&p, sl micac, 100% strong 100 mod gold dk amber inst strong Excellen sl carb, ang-sbang, w srt, friable, f med-dk mlky yel t por, fnt lam. brn org 5047 Sh: It gry, sl slty, firm, w lam, subfiss. none none 5 v dull yellow none mod slow Poor wk-mod pale grn 5050 Sh: med-dk gry, v sl slty, soft, w lam, none none 5 v dull yellow none mod slow Poor subfiss. wk-mod pale grn 5053 Sh: med-dk gry, soft, w lam, subfiss. none none 5 v dull yellow p straw fast mod Poor mlky yel wht 5056 Sh: med-dk gry, soft, scat carb none none 10 v dull yellow none mod slow Poor flakes, w lam, subfiss. wk-mod pale grn 5059 Ss-Slts: brn, crs slt-vfL, qtzose, minor 100% v 100 mod gold amber inst strong Excellen lithics, sbang, mod w srt, mod indur, med-dk strong mlky yel t p-f por. brn org 5062 Ss-Slts: brn, crs slt-vfL, qtzose, minor 100% v 100 mod gold amber inst strong Excellen lithics, sbang, mod w srt, mod indur, med-dk strong bright mlky yel t p-f por. brn org Remarks Described by P. L. Decker, J. D. Corrigan AF<3B-2389-B ) ') ARCO Alaska, Inc. ..¡jll,. Core Chip Description ~,. Operator and Well Name: Section of ARCO Alaska, Inc. Kalubik 2 2 13 Location: Date 70.484882 deg N, 150.306061 deg W March 17, 1998 Core #2: 5032-5122' MD Recovered: 66.25 of 90 ft Depth Rec. Description Oil Oil Fluor Cut Cut Show ft. in, Stain O:b' % Intensity Color color fluor Summary 5064.8 Sh: med gry, sit interlam, mod firm, Sh: weak 15 v dull yellow none slow wk Trace- subfiss. none; SIt: pale grn Poor It brn 5066.5 Slts-Ss: It gry-brn, crs slt-vfL, qtzose, 100% strong 100 dull gold amber inst strong Excellen minor lithics, micac, 51 carb, sbang- med brn milky yel- t subrnd, mod w srt, mod indur, p-f org por, interlam. 5069 Sh: med gry, w lam, mod firm, none none 30 dull gold none mod slow Poor su bfiss. mod It bluish grn 5072 Ss-Slts: brn, crs slt-vfL, qtzose, minor 100% v 100 pale yellow straw fast mlky Good lithics, sbang, mod w srt, mod indur, med-dk strong gold yel wht p-f por. brn 5075 Ss: brn, vfL, qtzose, minor lithics, 100% v v 100 mod gold dk brown v fast mlky Good- micac, sbang-subrnd, w srt, mod dk brn strong orange org-brn Excellen indur, p-f por, non lam. t 5078 Sh: dk gry, w lam, soft, fiss. none none 75 pale yellow p straw fast mod Fair mlky bluish grn 5081 Sits: gry brn, qtzose, micac, scat carb patchy mod 100 pale yellow straw v fast mod Good debris, w indur, w lam. med brn strong gold strong mlky bluish grn 5084 Sits: med gry brn, argillaceous, sl patchy weak- 90 pale gold It amber v fast Good- qtzose, mod indur, faint lam It-med mod strong mlky Excellen brn yel wht-org t 5087 Slts-Ss: med gry-brn, crs slt-vfL, Even strong 95 pale brown It amber v fast Excellen qtzose, minor lithics, v micac, scat med brn gold strong mlky t carb debris, sbang-subrnd, mod w yel wht-org srt, mod indur, p-f por, interlam wI vfL ss. 5090 Ss-Slts: med gry brn, vfL-vfU, s&p, 51 100% strong 95 pale light It amber fast strong Excellen micac, 51 carb, ang-sbang, w srt, mod med-dk amber mlky yel t indur, f por, v thinly intbdd ss-slts. brn wht-org Kemarks Described by P. L. Decker, J. D. Corrigan Ak,3ß-2389-B ARca Alaska, Inc. <> ) Operator and Well Name: ARCO Alaska, Inc. Kalubik 2 Location: 70.484882 deg N, 150.306061 deg W Core #2: 5032-5122' MD Depth ft 5093 Rec, in. Description Sh: med gry, interlam wI ripple xlam sit, mod soft, subfiss. 5096 Sh: It-med gry, firm-hard, subfiss. 5097.25 5s: brn, vfL, qtzose, minor lithics, micac, sbang-subrnd, w srt, w-vw indur, p-f par, nonlam. Kemarks Ak3B-2389-B ") Core Chip Description Section of 3 13 Date March 17, 1998 Recovered: 66.25 of 90 ft Oil Oil Fluor Cut Cut Show Stain a±r % Intensity Color color fluor Summary none none 30 v dull yellow none fast mod Poor bluish grn none none 55 dull goldbro p straw v fast mod Poor- wn strong mlky Fair yel wht even v 100 pale- yellow amber v fast Excellent med strong mod gold strong mlky brn yel org Described by P. L. Decker, J. D. Corrigan ) ) 1. '~~)~'1 I~·, J!L,fLAB Profile Permeability Data ARca Alaska, Inc. Well: Kalubik #2 Core # 2 5032.00 - 5097.25 ft. :':i::::.':rtiQ~IW:i;i::i. ¡'··(:Iî?ltJ¡'i;n::li:r::~~ï::J:ml'::I:II:,;I:~':(;'tœl):',I;'" f.gjnt I DQptf1 I K, (rod·) I·· KI (md) 1 5032.23 0.09 0.04 44 5040.60 32.4 28.8 2 5032.39 0.18 0.10 45 5040.80 49.0 44.3 3 5032.55 0.22 0.12 46 5041.06 36.7 32.8 4 5032.76 0.80 0.56 47 5041.20 54.7 49.7 5 5032.95 0.01 0.00 48 5041.40 30.7 27.3 6 5033.10 0.53 0.35 49 5041.60 40.9 36.7 7 5033.30 0.12 0.06 50 5041.80 59.7 54.5 8 5033.59 0.02 0.01 51 5042.00 39.8 35.9 9 5033.82 0.76 0.53 52 5042.20 68.2 62.4 10 5034.14 0.24 0.14 53 5042.40 39.5 35.4 11 5034.31 0.55 0.37 54 5042.60 29.4 26.0 12 5034.50 0.38 0.24 55 5042.80 38.0 34.1 13 5034.65 0.56 0.37 56 5043.00 35.2 31.4 14 5034.74 0.06 0.02 57 5043.20 39.9 35.8 15 5034.89 0.52 0.34 58 5043.40 84.6 78.0 16 5035.22 0.30 0.18 59 5043.60 19.6 17.0 17 5035.42 0.15 0.08 60 5043.80 32.8 29.2 18 5035.55 0.02 0.01 61 5044.05 25.5 22.4 19 5035.63 0.25 0.15 62 5044.20 14.5 12.3 20 5035.89 0.98 0.70 63 5044.41 52.6 47.7 21 5036.00 0.05 0.02 64 5044.52 17.1 14.8 22 5036.14 0.06 0.03 65 5044.70 8.45 6.97 23 5036.28 0.01 0.003 66 5044.84 0.08 0.04 24 5036.60 17.3 14.9 67 5044.95 2.19 1.69 25 5036.80 10.4 8.75 68 5045.17 0.39 0.25 26 5037.00 10.0 8.38 69 5045.30 3.78 2.99 27 5037.20 7.29 5.94 70 5045.59 0.13 0.07 28 5037.40 6.97 5.66 71 5045.81 13.4 11.4 29 5037.60 4.36 3.43 72 5046.42 0.002 0.0003 30 5037.80 4.53 3.58 73 5046.60 0.11 0.05 31 5038.05 4.12 3.24 74 5046.84 0.52 0.34 32 5038.20 3.20 2.47 75 5047.34 0.06 0.03 33 5038.40 3.98 3.12 76 5047.65 0.49 0.32 34 5038.60 3.75 2.92 77 5047.72 0.28 0.17 35 5038.80 6.55 5.29 78 5047.80 0.11 0.05 36 5039.00 14.0 11.9 79 5048.69 0.05 0.02 37 5039.20 8.56 7.04 80 5048.81 0.06 0.03 38 5039.40 22.5 19.7 81 5049.77 0.10 0.05 39 5039.60 42.4 38.2 82 5050.39 0.04 0.02 40 5039.80 19.1 16.6 83 5050.44 0.83 0.58 41 5040.00 35.8 32.0 84 5050.67 0.07 0.03 42 5040.20 36.8 32.9 85 5050.79 0.66 0.45 43 5040.40 47.4 42.9 86 5051.42 0.27 0.16 Page 1 ) " ) ('r'ì'~LAB Profile Permeability Data 'J J .. ¡. J ARCa Alaska, Inc. Well: Kalubik #2 Core # 2 5032.00 - 5097.25 ft. fWDl 1 Depth. 1 KI (mdll KI (mtO 87 5051.68 0.11 0.06 130 5062.35 0.23 0.13 88 5052.00 0.10 0.05 131 5062.53 0.19 0.11 89 5052.11 0.86 0.60 132 5062.75 0.07 0.03 90 5052.51 0.97 0.69 133 5062.91 0.14 0.07 91 5052.71 0.77 0.54 134 5063.11 0.10 0.05 92 5052.90 1.06 0.76 135 5063.27 0.21 0.12 93 5053.29 0.14 0.08 136 5063.43 0.11 0.06 94 5053.49 0.37 0.23 137 5063.63 0.18 0.10 95 5053.86 0.09 0.04 138 5063.82 0.08 0.04 96 5054.30 0.07 0.03 139 5064.30 0.06 0.03 97 5054.67 0.04 0.01 140 5064.51 0.17 0.10 98 5054.83 0.59 0.40 141 5064.64 0.17 0.09 99 5055.12 0.23 0.13 142 5065.37 0.07 0.03 100 5055.32 0.35 0.22 143 5065.82 0.07 0.03 101 5055.59 0.09 0.04 144 5066.07 0.14 0.07 102 5056.23 0.33 0.20 145 5066.49 0.13 0.07 103 5056.43 0.28 0.17 146 5066.61 0.06 0.03 104 5056.57 0.21 0.12 147 5066.78 0.24 0.14 105 5056.92 0.02 0.01 148 5067.22 0.19 0.11 106 5057.11 0.19 0.11 149 5067.28 0.44 0.28 107 5057.43 0.24 0.14 150 5067.51 0.15 0.08 108 5057.79 0.02 0.01 151 5067.78 0.21 0.12 109 5058.06 0.19 0.11 152 5067.92 0.26 0.15 110 5058.35 0.37 0.23 153 5068.72 0.12 0.06 111 5058.44 0.63 0.43 154 5068.86 0.24 0.14 112 5058.61 0.72 0.49 155 5069.39 0.20 0.11 113 5058.81 0.51 0.34 156 5069.55 0.09 0.04 114 5059.11 1.30 0.95 157 5069.69 0.14 0.08 115 5059.35 0.13 0.07 158 5069.91 0.07 0.03 116 5059.81 0.62 0.42 159 5070.80 0.29 0.17 117 5059.92 0.49 0.32 160 5070.92 0.84 0.59 118 5060.08 0.38 0.24 161 5071.35 0.39 0.25 119 5060.34 0.22 0.12 162 5071.52 0.40 0.26 120 5060.57 0.06 0.03 163 5072.10 0.64 0.43 121 5060.70 0.29 0.17 164 5072.35 0.63 0.43 122 5060.83 0.52 0.35 165 5072.72 0.36 0.22 123 5060.97 0.69 0.47 166 5072.79 0.14 0.07 124 5061.26 0.63 0.43 167 5072.90 0.35 0.22 125 5061.33 0.23 0.13 168 5073.87 0.48 0.32 126 5061.52 0.55 0.37 169 5074.05 0.75 0.52 127 5061.73 0.32 0.20 170 5074.17 0.16 0.08 128 5061.94 0.22 0.13 171 5074.46 0.63 0.43 129 5062.05 0.22 0.13 172 5075.10 0.32 0.20 Page 2 , ) 'Y',l'~LAB . J ~ . ~ L. J Profile Permeability Data ARca Alaska, Inc. Well: Kalubik #2 Core # 2 5032.00 - 5097.25 ft. :¡>!:!:!:!i~ltijQ:~·~i:!: 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 191 192 193 194 195 196 197 198 199 200 201 202 203 204 205 206 207 208 209 210 211 212 213 214 215 :I¡i::!!::¡!~~~~~.. ·1;i:!!~·~::'ij9~J!:!;!I!:!,.!¡[I1~:;'¡Ø11:~t::::!: 5075.35 0.55 0.37 5075.44 0.29 0.17 5076.11 0.74 0.51 5077.26 0.83 0.58 5077.52 0.59 0.40 5078.19 0.61 0.41 5079.11 1.02 0.73 5079.34 0.81 0.57 5079.48 0.12 0.06 5079.54 0.44 0.28 5080.08 0.15 0.08 5080.77 0.55 0.37 5080.85 0.24 0.14 5080.99 0.35 0.22 5081.41 0.76 0.53 5082.14 0.40 0.25 5082.32 0.52 0.35 5082.50 0.05 0.02 5082.94 0.34 0.21 5083.32 0.06 0.03 5083.60 0.90 0.63 5084.05 0.28 0.17 5084.32 0.11 0.05 5084.67 0.08 0.04 5084.75 0.42 0.27 5085.22 0.51 0.34 5085.46 0.22 0.13 5085.80 0.38 0.24 5086.54 0.80 0.56 5087.29 0.71 0.49 5087.51 0.20 0.12 5087.83 0.34 0.21 5088.39 0.15 0.08 5088.70 0.06 0.03 5089.30 1.08 0.78 5090.40 0.83 0.58 5090.73 0.16 0.08 5090.83 0.13 0.07 5091.12 0.82 0.57 5091.64 1.02 0.73 5091.74 0.27 0.16 5092.10 0.42 0.27 5092.40 0.30 0.18 Page 3 ') 216 217 218 219 220 221 222 223 224 225 226 227 . 1!;:i:'!il!'îl~n:!::¡:i!I!!i·æ'!(:nñUI:!;!I!:::i:·:IS,t:':~(m~it:!:!! 5092.78 0.13 0.07 5093.09 0.09 0.04 5094.11 0.08 0.04 5094.56 0.88 0.62 5095.42 1.72 1.30 5095.92 0.84 0.59 5096.18 0.38 0.24 5096.32 0.35 0.22 5096.48 0.12 0.06 5096.73 0.70 0.48 5097.00 0.70 0.48 5097.21 0.44 0.29 ( ( , "DlLAB Jrfù PETROLEUM SERVICES September 16, 1998 ARCO Alaska, Inc. 700 G Street PO BOX 100360 Anchorage, Alaska 99510-0360 Attention: Ms. Renee Hannon Re: Final Report of CMS-300 and Dean Stark Analyses Arco Alaska, Inc. Kalubik No.2 & 3 Wells Alaska C.L. File No.: 57161-12404 Dear Ms. Hannon; Presented in the following report are final results of CMS-300 and Dean Stark analyses on plugs extracted from conventional cores from the above referenced wells. This work was performed in conjuction with other services provided by Core Lab's Anchorage facility and Arco's lab in Piano, Texas. Seven copies of this report have been generated. Thank you for providing Core Laboratories the opportunity to be of service by performing this study on behalf of Arco Alaska, Inc. Should there be any questions about the contents of this report, or if I may be of further assistance, please do not hesitate to contact me at (504) 581- 5222 or at the address below. Sincerely, /7(:2· ., r-y ,,'-- ~ ~/I'- .'__ Wesley Cantwell Laboratory Supervisor Reservoir Geologist Core Laboratories, Inc. 929 Howard Avenue, New Orleans, Louisiana 70113, (504) 581-5222, Fax (504) 586-9476 ~ , { Table of Contents Project Overview......................................................................................................... 1 Appendix A - CMS-300 Analysis - Tabular Results ................................................... A 1 Appendix 8 - Deans Stark Analysis - Tabular Results ............................................... 81 Appendix C - Project Protocol.................................................................................... C1 Data Diskette .................................................................................... Labled back folder A1 CMS-300 Tabular Data ApPENDIX A (( \ (e ~ ~R}AB CORE LABORATORIES Company: Arco Alaska Core Lab File No.: 57161-12404 Well: Kalubik NO.2 Date: 24-Aug-98 Location: Alaska Analyst(s): WC, JP, WJ, BP CMS-300 Report 1.0 Inch Plugs Sample Depth Confining Pore Porosity Permeability Slip Forsheimer Grain Notes Number Stress Volume Klinkenberg Air Factor Effect Density (feet) (psi) (cc) (%) Koo Ka (b) (13) g/cm3 Horizontal Plugs -- 1 4950.10 800 3.99 21.7 5.86 7.12 12.29 6.42E+08 2.70 2 4951.80 800 3.43 16.6 4.45 4.98 6.93 3.85E+10 2.27 2 3 4954.10 800 3.65 19.8 4.53 5.34 10.41 7.74E+09 2.71 2 4 4955.70 800 3.31 17.9 0.70 0.94 22.64 5.57E+11 2.70 2 5 4956.70 800 3.79 20.3 3.10 3.91 15.37 5.86E+09 2.65 6 4959.15 Ambient 3.94 21.1 Fractured Sample 2.68 6 7 4960.00 Ambient 3.62 19.6 Fractured Sample 2.73 6 8 4962.25 800 3.76 20.1 2.47 3.14 16.49 6.90E+09 2.71 9 4964.85 800 0.96 5.0 10.87 10.96 0.48 7.71 E+09 2.83 2 10 4965.10 800 0.96 5.0 0.82 0.85 1.65 1.28E+11 2.83 2 11 4966.20 800 3.77 20.3 3.66 4.49 13.42 3.58E+09 2.68 2 12 4966.45 800 3.29 17.4 0.41 0.60 31.08 9.91 E+09 2.69 3 13 4968.75 800 3.85 20.5 6.79 7.83 8.66 1.87E+09 2.69 3 14 4969.50 800 3.53 19.0 0.29 0.42 32.78 1.13E+11 2.82 15 4970.90 800 4.04 21.4 2.29 2.95 17.43 8.49E+09 2.83 16 4971.10 800 4.67 25.7 87.78 93.63 3.30 2.22E+07 2.66 17 4972.30 Ambient 3.42 18.7 Fractured Sample 2.67 6 18 4973.80 Ambient 3.58 19.0 Fractured Sample 2.60 6 19 4974.70 800 4.46 23.9 33.33 37.09 5.87 6.54E+07 2.66 20 4975.30 Ambient 3.53 18.8 Fractured Sample 2.68 6 21 4976.95 800 3.96 21.4 5.89 7.17 12.41 6.42E+08 2.67 2 22 4977.35 800 3.49 18.9 0.26 0.43 43.23 3.54E+11 2.74 23 4977.85 800 3.41 18.7 0.58 0.79 23.69 1.26E+12 2.70 24 4979.15 800 1.72 9.3 0.03 0.05 52.75 5.49E+14 2.70 Core Laboratories, Inc. Page 1 of 5 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the besl judgment of Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profrtableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is use<! or relied upon for any reason whatsoever. This report shall not be reproduced except in ifs entirety, without the written approval of Core Laboratories. Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profrtableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. YlJìAB CORE LABORATORIES V.. Company: Arco Alaska Core Lab File No.: 57161-12404 Well: Kalubik NO.2 Date: 24-Aug-98 Location: Alaska Analyst(s): WC, JP, WJ, BP CMS-300 Report 1.0 Inch Plugs Sample Depth Confining Pore Porosity Permeability Slip Forsheimer Grain Notes Number Stress Volume Klinkenberg Air Factor Effect Density (feet) (psi) (cc) (%) Koo Ka (b) (ß) g/cm3 25 4980.40 Ambient 3.31 18.2 Fractured Sample 2.72 6 ~. 26 4981.40 Ambient 3.22 17.4 Fractured Sample 2.76 6 27 4982.20 800 2.94 15.9 0.09 0.16 57.84 1.09E+12 2.98 28 4984.95 800 3.20 17.5 0.66 0.78 11.05 1.98E+12 2.71 29 4986.95 800 3.57 19.3 7.17 8.05 6.78 1.24E+09 2.72 30 4988.60 800 2.93 16.1 0.18 0.28 39.14 1.33E+12 2.68 1 31 4989.40 800 3.33 18.4 0.43 0.62 28.37 1.11E+11 2.71 1 32 4990.90 800 3.31 17.8 0.18 0.30 44.68 2.74E+11 2.89 33 4992.05 800 3.14 17.0 0.70 0.82 10.42 3.88E+11 2.69 34 4993.70 800 3.30 17.9 1.40 1.71 13.51 8.82E+10 2.71 35 4994.60 800 3.06 16.6 1.64 1.76 4.40 2.20E+11 2.70 4 36 4995.10 800 3.04 16.5 0.43 0.53 15.24 1.11 E+11 2.67 1 37 4996.25 800 2.88 15.7 0.27 0.37 25.40 5.21E+10 2.69 3 38 4997.80 800 3.20 17.7 3.93 4.23 4.33 9.23E+10 2.71 4 39 4998.05 800 2.15 16.9 0.87 0.95 5.30 4.89E+11 2.70 2 40 4999.30 800 3.11 16.5 0.77 1.02 20.49 1.24E+11 2.70 3 ~, 41 5000.95 800 3.57 19.2 0.62 0.91 29.65 1.85E+11 2.77 42 5001.30 800 3.26 17.9 0.20 0.34 46.59 5.50E+11 2.68 1 43 5002.90 800 3.50 18.3 0.18 0.31 51.57 7.59E+11 2.69 44 5004.90 800 3.27 17.3 0.10 0.19 63.14 1.62E+12 2.96 45 5006.30 800 3.09 16.7 1.48 1.84 14.34 3.29E+11 2.72 1 46 5008.10 800 3.08 16.4 0.22 0.30 25.50 4.18E+11 2.72 47 5008.40 Ambient 2.34 13.6 Fractured Sample 2.80 6 48 5010.90 800 2.61 16.4 3.61 3.89 4.44 4.26E+10 2.69 4 49 5011.35 800 3.40 18.0 2.12 2.45 9.31 4.94E+10 2.70 Core Laboratories, Inc. Page 2 of 5 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Core YRJÌAB CORE LABORATORIES \/. Company: Arco Alaska Core Lab File No.: 57161-12404 Well: Kalubik NO.2 Date: 24-Aug-98 Location: Alaska Analyst(s): WC, JP, WJ, BP CMS-300 Report 1.0 Inch Plugs Sample Depth Confining Pore Porosity Permeability Slip Forsheimer Grain Notes Number Stress Volume Klinkenberg Air Factor Effect Density (feet) (psi) (cc) (%) Koo Ka (b) (ß) g/cm3 50 5012.90 800 3.22 17.2 0.35 0.46 22.09 1.41 E+11 2.74 1 -~, 51 5014.15 800 3.62 19.3 0.61 0.91 30.98 1.96E+11 2.76 52 5015.25 800 3.23 17.2 0.07 0.14 75.06 6.92E+12 2.71 53 5017.25 800 3.98 21.0 4.22 5.24 13.64 2.76E+09 2.73 1 54 5020.70 800 3.56 18.9 0.70 1.03 29.61 1.17E+11 2.73 55 5021.80 800 3.48 18.4 0.29 0.44 35.72 3.30E+11 2.73 56 5022.90 800 3.41 17.7 0.13 0.23 55.51 1.25E+12 2.72 57 5025.50 800 2.96 16.0 1.67 1.76 3.27 1.90E+11 2.76 4 58 5026.90 Ambient 3.54 18.8 Fractured Sample 2.89 6 59 5037.20 800 4.57 24.0 33.85 38.28 6.59 5.84E+07 2.70 60 5038.10 800 3.90 20.6 16.34 18.86 8.05 1.60E+08 2.74 61 5038.90 800 4.31 22.6 28.40 32.36 7.09 8.05E+07 2.71 62 5039.80 800 4.54 24.7 58.50 64.62 5.12 3.14E+07 2.68 63 5041.10 800 4.72 24.8 63.44 69.79 4.88 2.96E+07 2.67 64 5042.10 800 4.81 25.1 63.87 70.19 4.82 3.37E+07 2.67 65 5043.10 800 4.60 24.5 35.19 39.71 6.45 7.54E+07 2.69 66 5044.20 800 4.39 23.2 23.66 27.08 7.42 1.23E+08 2.71 67 5045.70 Ambient 2.08 12.6 Fractured Sample 2.94 6 68 5047.75 800 3.29 17.1 0.63 0.74 11.27 2.38E+12 3.03 69 5050.75 800 3.13 16.4 8.52 10.82 14.63 1.48E+10 2.73 4 70 5052.70 800 3.42 18.1 0.35 0.57 41.76 1.64E+11 2.73 1 71 5053.30 800 3.80 20.0 0.25 0.39 38.03 O.OOE+OO 2.97 72 5056.25 800 3.27 17.1 0.26 0.37 31.04 3.28E+11 2.76 73 5057.50 800 3.25 17.6 0.69 0.93 21.79 2.46E+11 2.77 1 74 5058.20 800 3.73 19.7 1.78 2.41 21.25 1.51 E+1 0 2.69 Core Laboratories, Inc. Page 3 of 5 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or promableness of any oil, gas, coal or other mineral, property, weli or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced except in ils entirety, without the written approval of Core Laboratories. , "IJÌÅB CORE LABORATORIES \lr Company: Arco Alaska Core Lab File No.: 57161-12404 Well: Kalubik NO.2 Date: 24-Aug-98 Location: Alaska Analyst(s): WC, JP, WJ, BP CMS-300 Report 1.0 Inch Plugs Sample Depth Confining Pore Porosity Permeability Slip Forsheimer Grain Notes Number Stress Volume Klinkenberg Air Factor Effect Density (feet) (psi) (cc) (%) Koo Ka (b) (ß) g/cm3 75 5059.10 800 3.84 20.7 2.46 3.24 18.73 7.78E+09 2.75 -'. 76 5060.05 800 3.29 17.4 1.09 1.44 20.29 2.28E+11 2.73 1 77 5061.20 800 3.99 20.7 5.12 6.24 12.26 2.54E+09 2.68 78 5062.15 800 3.91 21.1 5.16 6.47 14.20 7.72E+08 2.67 79 5062.75 800 1.96 10.6 0.10 0.15 34.01 1.43E+13 2.87 80 5064.30 800 2.66 15.5 0.28 0.39 26.37 2.69E+11 2.70 1 81 5066.75 800 3.41 18.4 0.30 0.50 45.28 1.54E+11 2.69 5 82 5067.20 800 3.36 18.1 0.51 0.71 24.04 1 .41 E+ 12 2.75 83 5072.15 800 3.77 20.4 1.99 2.61 18.41 1.51E+10 2.73 84 5072.80 800 3.86 20.5 6.60 7.88 10.63 6.65E+08 2.73 85 5073.90 800 4.03 21.5 9.63 11.27 9.18 4.52E+08 2.72 86 5074.39 800 3.21 18.0 1.66 2.01 12.58 1.14E+11 2.64 4 87 5075.70 800 3.67 19.6 1.14 1.55 21.89 4.30E+10 2.78 88 5080.05 800 3.52 19.2 0.19 0.32 49.11 4.20E+11 2.93 89 5082.35 800 3.62 19.5 0.55 0.79 28.52 1.70E+11 2.92 90 5084.39 800 2.84 19.3 0.94 1.33 25.79 4.55E+10 2.72 -" 91 5087.40 800 3.75 19.9 2.62 3.25 13.97 1.99E+10 2.77 92 5097.00 800 2.58 14.1 0.30 0.40 21.61 1.51 E+11 3.11 Vertical Plugs 1V 4950.20 800 1.97 20.3 0.07 0.12 56.29 1.04E+13 2.63 2V 4956.40 800 2.69 20.9 0.37 0.53 29.95 2.33E+12 2.67 3V 4965.25 800 1.16 6.3 < 0.01 < 0.01 2.77 4V 4971.30 800 4.65 25.3 0.82 1.04 17.58 3.03E+12 2.67 5V 4977.05 800 3.02 20.8 0.46 0.74 39.89 2.49E+11 2.69 Core Laboratories, Inc. Page 4 of 5 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for Whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent 'he best judgment of Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. ~ ~iJìAB Company: Arco Alaska Well: Kalubik NO.2 Location: Alaska Sample Depth Number (feet) 6V 4984.70 7V 4986.70 8V 4992.50 9V 4996.10 10V 4998.95 11V 5008.30 12V 5012.10 13V 5025.50 14V 5037.30 15V 5039.90 16V 5043.20 17V 5047.75 18V 5052.80 19V 5058.70 20V 5060.90 21V 5067.20 22V 5072.70 23V 2097.00 Notes: CORE LABORATORIES Core Lab File No.: Date: Analyst(s): CMS-300 Report 1.0 Inch Plugs Confining Pore Porosity Permeability Slip Forsheimer Grain Stress Volume Klinkenberg Air Factor Effect Density (psi) (cc) (%) Kao Ka (b) (ß) g/cm3 800 3.65 19.3 0.07 0.12 55.06 2.67E+13 2.79 800 1.59 20.5 0.03 0.05 58.31 4.23E+13 2.67 800 2.21 18.2 0.04 0.08 66.32 9.71E+13 2.76 800 2.55 18.5 0.04 0.09 72.85 5.80E+13 2.68 800 2.73 17.4 0.02 0.03 36.66 9.28E+15 2.71 800 3.11 18.7 0.06 0.12 76.15 9.15E+12 2.70 800 2.49 19.3 0.04 0.08 62.66 1.90E+14 2.73 800 2.76 16.6 0.03 0.04 43.86 1.78E+15 2.73 800 4.38 23.7 23.06 26.12 7.05 8.76E+07 2.72 800 4.44 24.2 23.76 26.82 6.81 1.10E+08 2.68 800 4.60 24.6 23.24 26.39 7.20 1.40E+08 2.67 800 2.21 17.3 0.01 0.02 88.92 1.00E+00 3.05 800 3.37 18.4 0.07 0.13 71.30 2.13E+13 2.67 800 3.60 19.4 0.27 0.42 38.46 2.83E+11 2.68 800 3.55 18.8 0.28 0.44 37.49 2.90E+11 2.68 800 3.28 17.6 0.05 0.10 74.38 2.01 E+13 2.71 800 3.83 20.5 0.56 0.84 33.88 4.66E+11 2.72 800 1.81 13.9 0.02 0.02 22.58 4.28E+15 3.05 1 = Slightly irregular plug cylinder 2 = Plug contains one single non-seperated fracture down its length. 3 = Plug contains one single non-seperated fracture down part of its length. 4 = Plug contains one single seperated fracture bisecting its length. 5 = Plug contains seperated fracture down part of its length. 6 = Broken plug. Porosity measured at ambient conditions in Small Volume Porosimeter 57161-12404 24-Aug-98 WC, JP, WJ, BP Notes ~'. 4 4 ~.~ Core Laboratories, Inc. Page 5 of 5 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. ~ ~RJÌAB Company: Arco Alaska Well: Kalubik NO.3 Location: Alaska Sample Number Depth (feet) CORE LABORATORIES Core Lab File No.: 57161-12404 Date: 25-Aug-98 Analyst(s): WC, JP, WJ, BP CMS-300 Report 1.0 Inch Plugs Confining Pore Stress Volume (psi) (cc) Forsheimer Grain Effect Density (ß) g/cm3 Notes Porosity Permeability Klinkenberg Air (%) Koo Ka Slip Factor (b) ~, Horizontal Plugs 1 6331.60 800 4.22 22.4 0.29 0.45 38.13 2.28E+11 2.96 2 6332.00 800 0.27 1.2 1.15 1.24 4.56 1.11E+11 3.26 3 6332.50 800 4.45 19.4 1.05 1.22 9.91 1.57E+12 2.91 4 6333.00 800 4.42 19.8 0.46 0.65 26.72 2.47E+11 3.01 5 6333.50 800 4.21 19.2 1.66 2.14 17.29 4.21 E+1 0 3.11 6 6334.00 800 3.92 19.1 7.49 7.69 1.49 9.67E+09 2.77 7 6334.50 Ambient 4.13 22.3 Fractured Sample 2.98 8 6335.00 Ambient 4.64 23.2 Fractured Sample 2.67 9 6335.00 800 3.90 18.5 7.95 9.18 8.49 2.37E+09 3.02 1V 2V 6332.60 6334.80 Notes: Core Laboratories, Inc. 5 5 1 6 6 800 800 32.4 16.3 Vertical Plugs 1783.41 2403.60 0.05 0.08 14.89 53.02 1.19E+06 7.72E+13 2.79 2.81 7 2.43 3.08 1 = Slightly irregular plug cylinder 2 = Plug contains one single non-seperated fracture down its length. 3 = Plug contains one single non-seperated fracture down part of its length. 4 = Plug contains one single seperated fracture bisecting its length. 5 = Plug contains seperated fracture down part of its length. 6 = Broken plug. Porosity measured at ambient conditions in Small Volume Porosimeter 7 = Friable or unconsolidated. Mounted in tin sleeve with end-screens. --, Page 1 of 1 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. ( ('~ ApPENDIX B Dean Stark Tabular Data 81 ~ ~RJÌAB Company: Areo Alaska, Inc. Well: Kalubik NO.2 Location: Alaska DEAN STARK FLUID SATURATIONS One-Inch Plugs Sample Depth Reservoir Porosity Permeability Number Net Overburden Klinkenberg I Kair ft psig % md 1 4950.10 800 21.7 5.86 7.12 2 4951.80 800 16.6 4.45 4.98 3 4954.10 800 19.8 4.53 5.34 4 4955.70 800 17.9 0.70 0.94 5 4956.70 800 20.3 3.10 3.91 6 4959.15 800 21.1 Fractured Sample 7 4960.00 800 19.6 Fractured Sample 8 4962.25 800 20.1 2.47 3.14 9 4964.85 800 5.0 10.87 10.96 10 4965.10 800 5.0 0.82 0.85 11 4966.20 800 20.3 3.66 4.49 12 4966.45 800 17.4 0.41 0.60 13 4968.75 800 20.5 6.79 7.83 14 4969.50 800 19.0 0.29 0.42 15 4970.90 800 21.4 2.29 2.95 16 4971.10 800 25.7 87.78 93.63 17 4972.30 800 18.7 Fractured Sample 18 4973.80 800 19.0 Fractured Sample 19 4974.70 800 23.9 33.33 37.09 20 4975.30 800 18.8 Fractured Sample 21 4976.95 800 21.4 5.89 7.17 22 4977.35 800 18.9 0.26 0.43 23 4977.85 800 18.7 0.58 0.79 24 4979.15 800 9.3 0.03 0.05 25 4980.40 800 18.2 Fractured Sample 26 4981.40 800 17.4 Fractured Sample Core Laboratories, Inc. Page 1 of 4 CORE LABORATORIES CL File No.: Date: Analysts: 57161-12404 19-5ep-98 WC,WJ Saturation Grain Oil I Water Density % Pore Volume g/cm3 39.1 21.4 2.70 40.6 51.1 2.27 47.1 31.6 2.71 67.3 28.8 2.70 20.5 17.3 2.65 47.8 31.8 2.68 55.1 31.9 2.73 54.2 28.0 2.71 19.8 60.7 2.83 11.4 78.3 2.83 56.4 22.6 2.68 47.7 41.1 2.69 62.4 19.6 2.69 60.6 27.0 2.82 60.3 18.6 2.83 47.0 15.7 2.66 30.1 54.1 2.67 44.4 40.8 2.60 37.1 24.1 2.66 33.9 55.3 2.68 50.0 24.1 2.67 52.4 33.4 2.74 61.2 25.0 2.70 45.9 38.0 2.70 44.8 51.5 2.72 44.7 54.5 2.76 Final Report ~". --" The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made" The interpretations or opinions expressed represent the best judgment of Core Laboratories" Core Laboratories, however, assumes no responsibility and makes "!' warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever" This report shall not be reproduced except in lis entirety. without the written approval of Core Laboratories" , 'D1uJ JrU Company: Arco Alaska, Inc. Well: Kalubik NO.2 Location: Alaska DEAN STARK FLUID SATURATIONS One-Inch Plugs Sample Depth Reservoir Porosity Permeability Number Net Overburden Klinkenberg I Kair ft psig % md 27 4982.20 800 15.9 0.09 0.16 28 4984.95 801 17.5 0.66 0.78 29 4986.95 802 19.3 7.17 8.05 30 4988.60 803 16.1 0.18 0.28 31 4989.40 804 18.4 0.43 0.62 32 4990.90 805 17.8 0.18 0.30 33 4992.05 806 17.0 0.70 0.82 34 4993.70 807 17.9 1.40 1.71 35 4994.60 808 16.6 1.64 1.76 36 4995.10 809 16.5 0.43 0.53 37 4996.25 810 15.7 0.27 0.37 38 4997.80 811 17.7 3.93 4.23 39 4998.05 812 16.9 0.87 0.95 40 4999.30 813 16.5 0.77 1.02 41 5000.95 814 19.2 0.62 0.91 42 5001.30 815 17.9 0.20 0.34 43 5002.90 816 18.3 0.18 0.31 44 5004.90 817 17.3 0.10 0.19 45 5006.30 818 16.7 1.48 1.84 46 5008.10 819 16.4 0.22 0.30 47 5008.40 820 13.6 Fractured Sample 48 5010.90 821 16.4 3.61 3.89 49 5011.35 822 18.0 2.12 2.45 50 5012.90 823 17.2 0.35 0.46 Core Laboratories, Inc. Page 2 of 4 CORE LABORATORIES CL File No.: Date: Analysts: 57161-12404 19-5ep-98 WC,WJ Saturation Grain Oil I Water Density % Pore Volume g/cm3 50.4 36.6 2.98 45.9 46.4 2.71 55.1 34.8 2.72 38.6 60.2 2.68 44.8 44.6 2.71 55.1 32.5 2.89 44.0 55.9 2.69 54.7 37.6 2.71 50.1 49.9 2.70 39.8 57.8 2.67 63.1 28.9 2.69 71.8 18.2 2.71 52.0 38.6 2.70 62.6 30.0 2.70 64.4 23.3 2.77 74.8 18.8 2.68 57.8 27.5 2.69 47.4 32.1 2.96 30.2 54.0 2.72 54.3 34.3 2.72 60.7 38.8 2.80 39.0 51.6 2.69 50.5 37.3 2.70 35.7 56.8 2.74 Final Report ,~.. ~., whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity. proper operations, or profrtableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason ~ ~lJìAB CORE LABORATORIES Company: Arco Alaska, Inc. Well: Kalubik NO.2 Location: Alaska CL File No.: Date: Analysts: 57161-12404 19-5ep-98 WC,WJ DEAN STARK FLUID SATURATIONS One-Inch Plugs Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume g/cm3 51 5014.15 824 19.3 0.61 0.91 47.9 36.7 2.76 52 5015.25 825 17.2 0.07 0.14 54.3 35.9 2.71 53 5017.25 826 21.0 4.22 5.24 59.5 26.1 2.73 54 5020.70 827 18.9 0.70 1.03 56.6 26.4 2.73 55 5021.80 828 18.4 0.29 0.44 39.8 44.8 2.73 56 5022.90 829 17.7 0.13 0.23 51.7 36.9 2.72 57 5025.50 830 16.0 1.67 1.76 61.9 31.7 2.76 58 5026.90 831 18.8 Fractured Sample 34.7 47.4 2.89 59 5037.20 832 24.0 33.85 38.28 62.8 11.6 2.70 60 5038.10 833 20.6 16.34 18.86 58.8 12.3 2.74 61 5038.90 834 22.6 28.40 32.36 61.2 15.3 2.71 62 5039.80 835 24.7 58.50 64.62 59.3 16.3 2.68 63 5041.10 836 24.8 63.44 69.79 56.6 18.0 2.67 64 5042.10 837 25.1 63.87 70.19 61.4 15.6 2.67 65 5043.10 838 24.5 35.19 39.71 39.3 38.2 2.69 66 5044.20 839 23.2 23.66 27.08 38.6 37.5 2.71 67 5045.70 840 12.6 Fractured Sample 46.1 45.7 2.94 68 5047.75 841 17.1 0.63 0.74 54.7 19.1 3.03 69 5050.75 842 16.4 8.52 10.82 39.2 49.4 2.73 70 5052.70 843 18.2 0.35 0.57 49.5 33.6 2.73 71 5053.30 844 20.0 0.25 0.39 66.2 13.1 2.97 72 5056.25 845 17.1 0.26 0.37 50.4 36.7 2.76 73 5057.50 846 17.6 0.69 0.93 60.2 26.1 2.77 74 5058.20 847 19.7 1.78 2.41 54.4 25.4 2.69 Core Laboratories, Inc. Page 3 of 4 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Core ~~o ~~---. Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used Or relied upon for any reason whatsoever. This report shall not be reproduced except in ~s entirety, without the written approval of Core Laboratories. ~ ~IJÌAB CORE LABORATORIES Company: Arco Alaska, Inc. CL File No.: 57161-12404 Well: Kalubik NO.2 Date: 19-5ep-98 Location: Alaska Analysts: WC,WJ DEAN STARK FLUID SATURATIONS One-Inch Plugs Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume g/cm3 '-'", 75 5059.10 848 20.7 2.46 3.24 67.6 15.1 2.75 76 5060.05 849 17.4 1.09 1.44 42.4 40.9 2.73 77 5061.20 850 20.7 5.12 6.24 55.3 21.3 2.68 78 5062.15 851 21.1 5.16 6.47 68.5 11.7 2.67 79 5062.75 852 10.6 0.10 0.15 52.8 22.3 2.87 80 5064.30 853 15.5 0.28 0.39 81.0 18.0 2.70 81 5066.75 854 18.3 0.30 0.50 42.3 46.8 2.69 82 5067.20 855 18.1 0.51 0.71 59.8 22.3 2.75 83 5072.15 856 20.4 1.99 2.61 66.2 25.2 2.73 84 5072.80 857 20.5 6.60 7.88 57.0 21.5 2.73 85 5073.90 858 21.5 9.63 11.27 61.8 20.5 2.72 86 5074.39 859 17.6 1.66 2.01 47.8 38.9 2.64 87 5075.70 860 19.6 1.14 1.55 74.8 15.8 2.78 88 5080.05 861 19.2 0.19 0.32 54.8 29.2 2.93 89 5082.35 862 19.5 0.55 0.79 53.7 28.9 2.92 _~c 90 5084.39 863 19.5 0.94 1.33 47.7 28.8 2.72 91 5087.40 864 20.1 2.62 3.25 56.0 26.1 2.77 92 5097.00 865 14.2 0.30 0.40 41.1 31.4 3.11 Core Laboratories, Inc. Page 4 of 4 Final Report The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment 01 Core Laboratories. Core Laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core Laboratories. ~ ~RJìAB Company: Well: Location: Sample Number 1 2 3 4 5 6 7 8 9 Core Laboratories, Inc. Arco Alaska, Inc. Kalubik NO.3 Alaska Depth DEAN STARK FLUID SATURATIONS One-Inch Plugs Reservoir Net Overburden psig ft 6331.60 6332.00 6332.50 6333.00 6333.50 6334.00 6334.50 6335.00 6335.00 * = Equipment Error 800 800 800 800 800 800 800 800 800 Porosity % 20.0 1.2 19.4 19.8 19.2 19.1 22.3 23.2 18.5 Permeability Klinkenberg I Kair md 0.29 0.45 1.15 1.24 1.05 1.22 0.46 0.65 1.66 2.14 7.49 7.69 Fractured Sample Fractured Sample 7.95 9.18 Page 1 of 1 CORE LABORATORIES CL File No.: Date: Analysts: 57161-124048 19-5ep-98 WC,WJ Saturation Grain Oil I Water Density % Pore Volume g/cm3 54.2 23.7 2.96 * * 3.26 73.0 8.8 2.91 51.8 29.0 3.01 45.6 23.3 3.11 40.4 58.2 2.77 71.0 26.6 2.98 72.3 25.9 2.67 50.5 42.8 3.02 ~~ Final Report The analyses, opinions or interpretations contained in this report are based upon obseNations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories. Core laboratories, however, assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced except in its entirety, without the written approval of Core laboratories. REV DATE BY CK APP ') DESCRIPTION REV DATE BY )':K APP DESCRIPTION I 29 28 27 26 ·2S 30 29 28 :t-: 32 34 3S 36 31 32 33 Tl jN T1 N 5 2 6 5 3 2 ~ ~. \S'O II 12 8~ 9 10 II eKALUBIK #1 ~&- 14 13 18 17 16 IS 14 ~ ~ 24 , ~ 22 19 20 21 22 23 .0 U 30 29 " I CE ROAD 30' (Typ.) 440 I 160' KALUBIK #2. / 180' 260' /~ o o LOCA TED WITHIN PROTRACTED SEC. 15, TWP. 1.3 N., RGE. 7 E. UMIA T MERIDIAN LA T. = 70· 29' 05.57" N LONG. = 150· 18' 21.82" W 1099' F.N.L., 2124' F.W.L. Y = 6,027,050 X = 462,550 ~, KALUBIK #2 240' ICE ROAD 3D' (Typ.) NOTES ,. BASIS OF HORIZONTAL LOCA TlON IS U.S.G.S. MONUMEN T "NORMA ~ 2. COORDINA TES SHOWN ARE ALASKA STA TE PLANE ZONE 4, N. A. D. 27. 3. DA TE OF SURVEY: 1/19/98 Ø- LOUNSBURY 1\ & ASSOCIATES, INC. , -E~NEERS PLANNERS SURVEYORS Proposed Ice Pad '\. ARca Alaska, Inc. <> Subsidiary of Atlantic Richfield Company CADD FILE NO. LK601261.dwg 2/2/98 DRAWING NO: KALUBIK 2 EXPLORATORY WELL CONDUCTOR AS-STAKED SHEET: REV NSK 6.01-d261 1 OF 1 : 0 " ¡' REV DArE 8Y CK APP DESCRIPTION REV DATE BY CK APP DE~CRIPTION f ) ') \ ~ 2. 27 2' 2~ JO ~ ZI f II! :IS 36 31 3l :J3 KALUBIK #2 ! H!~ , 3 3 2 f .. +~, w ICE ROAD LOCA TED WITHIN PROTRACTED ~ [ 30' (Typ.) 'ßIO II "'0 II f' SEC. 15, TWP. 1.:5 N., RGE. 7 E. 12 8~ , 10 ~ eKALUBIK '1 ~'" I UMIA T MERIDIAN .: LAT. 70' 29' 05.576" N KAt UBIK 1#2 r = ~ I 150' 18' 21.822", W 14 13 II 17 .. I~ 14 LONG. = f 1099' F.N.L., 212.:5' F.W.L. i ~ i Y = 6,027,050.30 '" ~ I 2r 23 19 20 21 2r 23 ¡ ¡ X = 462,549.96 Co) Cí' I Top of Conductor = 4.64 Top of Rig Pad (Ice) = 4.7 :JII 440' Proposed Ice Pad 183' I I ~ KALUBIK #2 240' ICE ROAD 30' (Typ.) ~~"'-"'" ..-';'r: OF AI "'. .4tÞ ~ \.,... ............ <....,<J.~.. # ~ r :..... ..... t . Co::> ..' *....... . ..' '0.. " : 1:)./ 49th \;V~ ø : · ~ " .....:............................. ......":...... ~ ..... .:......~........~....." ¡Q' '0:11 ~ ~ \ BRIAN G. MANGOLD ¡ E" ~/.·o ...~. . ...... ú'A '. LS-8626 .0 ri!- . ..... ð ". .0' ~"". ... ~~ ....¡;....~ -~s .... ~.:' .. D A ............... Þ-~<:;) . "" :?QJ:"rSSIONA\.. \.. '!fÞ.. '''''-'''~~-';' ARCO Alaska, Inc. <> Subsidiary of Atlantic Richfield Company CADD FILE NO. ORA WING NO: LK601261.dwg 2/05/98 .þ.. o o NOTES T. BASIS OF HORIZONTAL LOCA nON IS U.S.G.S. MONUMEN T "NORMA ': 2. COORD IN A TES SHOWN ARE ALASKA STA TE PLANE ZONE 4, N.A.D. 27. 3. DA T£ OF SURVEY: 2/04/98 SURVEYOR'S CERTlFICA TE I HEREBY CERTIFY THA T I AM PROPERL Y REG I STEREO AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THA T THIS PLA T REPRESENTS A ,SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVI S ION AND THA TALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF F£BURARY 5, 1998 ß1 LOUNSBURY ^ & ASSOCIATES, INC. · ENGINEERS PLANNERS SURVEYORS 'qb . KALUBIK 2 EXPLORATORY WELL CONDUCTOR AS-BUILT SHEET: CEA-M1XX-601D266 1 Of" 1 REV: o ~ ¡ ~, f t í 1 " ¡ ! 'j t , 1 ~ 1 i . ~ ~ \, -.: . ~ .. , , i ~ ..:. ~ ~ If ~ ~ I " ~ ~ t Date: 3/24/98 ') ') ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL:KALUBIK #2 WELL_ID: AX9824 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: SPUD:02/07/98 START COMP: RIG:DOYON RIG 141 WI: 0% SECURITY: 0 API NUMBER: 50-103-20252-00 BLOCK: FINAL: -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 02/07/98 (D1) TD : 21 7' ( 2 1 7 ) SUPV:RLM 02/08/98 (D2) TD : 1 7 8 3 ' (15 6 6 ) SUPV:RLM 02/09/98 (D3) TD : 2 52 5' ( 7 4 2 ) SUPV:RLM 02/10/98 (D4) TD : 2 52 5' ( 0 ) SUPV:RLM 02/11/98 (D5) TD : 2 7 5 0' ( 2 2 5 ) SUPV:RLM MW: 10.0 VISC: 165 PV/YP: 24/22 APIWL: 12.8 DRILLING AHEAD AT 610' Accept rig at 0200 hrs. 2/7/98. Function test diverter system approved by Larry Wade. Held pre-job safety meeting. Drill 12.25" hole from 111' to 217'. MW: 10.0 VISC: 84 PV/YP: 24/21 APIWL: 11.6 DRILLING AT 2300' Drill and survey with MWD from 217' to 1783'. Circulate bottoms up and pump slug. Wipe hole from 1783' to 859'. Work through tight hole at 1300', remainder of trip free. CBU. MW: 10.0 VISC: 62 PV/YP: 19/18 APIWL: 0.0 CEMENTING 2ND STAGE ON SURFACE Pre-job safety meeting. Drill 12.25" hole and survey with MWD from 1783' to 2525'. Wipe hole from 2525' to 1177', hole free. Wash 30' to bottom, hole free, no fill. Pump hi/low vis sweep and circulate hole clean, pump slug. Rig up to run 9-5/8" casing. Held pre-job safety meeting. Run 9-5/8" casing. MW: 9.5 VISC: 43 PV/YP: 10/11 APIWL: 2.0 MAKE UP BHA Pre-job safety meeting. Finish running 9-5/8" casing to 2513'. Perform 2nd stage cement job. First stage through shoe at 2513' and second stage through stage collar at 1703'. ND diverter and set back. Wash cement out of 16x9-5/8" annulus. NU BOPE. Test BOPE. Bottom pipe rams failed. Remove bottom rams and redress. MW: 9.5 VISC: 43 PV/YP: 10/11 APIWL: 0.0 DRILLING Pre-job safety meeting. NU BOPE. Install fresh set lower rams. Test lower pipe rams to 500/5000. BOPE test witnessed and approved by Larry Wade (AOGCC). Drill out stage collar at 1703'. Test casing to 2000 psi. RIH tag cement at 2316'. Test casing to 2000 psi for 30 minutes. Drill out cement baffle at 2386', float collar at 2422', and float shoe at Date: 3/24/98 02/12/98 (D6) TD : 4 7 9 l' (2 0 41 ) SUPV:RLM 02/13/98 (D7) TD : 5 0 3 2' ( 2 41 ) SUPV:RLM 02/14/98 (D8) TD : 512 2' ( 9 0 ) SUPV:RLM 02/15/98 (D9) TD : 5 6 5 0' ( 52 8 ) SUPV:RLM 02/16/98 (Dl0) TD : 5 6 5 0' ( 0 ) SUPV:RLM 02/17/98 (Dl1) TD : 5 650' ( 0 ) SUPV:RWS ') ) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 2513'. Drill new hole from 2525' to 2545'. Change over to fresh 9.5 ppg mud. LOT shoe at 2513' MD, EMW 12.48 ppg. Drill 8.5" hole from 2545' to 2750'. MW: 9.5 VISC: 51 PV/YP: 14/23 APIWL: 0.0 RIH ROTARY ASSEMBLY Pre-job safety meeting. Drill 8.5" hole survey with MWD, log with LWD from 2750' to 4791'. Pump hi-vis sweep. Circulate bottoms up. Observe well and pump slug. POOH to shoe, hole free, observe well. MW: 9.5 VISC: 50 PV/YP: 11/16 APIWL: 5.0 LAY DOWN CORE Pre-job safety meeting. Wash to bottom at 4791', no fill. Circulate bottoms up 600+ units gas. Rotary drill from 4791' to 4950'. Circulate, bottoms up gas 600+ units, no free oil in mud. Pumped hi-vis sweep, observed well, pumped slug. POOH, hole free. RIH with coring BHA to 4820'. Wash to 4941', hit small soft bridge, rotate through wash to 4950'. Core with 8.5" x 4" core bit from 4950' to 5032'. MW: 9.5 VISC: 50 PV/YP: 11/14 DRILLING AHEAD @ 5300' Pre-job safety meeting. POOH cored 82', recovered 77.25'. 49"9"2':--C"ore #2 from 5032' 'to recovered 65.25'. APIWL: 5.2 C\'YV' '- with core barrel #1. Core #1 RIH with core barrel #2 to 5122'. Core #2 c_c:~_~_ª___2_º-~. ....,....,',..~...."...~_......_,-,..,.......,--'~'~þ MW: 9.8 VISC: 51 PV/YP: 12/20 APIWL: 4.0 RUNNING SCHLUMBERGER 'E' LOGS Pre-job safety meeting. Drill from 5122' to 5650'. Circulate and condition mud and hole. Had sloughing silty shale, splintery to blocky. Hole would not clean up. Weighted up to 9.8 ppg. Pump slug. Worked through to clean up. Pump hi-vis sweep. Mud weight increase reduced size and amount of sloughing silty shale. Circulated hole clean. Hole free. Ran DSL__ GR an. d Sp from 5630' . \ \ - \N\~\ t~,d APIWL: '\N\ "ù 'S 3.8 MW: 9.8 VISC: 52 PV/YP: 12/21 CIRC & COND HOLE FOR 7" CASING Pre-job safety meeting. Continue running DSI/GRISp_from 5630' to 2513'. Run #2 CMR/PEX/GR from 5630' to 2513'. Gran GR from 2513' to surface. Run #3 FMI. Ran #4 RFT. -~.--- MW: 9.8 VISC: 51 PV/YP: 13/18 APIWL: 4.4 NIPPLING UP BOPE Pre-job safety meeting. Wash from 5562'-5650'. Run 7" casing. Date: 3/24/98 02/18/98 (D12) TD : 5 6 5 0' ( 0 ) SUPV:RWS 02/18/98 (D13) TD : 5 6 5 0' ( 0 ) SUPV:RWS 02/19/98 (D14) TD : 5 6 5 0' ( 0 ) SUPV:RWS 03/07/98 (D15) TD : 5 6 5 0' ( 0 ) SUPV:RLM 03/08/98 (D16) TD : 5 6 5 0' ( 0 ) SUPV:RLM 03/09/98 (D17) TD : 5 6 5 0' ( 0 ) SUPV:RLM ') ) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 FREEZE PROTECT 7X9-5/8 ANNULUS PJMS-planned ops 1st day back. Rih p/u 64 jts tbg - 2000'. MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 FREEZE PROTECT 7X9-5/8 ANNULUS PJMS-planned ops 1st day back. Rih p/u 64 jts tbg - 2000'. MW: 8.8 VISC: 0 PV/YP: 0/ 0 RIG RELEASED TO KALUBIK #3. Rig released 0900 2/19/98. APIWL: 0.0 MW: 10.3 VISC: 66 PV/YP: 24/22 APIWL: 9.6 LAY DOWN 3.5" DP Move rig from Kalubik 3 to Kalubik 2 and rig up. PJSM, planned ops. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CLEAN MUD TANKS Rig accepted at 1100 hrs on 111~-~~ PJSM planned ops, service rig. CIP at 1553 hrs 3/8/98. Pulled up to 75' and circulated clean. Layed down 3.5" dp. MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED @ 1330 HRS 3/9/98 PJSM, planned ops. APIWL: 0.0 End of WellSummary for Well:AX9824 -.. ) ) ~~ ~~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 8, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kalubik #2 (Permit No. 98-20/398-043/398-062) Well Completion Report Dear Mr. Commissioner: ARCO Alaska, Inc., as operator of the exploration well Kalubik #2, submits the enclosed "Well Completion Report" (form 407). The Commission is requested to keep confidential the enclosed information due to the exploratory nature of the well. If you have any questions regarding this matter, contact me at 265-6206. Sincerely, :kilJ - ~ ~l"ý(;'H/ M. Zanghi Drilling Superintendent Kuparuk Development \ . .'- ¡'-', I~_ ') ¡I·· .~.... E I ~:f ~ ~\ \:-". Ii·· ~ ¡.} t" 1 ß ~ ';¡' L 'd' 11 ~ f."_,, ".. r, ,,") (. \""\ 19c;g J'....i· j'\ ~ji...~ \ v,~ C-""",,,,",;..'s"on , n'\ n ~';!'" Cons l¡\H¡"I~h' j~\3.SKa vlJ (;l ~,c'~",' OJ . y,\lC: lor uge MZlskad .,. ) ') 9'6' o~o ";1 \'~ r~ i¡\~'f' ~ f!\ ' " .'" I....~, .J J 'k , :!;) itU: :.::5 5::'l SPERRY-SUN DRILL~NG SERVICES PAGE 1 ANCHORAGE ALASKA ARCO Þ.LÞ.SKÞ., INC. DATE OF SURVEY: 021598 KALUBIK #2 MWD SURVEY 5010320252 a:> JOB NUMBER: AKMM80119 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 34.00 FT. COMPUTATION DATE: 4/ 1/98 OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -34.00 0 0 N .00 E .00 .OON .OOE .00 127.35 127.35 93.35 0 14 S 88.02 E .19 .01S .27E -.01 220.15 220.15 186.15 0 22 N 79.75 E .16 .04N .76E .04 316.73 316.73 282.73 0 12 N 64.97 E .18 .17N 1.22E .17 410.86 410.85 376.85 0 36 N 89.21 E .45 .25N 1.88E .25 500.18 500.17 466.17 0 42 N 85.59 E .11 .30N 2.90E .30 593.74 593.72 559.72 0 55 N 86.27 E .24 .39N 4.22E .39 684.98 684.94 650.94 1 10 S 86. 68 E .32 .38N 5.89E .38 772.75 772.69 738.69 1 13 S 85.95 E .05 .26N 7.72E .26 867 . 46 867.38 833.38 1 30 S 66.90 E .56 .30S 9.88E -.30 957.08 956.96 922.96 1 36 S 67.82 E .11 1.24S 12.13E -1.24 1049.08 1048.92 1014.92 1 55 S 70.52 E .35 2.24S 14.78E -2.24 1138.17 1137.95 1103.95 2 9 S 66.53 E .30 3.4 OS 17.72E -3.40 1233.37 1233.11 1199.11 1 21 S 77.70 E .91 4.35S 20.45E -4.35 1322.64 1322.35 1288.35 1 20 S 78.79 E .03 4.78S 22.50E -4.78 1416.25 1415.93 1381.93 1 25 S 69.24 E .26 5.40S 24.66E -5.40 1509.93 1509.58 1475.58 1 29 S 69.95 E .08 6.23S 26.89E -6.23 1601.30 1600.92 1566.92 1 35 S 65.13 E .18 7.17S 29.16E -7.17 1690.11 1689.70 1655.70 1 35 S 66.57 E .05 8.18S 31.40E -8.18 1789.31 1788.86 1754.86 1 42 S 61.15 E .20 9.44S 33.96E -9.44 1882.69 1882.19 1848.19 1 45 S 61.79 E .06 10.79S 36.45£ -10.79 1976.55 1976.00 1942.00 1 55 S 61.94 E .18 12.22S 39.11£ -12.22 2069.55 2068.95 2034.95 2 7 S 64.19 E .22 13.70S 42.04£ -13.70 2161.99 2161.34 2127.34 1 17 S 62.94 E .90 14.92S 44.51E -14.92 2254.12 2253.46 2219.46 0 16 S 35.89 E 1.15 15.57S 45.56E -15.57 2347.52 2346.86 2312.86 0 19 S 55.83 E .12 15.89S 45.90E -15.89 2440.00 2439.34 2405.34 0 21 S 22.77 E .21 16.30S 46.23E -16.30 2529.83 2529.17 2495.17 0 24 S 24.88 E .07 16.84S 46. 47E -16.84 2621.86 2621.19 2587.19 0 27 S 28.39 E .05 1 7 . 46S 46.78E -17.46 2715.83 2715.16 2681.16 0 28 S 19.91 E .07 18.14S 47.09£ -18.14 2806.75 2806.08 2772.08 0 25 S 37.52 E .16 18.76S 47.42E -18.76 2898.24 2897.56 2863.56 0 29 S 46.12 E .11 19.308 47.90E -19.30 2988.39 2987.-:-:' 2953.71 0 30 S 47.38 E .03 19.84S 48.48E -19.84 3086.90 3086.22 3052.22 0 31 S 40.77 E .06 20.47S 49.09E -20.47 3179.72 3179.03 3145.03 0 35 S 32.63 E .11 21.198 49.62E -21.19 og O.~¡G NA'~·f!,¡ '. III. ) SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKÞ.,INC. KALUBIK #2 5010320252CO NORTH SLOPE BOROUGH COMPUTATION DATE: 4/ 1/98 ) PAGE 2 DATE OF SURVEY: 021598 MWD SURVEY JOB NUMBER: AKMM80119 KELLY BUSHING ELEV. = 34.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 3268.95 3362.52 3456.28 3549.98 3642.39 3733.78 3828.27 3922.59 4014.23 4107.18 4200.85 4290.94 4385.64 4404.05 4569.77 4664.94 4742.10 4850.35 4949.46 5037.14 5126.18 5219.68 5312.09 5402.18 5499.22 5582.95 5650.00 3268.26 3361.82 3455.58 3549.27 3641.68 3733.06 3827.55 3921.86 4013.50 4106.44 4200.11 4290.19 4384.89 4403.30 4569.00 4664.17 4741.32 4849.56 4948.66 5036.33 5125.36 5218.84 5311.23 5401.31 5498.33 5582.05 5649.08 3234.26 3327.82 3421.58 3515.27 3607.68 3699.06 3793.55 3887.86 3979.50 4072.44 4166.11 4256.19 4350.89 4369.30 4535.00 4630.17 4707.32 4815.56 4914.66 5002.33 5091.36 5184.84 5277.23 5367.31 5464.33 5548.05 5615.08 o 31 o 30 o 37 o 36 o 38 o 37 o 40 o 34 o 37 o 34 o 34 o 32 o 35 o 43 o 39 o 39 o 39 o 52 o 57 o 58 1 1 1 1 1 1 1 S 24.79 E S 31.19 E S 33.16 E S 28.93 E S 24.77 E S 32.04 E S 30.16 E S 28.97 E S 29.47 E S 27.11 E S 31.72 E S 39.04 E S 32.96 E S 33.46 E S 28.14 E S 24.47 E S 10.83 E S 18.63 E S 17.97 E S 19.66 E o S 18.85 E 1 S 20.02 E 5 S 12.68 E 4 S 13.95 E 5 S 9.17 E 6 S 12.89 E 6 S 12.89 E .12 .06 .13 .06 .07 .09 .06 .11 .06 .06 .05 .09 .08 .70 .05 .05 .20 .22 .07 .05 .04 .04 .16 .03 .09 .09 .00 21.95S 22.69S 23.48S 24.34S 25.23S 26.11S 27.02S 27.91S 28.75S 29.61S 30.43S 31.14S 31.90S 32.07S 33.78S 34 .76S 35.59S 36.99S 38.50S 39.89S 41.35S 42.92S 44.56S 46.21S 48.00S 49.58S 50.85S THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 80.19 FEET AT SOUTH 50 DEG. 39 MIN. EAST AT MD = 5650 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG .00 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,650.00' MD 50.04E 50.43E 50.93E 51.45E 51.90£ 52.38£ 52.93E 53.43E 53.90£ 54.36E 54.83E 55.33£ 55.88E 55.99E 57. OlE 57.50£ 57.76£ 58.14£ 58.64E 59.12£ 59.63£ 60.18E 60.66E 61.05E 61.41E 61.72E 62.01£ VERT. SECT. -21.95 -22.69 -23.48 -24.34 -25.23 -26.11 -27.02 -27.91 -28.75 -29.61 -30.43 -31.14 -31.90 -32.07 -33.78 -34.76 -35.59 -36.99 -38.50 -39.89 -41. 35 -42.92 -44.56 -46.21 -48.00 -49.58 -50.85 ) ) SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA., INC. KALUBIK #2 501032025200 NORTH SLOPE BOROUGH COMPUTATION DATE: 41 1/98 DATE OF SURVEY: 021598 JOB NUMBER: AKMM80119 KELLY BUSHING ELEV. = 34.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -34.00 .00 N .00 E .00 1000.00 999.87 965.87 1.69 S 13.24 E .13 .13 2000.00 1999.44 1965.44 12.59 S 39.81 E .56 .43 3000.00 2999.32 2965.32 19.91 S 48.55 E . 68 .12 4000.00 3999.27 3965.27 28.61 S 53.82 E .73 .05 5000.00 4999.19 4965.19 39.29 S 58.90 E .81 .07 5650.00 5649.08 5615.08 50.85 S 62.01 E .92 .11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ') ) SPERRY-SUN DRILLING SERVICES PAGE 4 ANCHORAGE ALASKA ARCO ALASKÞ., :NC. DATE OF SURVEY: 021598 KALUBIK #.2 5010320252 ùC JOB NUMBER: AKMM80119 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 34.00 FT. COMPUTATION DATE: 4/ 1/98 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -34.00 .00 N .00 E .00 34.00 34.00 .00 .00 N .00 E .00 .00 134.00 134.00 100.00 .01 S .29 E .00 .00 234.00 234.00 200.00 .05 N .84 E .00 .00 334.00 334.00 300.00 .19 N 1.28 E .00 .00 434.01 434.00 400.00 .25 N 2.13 E .01 .00 534.01 534.00 500.00 .33 N 3.31 E .01 .01 634.03 634.00 600.00 .43 N 4.87 E .03 .01 734.05 734.00 700.00 .32 N 6.90 E .05 .02 834.07 834.00 800.00 .05 N 9.07 E .07 .02 934.11 934.00 900.00 .99 S 11.53 E .11 .04 1034.15 1034.00 1000.00 2.07 S 14.31 E .15 .05 1134.21 1134.00 1100.00 3.34 S 17.58 E .21 .06 1234.26 1234.00 1200.00 4.36 S 20.47 E .26 .05 1334.29 1334.00 1300.00 4.83 S 22.77 E .29 .03 1434.32 1434.00 1400.00 5.56 S 25.08 E .32 .03 1534.35 1534.00 1500.00 6.45 S 27.49 E .35 .03 1634.39 1634.00 1600.00 7.56 S 29.99 E .39 .04 1734.43 1734.00 1700.00 8.67 S 32.53 E .43 .04 1834.47 1834.00 1800.00 10.09 S 35.15 E .47 .04 1934.52 1934.00 1900.00 11.55 S 37.87 E .52 .05 2034.58 2034.00 2000.00 13.14 S 40.88 E .58 .06 2134.64 2134.00 2100.00 14.64 S 43.96 E .64 .06 2234.66 2234.00 2200.00 15.49 S 45.51 E .66 .02 2334.66 2334.00 2300.00 15.85 S 45.85 E .66 .00 2434.66 2434.00 2400.00 16.27 S 46.21 E .66 .00 2534.66 2534.00 2500.00 16.87 S 46.48 E .66 .00 2634.67 2634.00 2600.00 17.55 S 46.83 E .67 .00 2734.67 2734.00 2700.00 18.29 S 47.14 E .67 .00 2834.67 2834.00 2800.00 18.92 S 47.54 E .67 .00 2934.68 2934.00 2900.00 19.51 S 48.13 E .68 .00 3034.68 3034.00 3000.00 20.12 S 48.78 E .68 .00 3134.69 3134.00 3100.00 20.81 S 49.37 E .69 .00 3234.69 3234.00 3200.00 21.66 S 49.91 E .69 .00 3334.69 3334.00 3300.00 22.48 S 50.31 E .69 .00 ) ') SPERRY-SUN DRILLING SERVICES PAGE 5 ANCHORAGE ALASKA ARCO Þ.LÞ.SKA, :NC. DATE OF SURVEY: 021598 KALUBIK #2 501032025200 JOB NUMBER: AKMM80119 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 34.00 FT. COMPUTATION DATE: 4/ 1/98 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3434.70 3434.00 3400.00 23.28 S 50.80 E .70 .00 3534.70 3534.00 3500.00 24.20 S 51.37 E .70 .01 3634.71 3634.00 3600.00 25.15 S 51.87 E .71 .01 3734.72 3734.00 3700.00 26.12 S 52.38 E .72 .01 3834.72 3834.00 3800.00 27.09 S 52.96 E .72 .01 3934.73 3934.00 3900.00 28.02 S 53.49 E .73 .01 4034.73 4034.00 4000.00 28.94 S 54.01 E .73 .01 4134.74 4134.00 4100.00 29.86 S 54.49 E .74 .01 4234.74 4234.00 4200.00 30.72 S 55.00 E .74 .00 4334.75 4334.00 4300.00 31.46 S 55.59 E .75 .00 4434.76 4434.00 4400.00 32.39 S 56.20 E .76 .01 4534.76 4534.00 4500.00 33.43 S 56.82 E .76 .01 4634.77 4634.00 4600.00 34.45 S 57.36 E .77 .01 4734.78 4734.00 4700.00 35.51 S 57.75 E .78 .01 4834.78 4834.00 4800.00 36.77 S 58.07 E .78 .01 4934.80 4934.00 4900.00 38.26 S 58.57 E .80 .01 5034.81 5034.00 5000.00 39.86 S 59.10 E .81 .01 5134.83 5134.00 5100.00 41.50 S 59.68 E .83 .02 5234.84 5234.00 5200.00 43.18 S 60.27 E .84 .02 5334.86 5334.00 5300.00 44.98 S 60.75 E .86 .02 5434.88 5434.00 5400.00 46.81 S 61.20 E .88 .02 5534.90 5534.00 5500.00 48.67 S 61.52 E .90 .02 5634.91 5634.00 5600.00 50.56 S 61.95 E .91 .02 5650.00 5649.08 5615.08 50.85 S 62.01 E .92 .00 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ( t t 9~' o'~o ~/(9 1'10 CONF'DENT¡ft~l ~er A05~C r€~ 10 AAC 25 5~7 ~~ ~". ( ARCO KALUBIK #2 Section 15- T13N-R7E Colville Delta Kuparuk North Slope Borough, Alaska Paul R. StilesJ Geolo,gist Artem RatchkovskiJ- Geologist Epoch Well Logging, Inc. ( . (" OPERATOR: WELL NAME: LOCATION: FIELD: COORDINATES: ELEVATIONS: WATER DEPTH: COUNTY: STATE: API INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE (T.D.): CONTRACTOR: RIG#: RIG TYPE: MUD PUMPS: COMPANY GEOLOGISTS: COMPANY ENGINEERS: TOOLPUSHERS: MUD COMPANY: MUD'ENGINEERS: MUDTYPES: HOLE SIZES: ( CASING DATA: MUDLOGGING SERVICES: TYPE UNIT: UNIT#: LOGGING GEOLOGISTS: SAMPLE TECHNICIANS: LWD IMWD: ELECTRIC LOGS BY: LOG INTERVALS: LOG SUITES RUN: LOGGING ENGINEERS: DST INTERVALS: TESTING COMPANY: CORED INTERVALS: CORING COMPANY: BOTTOM HOLE FORMATION: WELL STATUS: ( ( ( WELL RESUME ARCO ALASKA KALUBIK #2 SEC. 15 T13N R7E, SM WILDCAT 1099'FNL,2124'FWL R.K.B. = 34' -3' NORTH SLOPE BOROUGH ALASKA 50-103-20252 7 FEBRUARY, 1998 5,650' 15 FEBRUARY, 1998 DOYON DRILLING, INC. #141 SCR DIESEL-ELECTRIC (2) EMSCO FB1600 (6" X 12") PAUL DECKER, JEFF CORRIGAN BOBBIE MORRISON I RAY SPRINGER BAROID DRILLING FLUIDS, INC. SEAWATER BIPOL YMER 20" TO 111', 12 1/4" TO 2525', 8 1/2" TO 5650' 9 5/8" TO 2525' EPOCH WELL LOGGING, INC. (FID) GAS DETECTION, RIGWATCH, RIGTRAK 14 PAUL R. STILES, ARTEM RATCHOVSKI NONE SPERRY -SUN SCHLUMBERGER 5650' -2525' FDCICNL, DIL, SONIC, GR, CMR NONE NONE NONE 4950'-5122' RECOVERY 142.5' BAKER HUGHES INTEQ BASAL MORAINE AWAITING TESTING (' 218/98 554' 219/98 2247 2110/98 2525' 2111198 2525' 2/12/98 3152' 2113/98 4791' 2114/97 ( 5028' 2/15/98 5224' 2/16198 5650' 2117/98 5650' 2/18/98 5650' 2/19/98 5650' ( ( ( ARca KALUBIK NO.2 RIG ACTIVITY NIPPLE UP BOPE. PICK UP 12 1/4" BHA. DRILL OUT CONDUCTOR. DRILL AHEAD WITH 121/4 HOLE FROM 111' TO 554'. DRILL AHEAD FROM 554' TO 1783'. MAKE A 10 STAND WIPER TRIP AT 1783'. DRILL AHEAD TO 2247. DRILL AHEAD FROM 2247 TO 2525'. MAKE A WIPER TRIP IN PREPARATION FOR CASING RUN. RUN 95/8" CASING AT 2525'. CEMENT CASING. NIPPLE DOWN AND NIPPLE UP BOPE. PICK UP NEW BHA. DRILL OUT CEMENT IN CASING. TEST CASING. DRILL OUT SHOE. RUN FORMATION INTEGRITY TEST. DRILL AHEAD WITH 8 1/2" HOLE TO 3152'. DRILL AHEAD TO 4991'. TRIP TO CHANGE BHA. LAY DOWN MUDMOTOR AND PICK UP NEW BHA. TRIP IN HOLE WITH RRB#2. DRILL AHEAD TO 4936'. CIRCULATE BOTTOMS UP LOOKING FOR CORE POINT, DRILL AHEAD TO 4950'. TRIP OUT OF HOLE TO PICK UP CORE BARREL. PICK UP CORE BARREL. TRIP IN HOLE AND CORE TO 5032'. BARREL JAMMED. TRIP OUT OF HOLE WIT rlCORENO.'1 , LAY DOWN CORE NO.1. RECOVERED 77.25'OF 82' TOTAL. TRIP IN HOLE FOR CORE NO.2. CORE TO 5122'. TRIP OUT OF HOLE WITH CORE NO.2. LAY DOWN CORE. RECOVERED 65.25' OF 90' TOTAL. TRIP IN HOLE WITH RRB#2. DRILL AH EAD TO 5224'. DRILL AHEAD TO 5650' CIRCULATE AND BUILD MUD WEIGHT TO 9.8 PPG. TRIP OUT OF HOLE FOR ELECTRIC LOGS. RUN ELECTRIC LOGS, RUN ELECTRIC LOGS. TRIP IN HOLE TO CONDITION FOR CASING RUN. CUT AND SLIP DRILLING LINE. CIRCULATE AND CONDITION HOLE FOR PRODUCTION CASING RUN. RUN PRODUCTION CASING. CIRCULATE THROUGH CASING. CEMENT CASING. CHANGE OUT RAMS. RUN PRODUCTION TUBING IN HOLE. (' MUDLOG Tl 's / CORRELA TION Sf AMARY ARCa ALASKA, INC. Kalubik #2 Section 15 - T13N - R7E North Slope Borough, Alaska K.B. = 34' FORMATION M.D. Subsea K-10 / C-80 2932' -2898' K-5/ C-50 3244' -321{)' K-3 4260' -4226' -Top of Moraine Sand 4920' -4886' T otat Depth 5650' ';5650' ( ( ~, ARca ALASKA, INC. Kalubik #2 Doyon Drilling Performance Chart ept~ vs Time ~ J . .", ¿¿~~:id~.·..'.~:~~! , . , ... ~ .~ ..-.. -... ("" ( (' SUMMARY AND CONCLUSIONS ( ARCO ALASKA spudded the Kalubik #2 well on February 7, 1998 with Doyon Drilling Rig #141 as the start of a possible two well drilling program. The primary objective of this wildcat well was the turbidite Moraine sands of the West Sak Formation lying in a positive structure off the Colville Delta. Drilling progressed with no difficulties. The permafrost ended at approximately 1290', with no gas hydrates detected. The decision was made to T.D. the weU at 11 :OOam, February 15, 1998 at a depth of 5650'. (FID) gas detection and two geologist Rigwatch/RigtraklDML mudlogging services commenced on February 7,1998 at 111' to T.D. above the HRZ. Several significant oil and gas shows were observed in this well and are briefly summarized below. The first significant shows were observed within the Moraine sand from 4920' to 5135'. Excellent oil indicßtorsaoo heavy C-5 chromatogfapRy ·readings were observed. These very fine grained sands anp silts were saturated with oil, had a strong petroleum odor, left free oil in the drilling mud, gav~ a bright yellowwhite fluorescence, immediate streaming bright yellowwhite to yellowgreen cut, and left a moderate yellow residual ring fluorescence. These sands were extremely fine grained, grading to silt, but should be producable with proper stimulation techniques. The lower Moraine sands.a1so indicated·a possibleoi1 reservoir from 5224' to 5303'-artd 5626' to 5645'. Tpese sands indicated the same fluorescence in the well, with a gas peak of 140u. This zone cpuld be economic. One thing was definitely noticed during the coring of the well. It is stiU, difficult to retain core in the core catcher, losing 30'totalfrom both cores. They appear to have slid out through the bottom of the catcher after they had been broken off before the trip. Perhaps a PVC core barrel may aid in keeping the core inside the barrel, or checking the inner diameter of the barrel versus the inner diameter of the core bit, and adjusting for washout. Overall, I would gauge the well to be a success. The oil .column was proven in this well, with the trap most likely being the siderite zone above the Moraine sand. It would have been interesting to go on to the Kuparuk sands, even though 3-D seismic data showed that it may be below the oil/water contact. CO Nfl 0 ENT'~L ( RECEIVED J un (}9 1998 Alaska on & Gas Cons. Commission Anchorage .>-"'" '~'. ~ MUD RECORD §p&J~ ARCa ALASKA, INC. KALUBIK #2 \NEI-L LOGGING. INC_ DATE DEPTH MW FV PV YP GELS FL SOL SD pH CI- OIL 211lfØ8 121' 10.1 91 16 24 8/14 12.4 8.0% 0.00% 9.0 350 0/92 .2(8/98 250' 10.0 124 20 20 8/14 13.4 7.0% 0.10% 10.0 600 0/93 ~. ~~~l~~. '250' 10.0 165 24 22 12120 12.8 9.0% 0.75% 9.5 700 0/91 2/9798 1~QÞ{)' 10.2 122 25 18 11/26 12.6 10.0% 0.25% 9.0 750 0/90 219/98 1900' 10.0 84 24 21 10/26 11.6 11.0% 0.50% 8.5 800 0/89 211 0/98 2525' 10.0 62 19 18 7/17 11.8 11.0% 0.25% 8.5 850 0/89 Z/11/98 2523' 8.3 28 1 0 0/0 0.0 0.0% 0.0 0 0/0 ~/11/98 2523' 9.5 43 10 11 5n 16.6 5.0% 0.00% 9.0 450 0/95 , I 'I't ~/12/98 2523' 9.5 43 10 11 5n 16.6 5.0% 9 450 0/95 ~12198 .1 2601' 9.5 43 10 11 4/7 12.4 4.4% TR 9 1450 0/95 2/12198 3914' 9.5 50 15 19 7/11 6.8 6.5% TR 8.9 700 0/93.5 2/12/98 4791' 9.5 51 14 23 8/11 5.6 7.0% TR 9.2 800 0/93 ~13/98 4846' 9.5 60 19 25 11/15 4.8 6.9% TR 9 1100 0/93 2113/98 4950' 9.5 50 11 16 6/10 5.0 6.9% TR 9 1100 0/93 2/14/98 5070' 9.5 50 12 16 6/9 5.2 6.9% 0.10% 10.2 1200 0/93 2114/98 5122' 9.5 50 11 14 6/10 5.2 5.2% 0.10% 10.2 1100 0/94 ----\ /~ ,.-... 'S/tRECORD' . " . . ARCO ALASKA, INC. KALUBIK #2 . . . . . . . - . - . , . . I . _ . . . . . . . . . . . §P(§J~ \N'I:LI,... L.QGQINQ. INC. -- .----.......---...y--'-. ~. ~~.-~~---...- ~-~ ...---~~,..~_..-- ..,~~ ." .._-_.~--._.- - BIT # SIZE MAKE AND SERIAL JETS DEPTH DEPTH FEET' HOURS AVG WOB RPM TORQUE PUMP PRESS TYPE NUMBER IN OUT ROP LOW-HIGH-AVG LOW·HIGH-AVG LOW-HIGH-AVG LOW-HIGH-AVG _. - - - -_.- -- ~ r 1 12.2$" STC MA_1 ~L LM4561 ! 1x10, 2x15_ 111' 2525' 2414' 13.~ 182.9 0-50-13 0-212-190 0-133-100 492-3118-2685 - 2 ,- ~~~'~. HYQA DS70F~NeV 20908 6><11 2525' 4950' 2425' 16.7 145,3 0-17-5 100-278-256 32-98-83 1288--3015-2618 -- - '~---- _~~rQ#t!- 8.5'1 _ HTC ARC41 Z 1$01130 OPEN 495C)' 5122' 172' 7.6 22.6 3.-8~6 28-87 -so 75-100.9!; 267-730-$0 - -. - ---~- RR#2 8.6" HYCA DS7QFGNPV 2000S 6><11 5122' 5650' 528' 5,4 97.4 0-12.3 238-263-257 00-101-00 2479-2927-2765 ..-..., ~. . . . . -." \ GRADE TIB/G 1-1·1 ,--.. ( ( ARCa ALASKA, INC. February 1998 ~~~ (" ~LUBIK #2 SURVEY SUMMARY NORTH SLOPE, AK Data from SPERRY-SUN WELL LOGGING, INC. MEASURED HOLE VERTICAL COURSE COORDINATES DOGLEG DEPTH TVD ANGLE . AZIMUTH SECTION . LENGTH N (+) or S (-) E (+) or W (-l SEVERITY 111 111 0 0 0 0 0 0 0 127.35 127.35 0.24 91.98 0 16.35 0 0.03 1.47 220.15 220.15 0.37 79.75 0.05 92.8 0.05 0.52 0.16 316.73 316.73 0.21 64.97 0.18 96.58 0.18 0.99 0.18 410.86 410.85 0.61 89.21 0.26 94. 12 0.26 1.65 0.45 500.18 500.17 0.7 85.59 0.3 89.32 0.3 2.67 0.11 593.74 593.72 0.92 86.27 0.4 93.55 0.4 3.99 0.24 684.98 684.94 1.18 93.32 0.39 91.22 0.39 5.66 0.32 772.75 772.69 1.22 94.05 0.27 87.75 0.27 7.49 0.05 867.46 867.38 1.51 113.1 -0.29 94.69 -0.29 9.64 0.56 lie 957.08 956.97 1.61 112.18 -1.23 89.59 -1.23 11.9 0.12 ~: ( 1049.08 1048.92 1.92 109.48 -2.23 91.95 -2.23 14.55 0.35 1138.17 1137.96 2.15 113.47 -3.39 89.04 -3.39 17.48 0.3 1233.37 1233. 11 1.35 102.3 -4.34 95.15 -4.34 20.22 0.91 1322.64 1322.36 1.34 101.21 -4.77 89.25 -4.77 22.27 0.03 1416.25 1415.94 1.42 110.76 -5.39 93.58 -5.39 24.43 0.26 1509.93 1509.59 1.49 110.05 -6.22 93.65 -6.22 26.66 0.08 1601.3 1600.93 1.59 114.87 -7.16 91.34 -7.16 28.92 0.18 1690.11 1689.7 1.59 113.43 -8.17 88.77 -8.17 31.17 0.04 1789.31 1788.86 1.71 118.85 -9.43 99.16 -9.43 33.73 0.2 1882.69 1882.2 1.76 118.21 -10.78 93.34 -10.78 36.22 0.06 1976.55 1976.01 1.93 118.06 -12.21 93.81 -12.21 38.88 0.18 2069.55 2068.95 2.12 115.81 -13.69 92.94 -13.69 41.81 0.22 2161.99 2161.35 1.29 117.06 -14.91 92.4 -14.91 44.28 0.9 2254.12 2253.47 0.27 144.11 -15.56 92.12 -15.56 45.33 1.15 2347.52 2346.87 0.32 124.17 -15.88 93.4 -15.88 45.67 0.12 2440.00 2439.35 0.35 157.23 -16.29 92.48 -16.29 46.00 0.21 ( 2529.83 2529.17 0.41 155.12 -16.83 89.82 -16.83 46.24 0.07 2621.86 262142 , 0.45 151461 -17~45 92.03 -17 ~45 46,,55 0,,05 (' ( MEASURED HOLE VERTICAL ' COURSE . COORDINATES DOG LEG DEPTH TVD ANGLE AZIMUTH -, SECTION . LENGTH N (+) or S (-) E (+) or W (-) SEVERITY (' 2715.83 2715.17 0.41 160.09 -18.14 90.92 -18.14 46.85 0.08 { 2806.15 2$09.09 0.42 142.48 -18.75 91.48 -18.75 47.18 0.08 2898.24 2897.57 0.49 133.88 -19..29 90.15 -19.29 47.67 0.16 2988.39 2987.72 0.51 132.62 -19.83 98.51 -19.83 48.24 0.03 I 3086.9 3Q86.23 0.52 139.23 -20.46 92.81 -20.46 48.86 0.06 3179.72 317~04 . 0.59 141.31 -21.18 89.23 -21.18 49.39 0.11 3286.95 3268.27 0.52 155.21 -21 ~ 94 93.56 -21.94 49.81 0.12 3362.52 3361.83 . 0.51 148.81 -22~~8 93.76 -22.68 50.2 0.06 3456.28 3455.59 O~63 146.-84 -23.47 93~69 -23.47 50.7 0.13 3549.98 3549.28 0.6 151.07 -24.33 92.41 -24.33 51.22 0.06 3642.39 3641.69 0.64 155.23 -25.22 91.38 -25.22 51.67 0.07 3733.78 3733.07 0.62 147.96 -2,6.1 94.49 -26.1 52.15 0.09 3828.27 3827.56 0.67 149.84 .;.27.02 94.31 -27.02 52.69 0.06 3922.59 3921.87 0.57 151.03 -27.9 91.64 -27.9 53.2 0.11 4014.23 4013.51 0.63 150.53 -2'8.74 92.94 -28.74 53.67 0.07 ( 4107.18 4106~45 0.58 152.89 -29~6 93~67 -29.6 54.13 0.06 4200.85 4200.12 0.57 148.28 -30.42 90.08 -30.42 54.59 0.05 4290.94 4290.2 0.54 140.96 -31.13 94.7 -31. 13 55.1 0.09 4385.64 4384~9 0.59 147.04 -31.89 18.41 -31.89 55.64 0.08 4404.05 4403.31 0.72 146~54 -32;07 165.7 -32.'07 55.76 0.71 4569.77 4569.01 0.66 151.86 -33.78 95.17 -33.78 56.78 0.05 \ 4664.94 46~4.18 0.65 155.53 -34.75 77.15 -34.75 57.26 0.05 4742.1 4741.33 0.66 169.17 -35,,58 108.24 -35.58 57.53 0.2 4850.35 4849.57 0.88 161.37 ~36.98 99.1 -36.98 57.91 0.22 4949.46 4948.67 0.95 162.03 -38.49 87.67 -38.49 58.41 0,,07 5037.14 5036.34 0.98 1.60..34 ~39...89 89.02 -39.89 5.8.89 0.-05 5126.18 5125.36 1.01 161.15 41.34 93.49 -41.34 '59~4 0.04 5219.68 52-18.85 1.03 159.98 -42.91 92.39 -42.91 59.95 0.03 5312.09 5311.24 1.09 167.32 -44.55 90.08 -44.55 60.43 0.16 \ 5402.18 54-01.32 1..07 166.05 -46.2 97.02 -46.2 60.82 ,0.03 5499.22 5498.34 1.09 170.83 48 83.72 -48 61.18 0.1 ( 5582.95 5582.06 1.11 167. 11 -49.57 67.03 -49.57 61.49 0.09 I, 5650 5649~-o9 - 1~11 167.11 -4-g~'S7 -49.57 61.49 0 '" (" (' ( LITHOLOGIC SUMMARY ARCO Kalubik #2 111' Conglomerate/Sand/Gravel = black to light yellowish gray to light gray to amber to light green; clasts range from medium upper to pebble size grains; subangular to well rounded pebbles; fair sphericity; poorly sorted; loose and disaggregate; grain supported with minor clay installation filling; predominately clay cement; 60% black chert fragments; 30% quartz and light gray chert; 10% jasper, metalithics, limestone, other lithics; fair estimated porosity and permeability; no oil indicators present. 165' Claystone = light grayish brown to medium grayish brown; soft and gummy, occasionally chalky; earthy to matte luster; appears as amorphous lumpy clumps; predominately matrix material for sands and gravels; slightly hydrophilic; readily soluble; fair adhesion and cohesion; non carbonaceous; slightly calcareous. 228' Conglomerate/Gravel/Sand = black to very light gray to translucent white to light yellowish gray to light orange to light green; clasts range from medium upper to well rounded pebble size; subangular to well rounded; fair sphericity; poorly sorted; loose and disaggregate; grain supported with occasional clay installation filling; clay predominately matrix material; 50% black chert; 30% quartz and light gray chert; 20% jasper, limestone, other lithics; fair estimated porosity and permeability; no oil indicators present. ( 298' Claystone = light grayish brown to medium grayish brown; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; slightly hydrophilic; readily soluble; good adhesion and cohesion; slightly carbonaceous; occasional lignite; slightly to moderately calcareous. 350' Claystone = light grayish brown to medium grayish brown to light yellowish gray; soft and gummy, occasionally chalky; appears as amorphous lumpy clumps; earthy to matte luster; slightly hydrophilic; readily soluble; good adhesion and cohesion; slightly to moderately carbonaceous, increasing with depth; slightly to moderately calcareous primarily lime based cement. 397' Sand = black to very light gray to light yellowish gray; clasts range from fine upper to coarse lower, with occasional pebble size grains; subangular to angular; poorly to moderately sorted; fair sphericity; loose and disaggregate; matrix supported; predominately clay installation filling; slightly calcareous cement; 40% black chert; 40% quartz, light gray chert; 20% limestone, jasper, other lithics; poor estimated porosity and permeability; no oil indicators present. 491' Sand/Conglomerate = very light gray to black to light yellowish green to light yellowish brown; clasts range from medium upper to occasional bit broken pebbles; subangular to subrounded; fair sphericity; poorly sorted; loose and disaggregate; grain supported with abundant clay installation filling; clay moderately calcareous; 40% quartz; 40% black chert; 20% limestone, jasper, epidote, other lithics; poor estimated porosity and permeability; no oil indicators present. ( 510' Claystone = light yellowish gray to light grayish brown; soft and gummy, occasionally chalky; appears as amorphous lumpy clumps; earthy to matte luster; { ( (' ( moderately hydrophilic; readily soluble; good cohesion and fair adhesion; occasionally very carbonaceous, grading lignite, with occasional wood fragments; moderately calcareous. 618' Sand/Conglomerate = black to very light gray to light greenish yellow to light yellowish brown; clasts range from medium lower to occasional bit broken pebbles; subangular to subrounded; fair sphericity; poorly sorted; loose and disaggregate; matrix supported with clay installation filling; clay moderately calcareous; 30% quartz; 50% chert (black and light gray); 20% limestone, epidote, jasper, other lithics; poor to fair estimated porosity and permeability; no oil indicators present. 652' Claystone = very light grayish brown to light yellowish gray; soft and gummy, occasionally chalky when dry; appears as amorphous lumpy clumps; earthy to matte luster; moderately hydrophilic; readily soluble; good cohesion and fair adhesion; slightly to moderately carbonaceous; moderately calcareous. 742' Conglomerate/Sand = black to very light gray to translucent white to light yellowish brown to light greenish yellow; clasts range from medium lower to bit broken pebble size; angular to subround; poor to fair sphericity; poorly sorted; loose and disaggregate; grain supported with abundant clay installation filling for matrix; predominately moderately calcareous matrix; 50% black chert; 30% quartz and light gray chert; 20% limestone, epidote, jasper, greenstone, and other lithics; poor estimated porosity and permeability; no oil indicators present. ( 796' Conglomerate/Sand = black to very light gray to white to light green to light yellowish gray; clasts range from medium upper to bit broken pebble size; angular to subangular with occasional rounded chert pebbles; poor to fair sphericity; poorly sorted; loose and disaggregate; grain supported, grading to matrix support with depth; abundant clay installation filling forming matrix; moderately calcareous; 40% black chert; 40% quartz and light gray chert; 20% limestone, greenstone, epidote, jasper, other lithics; poor estimated porosity and permeability; no oil indicators present. 855' Claystone = very light grayish brown to light yellowish gray; soft and gummy, occasionally chalky; earthy to matte luster; moderately hydrophilic; readily soluble; good adhesion and fair cohesion; slightly carbonaceous; non to slightly calcareous. 901' Conglomerate/Sand = black to very light gray to white to light yellowish gray; clasts range from medium upper to bit broken pebble size; angular to subround with occasional rounded pebbles; poor to fair sphericity; poorly sorted; loose and disaggregate; clay installation filling matrix with matrix support; non to slightly calcareous matrix; 30% black chert; 50% quartz and light gray chert; 20% limestone, epidote, jasper, other lithics; poor estimated porosity and permeability; no oil indicators present. 962' Carbonaceous Material/Lignite = black to dusky brown; firm; brittle; earthy to resinous luster; hackly to subplanar fracture; abundant woody texture, grading to wood; trace visible bleeding gas bubbles from fractures. ( 985' Claystone = very light grayish brown to light yellowish gray; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; moderately hydrophilic; readily soluble; good adhesion and fair cohesion; occasionally silty; slightly to moderately carbonaceous, decreasing with depth; non to slightly calcareous. 1094' Conglomerate/Sand = light gray to medium dark gray, light to dark greenish gray to black; clasts range from upper fine to coarse occasionally very coarse and granules, often f (" (' bit impacted; subangular to subrounded; poor to occasionally moderately sorted; very loose; poor to moderate sphericity; both grain and clay support; slightly calcareous; composed mainly of quartz (50 to 60%) and light to medium gray to black chert (30 to 40%) and various metalithics such as limestone, greenstone and epidote (greenish color); occasionally scattered micaceous fragments and pyrite chunks; poor estimated visual porosity and permeability; no oil indicators. , '54' Claystone = light gray to medium light gray to brownish gray; soft to very soft; gummy to sticky; earthy dull luster; hydrophilic, easily soluble; smooth texture; amorphous, clumpy to occasionally structureless; non to slightly calcareous. 1218' Conglomerate/Sand = light to medium gray to medium dark gray, grayish to dusky green; black; clasts range from upper fine to coarse to granules and pebbles; larger clasts are largely bit impacted and broken; unconsolidated and loose; both grain and clay support; composed mainly of quartz (about 70%) and various meta/igneous lithics as chert, greenstone, epidote and rare jasper; occasionally scattered micaceous fragments to muscovite; subangular to subrounded; larger grains generally have better rounding; non to slightly calcareous; poor to fair estimated visual porosity and permeability; no oil indicators in sample. '271' Claystone = light gray to medium brown gray to medium dark gray occasionally with olive hues; soft; very smooth to smooth texture, clumpy to generally structureless, amorphous; dull earthy occasionally matte; moderately hydrophilic; accessories in the form of scattered mica and occasionally pyrite fragments; poor to very poor induration; no oil indicators. ( 1317' Conglomerate/Sand = clear, translucent white, light gray to medium dark gray, dark yellowish green to grayish green to black; clasts range from upper fine to medium to coarser to grained up to granules and pebbles; subangular to subrounded, occasionally rounded; moderately sorted; predominately grain support; clay matrix is present only locally; mostly of quartz (60 to 70%) and light gray to brownish gray chert; other lithics as greenstone and occasionally epidote is common; scattered pyrite chunks; slightly calcareous; occasionally scattered carbonaceous material and lignite; no oil indicators. 1351' Conglomerate/Sand = clear, translucent white to light gray and dark gray to black; considerable amount of light green to dusky green metalithics (greenstone, epidote); moderately sorted; scattered pyrite grains and chunks; occasionally pyrite encrustation on quartz pebbles; scattered carbonaceous material and lignite; poor to moderately estimated visual porosity and permeability, no oil indicators. 1437' Claystone = medium gray to brownish gray to medium dark gray; soft to gummy locally sticky; very poor induration; crumbly tenacity; lumpy habit; amorphous smooth texture, almost structureless; earthy slightly sparkling micaceous luster; non to slightly calcareous; occasionally scattered carbonaceous material and dusky brown woody fragments; hydrophilic. ( 1521' Conglomerate/Sand = white, translucent, light gray to medium· dark gray to bluish gray; clasts range from upper fine to medium coarse occasionally very coarse; subangular to subrounded; larger grains are broken by the bit; slightly to moderately calcareous; loose, poor consolidation; both grain supported and clayey matrix; low to occasionally moderate sphericity; composed mainly of quartz grains (60 to 70 %) and various metamorphic and igneous lithics: 10 to 20% olive gray to olive black to brownish black chert, polished chipped; approximate 10% light greenish greenstone and epidote; occasionally scattered f ( ( jasper tiny grains; also limestone chunks recognizable by greasy luster and bubbly reaction with HCI acid; poor to fair estimated visual porosity and permeability, no oil indicators. 1575' Claystone = very light grayish brown to light yellowish gray; soft and gummy, occasionally chalky; earthy to matte luster; appears as amorphous lumpy clumps; moderately hydrophilic; readily soluble; good adhesion and fair cohesion; non to slightly carbonaceous; rare silty; non calcareous. 1662' Conglomerate/Sand = black to very light gray to light green; clasts range from medium upper to bit broken pebble size; subangular to subrounded; poor to fair sphericity; moderately sorted; loose and disaggregate; matrix supported with abundant clay installation filling; clay is non calcareous; 30% black chert; 50% very light gray quartz and chert; 20% greenstone, epidote, other metalithics; poor estimated porosity and permeability; no oil indicators present. 1723' Sand/Conglomerate = very light gray to black to light green to light yellow; clasts range from medium upper to coarse upper with occasional bit broken pebbles; subangular to subrounded; poor to fair sphericity; moderately sorted; loose and disaggregate; matrix supported with abundant clay installation filling; matrix is non calcareous; 30% black chert; 50% quartz and light gray chert; 20% greenstone, jasper, light yellow chert, other metalithics; poor to fair estimated porosity and permeability; no oil indicators present. ( 1742' Sand = very light gray to black to light green; clasts range from medium lower to coarse upper with occasional bit broken pebble size grains; subangular to subrounded; fair sphericity; moderately sorted; loose and disaggregate; grain supported with minor clay installation filling; non calcareous; 30% black chert and aigrette; 40% quartz and light gray chert; 30% greenstone, feldspar, other metalithics; fair estimated porosity and permeability; no oil indicators present. 1832' Claystone = very light grayish brown to light grayish brown; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; primarily matrix material for sand; moderately hydrophilic; readily soluble; good adhesion and fair cohesion; non carbonaceous; non calcareous. 1887' Sand = very light gray to black to light green; clasts range from medium upper to coarse upper in size; subangular to subrounded; poor to fair sphericity; moderately sorted; disaggregate and loose in sample; grain supported with occasional clay installation filling, decreasing with depth; 30% black chert and aigrette; 50% quartz and light gray chert; 20% greenstone, pyrite, other metalithics; fair to good estimated porosity and permeability; no oil indicators present. 1962' Sand = black to very light gray to light green; clasts range from medium lower to coarse lower with rare bit broken pebble fragments; subangular to subrounded; poor to fair sphericity; moderately sorted; loose and disaggregate; grain supported with rare clay installation filling; 40% aigrette and black chert; 40% quartz and light gray chert; 20% greenstone, pyrite, feldspar, other metalithics; fair to good estimated porosity and permeability; no oil indicators present. ( 2020' Claystone = very light grayish brown to light grayish brown; soft and gummy, occasionally chalky; predominately matrix support for sands; earthy to matte luster; smooth texture; moderately hydrophilic; readily soluble; good adhesion and fair cohesion; non carbonaceous; trace pyrite; non calcareous. (' (" (" 2068' Sand = very light gray to black to white to light greenish gray; clasts range from medium upper to coarse upper in size; subangular to subrounded; poor to fair sphericity; moderately sorted; loose and disaggregate; grain supported with increasing clay installation filling with depth; matrix non calcareous; 40% black chert; 40% Quartz and light gray chert; 20% greenstone, feldspar, pyrite, and other metalithics; poor to fair estimated porosity and permeability; no oil indicators present. 2150' Conglomerate/Limestone Fragments = light yellowish gray to black to brown to light green to white to very light gray; clasts range from coarse upper to bit broken pebble size; angular to subround; poorly sorted; poor sphericity; matrix supported with abundant calcite fracture filling; very calcareous matrix; 30% limestone; 40% black and brown chert; 20% Quartz; 10% greenstone, feldspar, other metalithics; poor estimated porosity and permeability; no oil indicators present. 2221' Claystone = very light grayish brown to light yellowish gray; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; smooth texture; moderately hydrophilic; readily soluble; fair adhesion and good cohesion; slightly carbonaceous; very calcareous. ( 2258' Conglomerate/Sand = black to brown to very light gray to light green to white; clasts range from coarse lower to bit broken pebble size; angular to subround; poor to fair sphericity; poorly sorted; loose and disaggregate; grain supported with abundant clay installation filling; moderately calcareous matrix; 30% black and brown chert; 50% Quartz and light gray chert; 20% greenstone, feldspar, other metalithics; poor estimated porosity and permeability; no oil indicators present. 2331' Claystone = very light grayish brown to light grayish brown; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; smooth texture, rare gritty; moderately hydrophilic; readily soluble; good adhesion and cohesion; non to slightly carbonaceous; slightly to moderately calcareous. 2370' Sand = very light gray to black to light green; clasts range from medium upper to very coarse lower in size; subangular to subrounded; poor sphericity; moderately sorted; loose and disaggregate; matrix supported with abundant clay installation filling; matrix slightly calcareous; 30% black chert and aigrette; 50% Quartz and light gray chert; 20% greenstone, feldspar, other metalithics, pyrite; poor estimated porosity and permeability; no oil indicators present. 2385' Claystone = very light grayish brown to light grayish brown; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; moderately hydrophilic; smooth texture; readily soluble; good adhesion and cohesion; non carbonaceous; slightly calcareous. 2533' Claystone = medium light gray to medium dark gray, occasionally dark gray; soft to moderately firm; very poor to slightly moderate induration; crumbly to slightly brittle; lumpy to mushy; common massive habit w/occasionally wedges; slightly metallic to earthy occasionally slightly sparkly micaceous luster; smooth to slightly gritty texture; rare scattered small pyrite grains. ( 2553' Sand = light gray to dark gray to brownish black; upper fine to upper medium; rounded to subrounded occasionally subangular; moderate sphericity; hard; fair to moderately sorting; low to moderately surface abrasion; moderate to friable consolidation; composed mainly of Quartz (60 to 70%) and various meta/igneous lithics which common (' (' (' has darker coloring; poor to fair visual estimated porosity and permeability; no oil indicators present in sample. 2606' Claystone = very light grayish brown to light grayish brown; soft to slightly firm; appears as amorphous lumpy clumps to subplaty chips; earthy to matte luster; crumbly to subplanar fracture; moderately hydrophilic; readily soluble; fair adhesion and good cohesion; slightly silty, increasing with depth; smooth to gritty texture; moderately carbonaceous; moderately calcareous. 2681' Claystone = very light gray to light grayish brown; soft to slightly firm; appears as amorphous lumpy clumps to subplaty chips; earthy to matte luster; crumbly to subplanar fracture; smooth to increasingly gritty texture; slightly silty; moderately carbonaceous; moderately carbonaceous. 2775' Claystone/Siltstone/Ash Fall Tuff = light grayish brown to medium grayish brown to white; soft to moderately firm (ash fall tuff); appears as amorphous lumpy clumps to subplaty chips; earthy to matte to sparkly luster; subplanar to subblocky fracture; clay and silt slightly hydrophilic, tuff moderately hydrophilic; clay and silt readily soluble, tuff poorly soluble; poor to fair adhesion and cohesion; tuff slightly micaceous (biotite), occasional limestone fragments in matrix; clay and silt moderately carbonaceous with rare lignite; slightly calcareous. ( 2800' Siltstone/Ash Fall Tuff = light grayish brown to medium grayish brown to light whitish gray (tuff); soft to slightly firm (silt) to moderately firm (tuff); subplaty to subfissile; earthy to matte to sparkly (tuff) luster; poorly to slightly hydrophilic; poorly to moderately soluble; gritty (silt) to smooth (tuff) texture; occasional mica flakes in tuff; siltstone moderately carbonaceous; non to slightly calcareous. 2870' Siltstone/Ash Fall Tuff = light grayish brown to medium yellowish gray to whitish gray; soft to moderately firm; subplaty to subfissile; earthy to matte to sparkly luster; subplanar fracture; poorly to slightly hydrophilic; non to readily soluble; gritty to smooth texture; occasional mica flakes in tuff; siltstone moderately carbonaceous, grading lignite; non to slightly calcareous. K-10/ C-80 2932' M.D. -2898' TVD SS 2932' Siltstone/Claystone = light grayish brown to medium yellowish brown; soft gummy to slightly firm (silt); appears as amorphous lumpy clumps to subplaty chips (silt); earthy to matte luster; smooth to gritty texture; slightly to moderately hydrophilic; slightly to readily (clay) soluble; poor (silt) to fair adhesion and cohesion; moderately carbonaceous; slightly calcareous. 2997' Claystone/Carbonaceous Material = light grayish brown to dusky brown; soft and gummy to slightly firm (carbonaceous); appears as amorphous lumpy clumps (clay) to subfissile chips (carbonaceous); earthy to matte to subresinous (carbonaceous) luster; smooth texture (clay) to woody texture (carbonaceous); moderately hydrophilic; readily soluble; trace visible bleeding gas bubbles from carbonaceous fractures; slightly calcareous. ( 3050' Carbonaceous Material = dusky brown to black; slightly firm to firm; subplaty to subfissile; earthy to subresinous luster; hackly to irregular to subplanar fracture; trace woody.texture; abundant claystone interbeds; trace visible bleeding gas bubbles from fractures; non calcareous. ( ( (- 3086' Claystone = light grayish brown to medium grayish brown; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; smooth texture; moderately hydrophilic; readily soluble; moderately carbonaceous, grading lignite; slightly calcareous. 3172' Claystone/Siltstone = light grayish brown to medium grayish brown; soft and gummy to slightly firm; appears as amorphous lumpy clumps to subplaty chips earthy to matte luster; smooth to gritty texture; moderately hydrophilic; readily soluble; fair adhesion and cohesion; slightly carbonaceous, decreasing with depth; slightly calcareous. 3190' Claystone = very light grayish brown to medium grayish brown; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; smooth texture; slightly to moderately hydrophilic; readily soluble; fair adhesion and good cohesion; slightly carbonaceous. K-5 / C-50 3244' M.D. -3210' TVD SS 3272' Carbonaceous Material = dusky brown to black; slightly firm to very firm; earthy to subresinous luster; hackly to irregular fracture; trace woody texture; grading to lignite; abundant claystone interbeds; trace visible bleeding gas bubbles from fractures. 3300' Claystone = light grayish brown to medium grayish brown; soft and gummy to slightly firm; appears as amorphous lumpy clumps; earthy to matte luster; smooth texture; moderately hydrophilic; readily soluble; good adhesion and cohesion; very carbonaceous, grading lignite; slightly to moderately calcareous. ( 3326' Carbonaceous Material/Lignite = dusky brown to black; slightly firm to firm; subplaty to subfissile; earthy to subresinous to subvitreous luster; hackly to irregular fracture; abundant claystone interbeds; predominately plant fragments with rare woody texture; rare visible bleeding gas bubbles from fractures. 3393' Claystone/Siltstone = light grayish brown to medium grayish brown; soft and gummy to slightly firm; earthy to matte luster; smooth to occasionally gritty texture; slightly to moderately hydrophilic; slightly to readily soluble; occasionally carbonaceous, decreasing with depth; slightly calcareous. 3420' Claystone/Siltstone = light grayish brown to dark grayish brown; soft to firm (siltstone); appears as amorphous lumpy clumps to subplaty chips; earthy to matte luster; smooth to gritty texture; subplanar fracture; slightly to moderately hydrophilic; readily soluble; occasionally carbonaceous; silt increasing with depth; slightly to moderately calcareous, increasing with depth. 3469' Carbonaceous Material/Lignite = dusky brown to black; firm to very firm; occasionally brittle; predominately plant material grading to lignite; gritty. occasionally woody texture; abundant siltstone interbeds; rare visible bleeding gas bubbles from fractures. 3500' Siltstone = medium grayish brown to dark grayish brown; slightly to moderately firm; occasionally brittle; subblocky to subplaty; earthy to matte luster; gritty texture; slightly hydrophilic; poor adhesion and cohesion; slightly to moderately carbonaceous, grading lignite; moderately calcareous. ( 3581' Carbonaceous Material/Lignite = dusky brown to dark grayish brown; firm to very firm; occasionally brittle; earthy to matte luster; hackly to irregular fracture; abundant siltstone interbeds; rare visible bleeding gas bubbles from fractures. (" ( (" 3616' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; subblocky to subplaty; earthy to matte luster; gritty texture; slightly hydrophilic; poorly soluble; poor adhesion and cohesion; slightly carbonaceous; moderately calcareous. 3671' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; subblocky to subplaty; earthy to matte lu~ter; trace subplanar fracture; gritty texture; slightly hydrophilic; poorly soluble; poor adhesion and cohesion; slightly carbonaceous; moderately calcareous. 3748' Carbonaceous Material/Lignite = dusky brown to black; firm to very firm, occasionally brittle; occasionally grading to lignite; hackly to irregular fracture; abundant siltstone interbeds; trace woody texture; rare visible bleeding gas bubbles from fractures. 3772' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; subblocky to subplaty, occasional subplanar fracture; earthy to matte luster; gritty texture; slightly hydrophilic; poorly soluble; poor adhesion and cohesion; occasionally very carbonaceous, grading lignite; moderately calcareous. ( 3837' Claystone = light brownish gray to brownish gray to medium dark gray; soft to occasionally slightly firm; non to poorly indurated occasionally poor to moderate induration; crumbly to mushy; smooth to occasionally slightly matte to gritty; lumpy to amorphous generally structureless; massive habit; earthy dull occasionally slightly sparkling luster; scattered carbonaceous specks; only very slight pale sample fluorescence is observed, the only oil indicator. 3856' Siltstone = medium grayish brown to dark grayish brown to dark gray; subblocky to subplaty; elongated to wedgy; slightly firm to firm; dense to brittle occasionally crumbly; slightly hydrophilic; dull earthy to matte luster occasionally slightly sparkling; poorly soluble, poor cohesion and adhesion; occasionally very carbonaceous; common carbonaceous specks throughout sample; occasionally carbonaceous material and woody fragments scattered in sample; occasionally scattered brownish black lignite fragments; no oil indicators present. 3912' Claystone = light brownish gray to brownish dark gray to medium dark gray; soft to occasionally slightly firm; poor induration; almost structureless; massive cuttings habit; mushy occasionally lumpy; hydrophilic; earthy slightly sparkling luster; common scattered carbon specks; continued weak pale sample fluorescence. 3970' Ash Fall Tuff = white to pinkish white; firm to very firm; gritty to rough texture; chalky to slightly waxy luster; slightly calcareous to calcareous; occasional biotite tiny flakes on tuff chunks; appears to be loosely compacted. 4026' Siltstone = very light gray to light gray to medium dark gray occasionally medium brownish gray; very firm to firm; poor to moderate induration; dense to brittle tenacity; subplaty to flaky; subfissile; occasionally conchoidal fractures on edges; gritty texture; occasionally scattered carbonaceous specks; earthy occasionally sparkling luster; rare scattered tiny biotite flakes; no sample fluorescence, very pale yellow very weak cut sample fluorescence, very weak very pale yellow residue cut fluorescence, no visible cut. ( 4086' Claystone = light brownish gray to brownish dark gray to medium dark gray; soft to slightly firm; non to poorly indurated; almost structureless; mushy occasionally lumpy; amorphous; hydrophilic; earthy slightly sparkling luster; slightly calcareous to calcareous; common scattered carbonaceous specks and calcite chunks; slight light yellow spotty (' { ( mineral fluorescence; weak light yellow cut fluorescence; very weak light yellow residue cut fluorescence and ring, no other oil indicators. 4134' Siltstone = light gray to medium dark gray; brittle to dense; firm; platy to scaly; very sandy; occasionally scattered carbonaceous specks; pyrite grains and chunks scattered throughout, also pyrite encrustation on siltstone chunks; minor amount of moderately yellowish brown siltstone; fissile to subfissile; slightly pale spotty sample fluorescence; weak light yellow cut fluorescence; light yellow residual ring, no stain. 4202' Carbonaceous Shale/Mudstone = medium light gray to medium dark gray; firm to occasionally very firm; fissile to subfissile; platy to tabular; common with rounded edges; black carbonaceous material engrained; sandy; scattered carbonaceous specks; planar to subplanar; carbonaceous material often fills the fractures to form planar to slightly rounded stripes; earthy to slightly sparkling micaceous luster; light yellow weak intense residual ring, the only oil indicator. K-3 4260' M.D. -4226' TVD SS 4260' Shale/Mudstone = medium dark gray to occasionally dark gray; firm to hard, knife leaves scratches; earthy to slightly micaceous sparkling luster; planar to subplanar; platy to subplaty; scattered pyrite chunks; scattered prismatic amber to dusky yellow Inoceramus clam mollusks; slight pale yellow spotty sample fluorescence, the only oil indicator. ( 4323' Siltstone = medium light gray to medium dark gray; slightly firm to firm; leaves scratches; platy, elongated; irregular fractures habit; gritty to rough texture; sandy; occasionally scattered carbonaceous specks in sample; occasionally scattered calcite; dense to brittle; rounded edges; occasionally scattered black and brownish black carbonaceous material; common scattered biotite and muscovite tiny flakes; earthy to sparkling micaceous luster; no oil. 4373' Shale = medium gray to slightly greenish gray; firm to very firm; dense to brittle; moderately to well indurated; gritty to matte texture; uneven splintery fractures occasionally slightly conchoidal; earthy to sparkling luster; occasionally scattered carbonaceous specks; scattered amber to dusky yellow prisms of Inoceramus clam mollusk in sample; weak light yellow trace cut fluorescence, light yellow residual ring, no staining in sample. 4440' Carbonaceous Shale = medium gray to dark gray; moderately to well indurated; dense to brittle; planar to subplanar; abundant carbonaceous material ingrained and also in scattered form; earthy to sparkling luster; common scattered carbonaceous specks; common ingrained and scattered flakes of biotite and muscovite; occasionally encrusted brownish orange woody fragments; gritty texture; very pale yellow cut fluorescence with weak intensity and slow speed, the only oil indicator. 4508' Ash Fall Tuff = white to creamy to pinkish white; slightly soft to firm; dense to fine to grained fragmental texture; crumbly; irregular angular chunks; gritty; brittle; silty in part; micaceous luster. ( 4532' Shale = medium dark gray to dark gray; slightly soft to firm; leaves scratches or breaks; fissile planar bedding; irregular fractures; gritty to rough texture; earthy to sparkling micaceous luster; platy to tabular cuttings habit with generally rounded edges; occasionally scattered carbonaceous specks; abundant scattered amber to dusky yellowish Inoceramus mollusk; spotty weak light yellow sample fluorescence; weak pale yellow cut fluorescence; no residual ring. (' ( (" 4601' Siltstone = light gray to medium light gray to occasionally moderate yellowish brown; poor to moderate induration; dense to brittle tenacity; irregular fracture habit; gritty to rough; fissile to subfissile; earthy to micaceous sparkling luster; common scattered carbonaceous specks; occasionally scattered biotite and muscovite tiny flakes; abundant scattered pieces of Inoceramus, usually amber to dusky yellowish to slightly rusty to looking; occasionally scattered carbonaceous specks; very weak to weak pale yellow sample fluorescence. 4651' Shale = medium dark gray to dark gray; slightly firm to firm; moderately to well indurated; gritty to rough texture; platy to tabular occasionally elongated pieces; planar to subplanar; earthy dull to slightly micaceous sparkling luster due to scattered carbonaceous specks; sandy in part; laminated bedding; non to slightly calcareous; occasionally scattered pyrite chunks and grains; common scattered fine pieces of biotite and muscovite; abundant scattered prisms of Inoceramus, amber to dusky yellowish; very weak light yellow sample fluorescence, pale yellow weak intensity slow cut fluorescence, no residual fluorescence and no visible cut is present. 4792' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; subplaty to subfissile; earthy to matte to sparkly luster; slightly hydrophilic; readily soluble; gritty texture; occasional fine crystalline pyrite throughout; slightly to moderately carbonaceous; non to slightly calcareous. ( 4833' Shale = dark grayish brown to medium grayish brown; soft and gummy; appears as amorphous lumpy clumps; earthy to matte luster; moderately hydrophilic; readily soluble; fair adhesion and cohesion; smooth texture; slightly carbonaceous; non to slightly calcareous. Top of Moraine Sand 4920' M.D. -4886' TVD SS 4920' Sand = very light gray to amber to Salt and Pepper; clasts range from very fine upper to fine upper in size; angular; very poor sphericity; moderately sorted; loose and disaggregate; grain supported with trace clay installation filling; 20% Quartz; 70% chert fragments; 10% argillite, greenstone, other metalithics; fair to good estimated porosity and permeability; spotty amber oil stain; faint uncut fluorescence; immediate streaming light yellow green cut fluorescence; faint yellow green residual ring cut. 4951' Sand = clear, white translucent to occasionally amber and dusky yellowish, and light gray; lower fine to occasionally upper fine and medium; moderate to high sphericity; rounded occasionally well rounded; moderately surface abrasion; moderately to well sorted; composed from Quartz and fragments of chert; scattered Inoceramus; oil sheen on mud, 2mm pops, gold yellow to brown yellow moderately to strong uniform fluorescence to 80%, milky yellow to green yellow instant cut fluorescence; bright yellow residue cut fluorescence and ring. 4983' Siltstone = golden brown to medium yellowish brown; soft; gritty; subblocky; earthy; spotty dull yellow fluorescence; moderately streaming faint yellowgreen cut; abundant iridescence from washed sample. ( 5027' Shale/Carbonaceous Shale = medium gray to medium dark gray; firm occasionally slightly soft; brittle; subplanar to slightly conch; subfissile; black carbonaceous material; scattered carbonaceous specks; occasionally biotite; gritty texture; waxy to earthy slightly sparkly luster; slightly calcareous; platy to subplaty occasionally elongate; rare pyrite grains; free oil in mud and iridescent sheen; yellow to brown gold fluorescence; fast green yellow to brownish yellow streaming cut fluorescence. (' f (" 5047' Sand = dark brown to amber; clasts range from very fine fine lower/silt to medium lower in size; angular to subrounded; moderate sorting; loose to friable; grain supported with occasional siderite cement; 30% quartz; 60% chert fragments; 10% other metalithics; fair estimated porosity and permeability; strong petroleum odor from core; saturated brown oil stain; saturated to patchy (in silt) dull yellow fluorescence, immediate bright blue/white to very weak faint dull yellowgreen cut; bright yellow/orange residual ring fluorescence. 5139' Siltstone = medium gray to dark grayish brown; slightly firm to firm; brittle; subplaty to subfissile; earthy to matte to iridescent luster/sheen; gritty texture; slightly hydrophilic; poorly soluble; trace sand interbeds; rare faint dull yellowgreen fluorescence; no cut. 5253' Sand = clear to medium brown; clasts range from fine upper to coarse lower in size; angular to subrounded; moderately sorted; fair sphericity; grain supported with minor clay installation filling; 30% quartz; 60% chert fragments; 10% jasper, argillite, other metalithics; fair to good estimated porosity and permeability; saturated brown oil stain; moderate yellowgreen fluorescence; immediate streaming bright blue/white cut; bright yellow/orange residual fluorescence. 5304' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; subplaty to subblocky; earthy to matte luster; gritty texture; rare sandy interbeds; slightly hydrophilic; poorly soluble; poor adhesion and cohesion; non carbonaceous; non to very slightly calcareous; very faint pale yellowgreen fluorescence; no cut. ( 5326' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; subplaty to subfissile to subblocky; earthy to matte luster; gritty texture with rare sandy interbeds; slightly hydrophilic; poorly soluble; poor adhesion and cohesion; non carbonaceous; non to very lightly calcareous; very faint pale yellowgreen fluorescence; no cut. 5356' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; brittle; subblocky to subplaty to subfissile; earthy to matte luster; gritty texture with rare sandy interbeds; slightly to moderately hydrophilic; poorly soluble; poor adhesion and cohesion; non carbonaceous; non to slightly calcareous; no fluorescence or cut. 5438' Sand = light brown to very light gray; clasts range from fine lower to medium upper in size; angular to subrounded; poor to fair sphericity; moderately sorted; loose and disaggregate to friable in sample; grain supported with occasional siltstone matrix filling; 30% quartz; 60% chert fragments; 10% jasper, argillite, other metalithics; fair estimated porosity and permeability; slight petroleum odor at shaker; patchy to saturated oil stain; patchy pale yellow fluorescence; very slow streaming pale yellow cut; pale yellowgreen residual fluorescence. 5501' Carbonaceous Material = dark brown to dusky brown; firm; brittle; grading to lignite; earthy to subresinous luster; hackly to irregular fracture; flaky texture; subfissile; no fluorescence; very faint dull yellowgreen cut. ( 5542' Siltstone = medium grayish brown to dark grayish brown; slightly firm to firm; subplaty to subfissile; earthy to matte to subresinous luster; gritty to flaky texture; slightly hydrophilic; poorly soluble; occasionally very carbonaceous; non to slightly calcareous. 5625' Sand = white to patchy medium brown; clasts range from very fine upper to medium upper in size; subangular to subrounded; fair sphericity; moderately sorted; loose ( ( ( ( and disaggregate to friable; grain supported with minor silty matrix; 30% quartz; 60% chert fragments; 10% argillite, other metalithics; fair estimated porosity and permeability; patchy brown oil stain; immediate streaming milky yellowgreen cut; dull yellow residual ring fluorescence. Total Depth 5650' M.D. -5650' TVD 55 ( ( EPOCH WELL ( ~i REPORT LOGGING MORNll\t--- 2-8-98 05:00 Depth: 554' ARGO Yesterday: 111' Kalubik #2 24 Hour Progress: 443' BIT INFORMATION: No. Size Type Ser No. 1 12.25" STC MA 1 SL LM4561 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' DRILLING PARAMETERS: Rate of Penetration (ft/hr) 770.1 To~ue 118 Weight on Bit 43 Rotary RPM 194 Pump Pressure 3012 HIGH at at at at at Jets Interval Ftg 2x10,1x15 111'- TVD Depth Incl. 00000.00' 00000' 00000.00' 00000' 119' 442' 211 ' 466 443' LOW at at at at at 28.4 22 o 72 890 DRILLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 ( GAS SUMMARY: Total Ditch Gas (units) Methane (C-1) (ppm) Ethane (C-2) Propane (C-3) Butane (C-4's) Pentane (C-5's) Background Gas: 00000' Connection Gas: 10 units 17.5 3490 0000 000 000 00 HIGH at at at at at at Hours Condition IN HOLE Azimuth TVD 00.0 000.00 00.0 000.00 263' 152' 470' 112' 113' AVERAGE 257.3 min/ft 84 amps 10 Klbs 172 rpm 2329 psi GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 LOW 1.6 at 320 at 000 at 00 at 00 at o at 339' 339' 00000 ' 00000 ' 00000' 00000' Trip Gas: OIL & GAS SHOWS: 00 units @ 00000' Wiper Gas: LITHOLOGY: 50% Sand and Sandstone 00% Chalk 00% Shale 50% Claystone/Mudstone FC 2/32 OIL 0 AVERAGE 4.7 units 944 ppm 000 ppm 000 ppm 000 ppm 00 ppm 437' 437' 00000' 00000' 00000' 00000' o units at o units at 00000' DAILY ACTIVITY SUMMARY: Drill out of conductor pipe at 111'. Drill ahead to 554'. Epoch Personnel on site: 2 SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $000.00 Total Cost: $00000.00 Report By: Paul R. Stiles ARCa Geologist: Bob Davis ARCO Drilling Foreman: Bobbie Morrison ( WELL ( LOGGING MORNIN( REPORT EPOCH 2-9-98 ( ARCO 05:00 Depth: 2247' Yesterday: 554' Kalubik #2 24 Hour Progress: 1693' BIT INFORMATION: No. Size Type Ser No. 1 12.25" STC MA 1 SL LM4561 Hours Condition IN HOLE Jets Interval Ftg 2x10, 1 x15 111'- SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' Azimuth TVD 00.0 000.00 TVD Depth Incl. 00000.00' 00000' 00.0 000.00 00000.00' 00000' DRilLING PARAMETERS: HIGH Rate of Penetration (ft/hr) 1 201. at Torque 133 at Weight on Bit 50 at Rotary RPM 21 2 at Pump Pressure 311 8 at A VERAG E 293.8 min/ft 11 5 amps 14 Klbs 1 91 rpm 2762 psi LOW at at at at at 1218' 1293' 21 00' 1293' 511 ' 31.9 o o o 492 1 830' 1 830' 1 71 A' 1965' 812' DRilLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 FC 2/32 OIL 0 AVERAGE 10.6 units 2126 ppm 000 ppm 000 ppm 000 ppm 00 ppm GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 LOW 1.4 at 270 at 000 at 00 at 00 at o at ( GAS SUMMARY: HIGH Total Ditch Gas (units) 47.4 at 971 ' Methane (C-1) (ppm) 9480 at 971 ' Ethane (C-2) 0000 at 00000 · Propane (C-3) 000 at 00000 · Butane (C-4's) 000 at 00000 · Pentane (C-5's) 00 at 00000 · Background Gas: 12 units 00000' Connection Gas: 00 units @ 00000 ' Oil & GAS SHOWS: 2081 ' 2081 ' 00000' 00000' 00000' 00000' Trip Gas: o units at Wiper Gas: 53 units at 1783' LITHOLOGY: 80% Sand and Sandstone 00% Chalk 00 % Shale 20% Claystone/Mudstone DAilY ACTIVITY SUMMARY: Drill ahead to 1783'. Make 10 stand wiper trip. Drill ahead to 2247'. SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $11325.00 Report By: Paul R. Stiles ARCO Geologist: Renee Hannon ARC 0 Drilling Foreman: Bobbie Morrison Epoch Personnel on site: 4 ( EPOCH WELL (" LOGGING MORNIN( REPORT 2-10-98 ( ARCO Kalubik #2 05:00 Depth: 2525' Yesterday: 2247' 24 Hour Progress: 278' BIT INFORMATION: No. Size Type Ser No. 1 12.25" STC MA 1 SL LM4561 Jets Interval Ftg Hours Condition 2x10, 1 x15 111 '-2525' 2414' 13.26 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00 ' 00000' 00.0 000.00 00000.00 ' TVD Depth Incl. 00000.00' 00000' 00000.00' 00000' DRILLING PARAMETERS: HIGH Rate of Penetration (ft/hr) 506.4 at Torque 127 at Weight on Bit 32 at Rotary RPM 210 at Pump Pressure 291 5 at 2215' 2298' 2238' 2412' 2503' DRILLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 ( GAS SUMMARY: HIGH Total Ditch Gas (units) 14.3 at 2211 ' Methane (C-1) (ppm) 2860 at 2211 ' Ethane (C-2) 0000 at 00000 ' Propane (C-3) 000 at 00000 ' Butane (C-4's) 000 at 00000 ' Pentane (C-5' s) 00 at 00000 ' Background Gas: 4 units 00000' Connection Gas: 00 units @ 00000 ' OIL & GAS SHOWS: LITHOLOGY: 50% Sand and Sandstone 00 % Chalk 00% Shale 50% Claystone/Mudstone 6.0 o o 143 2424 LOW at at at at at Azimuth TVD 00.0 000.00 00.0 000.00 2266' 21 89' 2220' 2189' 21 04' GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 LOW at at at at at at AVERAGE 175.5 min/ft 1 09 amps 12 Klbs 1 99 rpm 2690 psi FC 2/32 OIL 0 A VERAG E 4.9 units 977 ppm 000 ppm 000 ppm 000 ppm 00 ppm o units at 1.2 240 000 00 00 o Trip Gas: Wiper Gas: 2461 ' 2461 ' 00000' 00000 ' 00000' 00000 ' 5 units at 2525' DAILY ACTIVITY SUMMARY: Drill ahead to 2525'. Make wiper trip in preparation for casing run. Run 9 5/8" casing @ 2525'. Cement casing. Epoch Personnel on site: 4 SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $13590.00 Report By: Paul R. Stiles ARCO Geologist: Renee Hannon ARCO Drilling Foreman: Bobbie Morrison ( EPOCH WELL ( LOGGING MORNIN( REPORT 2-11-98 (- ARGO 05:00 Depth: 2525' Yesterday: 2525' BIT INFORMATION: No. Size Type Ser No. 2 8.5" HYCA DS70FGV Jets 6x11 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' Kalubik #2 Interval Ftg 2525'- TVD Depth Incl. 00000.00' 00000' 00000.00' 00000' DRILLING PARAMETERS: HIGH Rate of Penetration (ft/hr) 506.4 at Torque 127 at Weight on Bit 32 at Rotary RPM 210 at Pump Pressure 2915 at 2215' 2298' 2238' 2412' 2503' ( DRILLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 GAS SUMMARY: HIGH Total Ditch Gas (units) 14.3 at 2211 ' Methane (C-1) (ppm) 2860 at 2211' Ethane (C-2) 0000 at 00000 ' Propane (C-3) 000 at 00000 ' Butane (C-4's) 000 at 00000 ' Pentane (C-5's) 00 at 00000 ' Background Gas: 4 units 00000' Connection Gas: 00 units @ 00000 ' OIL & GAS SHOWS: LITHOLOGY: 50% Sand and Sandstone 00% Chalk 00% Shale 50% Claystone/Mudstone 6.0 o o 143 2424 LOW at at at at at 24 Hour Progress: 0' Hours Condition IN HOLE Azimuth TVD 00.0 000.00 00.0 000.00 2266' 2189' 2220' 21 89' 21 04' AVERAGE 175.5 min/ft 109 amps 1 2 Klbs 1 99 rpm 2690 psi GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 LOW 1.2 at 240 at 000 at 00 at 00 at o at Trip Gas: Wiper Gas: FC 2/32 OIL 0 AVERAGE 4.9 units 977 ppm 000 ppm 000 ppm 000 ppm 00 ppm 2461 ' 2461 ' 00000 ' 00000 ' 00000 ' 00000' o units at 5 units at 2525' DAILY ACTIVITY SUMMARY: Nipple down and nipple up BOP's. Pick up new BHA. ( Epoch Personnel on site: 4 SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $15855.00 Report By: Paul R. Stiles ARCO Geologist: Renee Hannon ARCO Drilling Foreman: Bobbie Morrison EPOCH WELL ( LOGGING MORNIN( REPORT 2-12-98 C" ARGO Kalubik #2 05:00 Depth: 3152' Yesterday: 2525' BIT INFORMATION: No. Size Type Ser No. 2 8.5" HYCA DS70FGV 20908 Jets 6x11 Interval Ftg 2525' - SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00 ' TVD Depth Incl. 00000.00' 00000' 00000.00' 00000' DRilLING PARAMETERS: HIGH Rate of Penetration (ft/hr) 652.4 at Torque 95 at Weight on Bit 1 7 at Rotary RPM 266 at Pump Pressure 2558 at 31.0 43 o 190 574 lOW at at at at at 2659' 2551 ' 2668' 2898' 2894' ( DRilLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 24 Hour Progress: 627' Hours Condition IN HOLE Azimuth TVD 00.0 000.00 00.0 000.00 2526' 2534' 2593' 2534' 2594' A VERAG E 147.9 min/ft 86 amps 6 Klbs 244 rpm 2127 psi GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 lOW at at at at at at GAS SUMMARY: HIGH Total Ditch Gas (units) 14.8 at 2771 ' Methane (C-1) (ppm) 2888 at 2771 ' Ethane (C-2) 55 at 291 7' Propane (C-3) 000 at 00000' Butane (C-4's) 000 at 00000 ' Pentane (C-5's) 00 at 00000 ' Background Gas: 12 units 00000 ' Connection Gas: 00 units @ 00000 ' Oil & GAS SHOWS: 1.4 280 o 00 00 o Trip Gas: Wiper Gas: LITHOLOGY: 10% Sand and Sandstone 00% Chalk 00% Shale 90% Claystone/Mudstone FC 2/32 Oil 0 AVERAGE 4.8 units 931 ppm 13 ppm 000 ppm 000 ppm 00 ppm 2708' 2708' 2920' 00000' 00000 ' 00000' o units at o units at 0000' DAilY ACTIVITY SUMMARY: Drill out cement in casing. Test casing. Drill out shoe. Run FIT. Drill ahead to 3152'. ( Epoch Personnel on site: 4 SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $18120.00 Report By: Paul R. Stiles ARCO Geologist: Renee Hannon ARCa Drilling Foreman: Bobbie Morrison EPOCH WELL ( LOGGING MORNIN{ 2-13-98 ( ARCO Kalubik #2 05:00 Depth: 4791' Yesterday: 3152' BIT INFORMATION: No. Size Type Ser No. 2 8.5" HYCA DS70FGV 20908 Jets 6xll Interval Ftg 2525' - SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00 ' 00000' 00.0 000.00 00000.00' TVD Depth Incl. 00000.00' 00000' 00000.00' 00000' REPORT 24 Hour Progress: 1639' Hours Condition IN HOLE Azimuth TVD 00.0 000.00 00.0 000.00 DRilLING PARAMETERS: HIGH LOW Rate of Penetration (ft/hr) 705.6 at 4111' 17.1 at 4172' Torque 96 at 3063 ' 14 at 4388' Weight on Bit 11 at 4728' 0 at 4389' Rotary RPM 278 at 3422' 197 at 4388' Pump Pressure 3015 at 4682' 1288 at 3148' DRilLING MUD REPORT: Report Depth: 000' ( MW 0.0 VIS 00 PV 00 YP 0 GELS 0/0 FL 0.0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 Pf/Mf 0.0/0.0 CI- 0000 GAS SUMMARY: Total Ditch Gas (units) Methane (C-l) (ppm) Ethane (C-2) Propane (C-3) Butane (C-4's) Pentane (C-5's) Background Gas: 00000' Connection Gas: Oil & GAS SHOWS: LITHOLOGY: HIGH LOW 262.6 at 4173' 1.6 at 34663 at 4173' 273 at 2914 at 4173' 0 at 2449 at 4173' 0 at 1801 at 4173' 0 at 1362 at 4173' 0 at 18 units Trip Gas: 00 units @ 00000' Wiper Gas: 3739' 3739' 3266' 4540' 3410' 4757' o AVERAGE 207.7 min/ft 81 amps 4 Klbs 259 rpm 2721 psi FC 2/32 OIL 0 AVERAGE 29.0 units 4760 ppm 251 ppm 1 41 ppm 102 ppm 44 ppm o units at units at 0000' 3750'-T.D.pale weak yellow flor, weak slow cut, no residual ring cut. 10% Sand and Sandstone 00% Chalk 90% Shale/Siltstone 00% Claystone/Mudstone DAilY ACTIVITY SUMMARY: Drill ahead to 4791'. Trip to change BHA. Lay down mudmotors and pick up new BHA. Trip in hole. ( SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $20385.00 Epoch Personnel on site: 4 Report By: Paul R. Stiles ARCO Geologist: Renee Hannon ARCO Drilling Foreman: Bobbie Morrison EPOCH WELL ( LOGGING MORNINf .( ARGO 2-14-98 Kalubik #2 05:00 Depth: 5028' Yesterday: 4791' BIT INFORMATION: No. Size Type Ser No. 2 8.5" HYCA DS70FGV 20908 Corel 8.5" HTC ARC412 1901130 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' DRilliNG PARAMETERS: Rate of Penetration (ft/hr) 91 .5 Torque 94 Weight on Bit 8 Rotary RPM 78 Pump Pressure 669 HIGH at at at at at REPORT 24 Hour Progress: 237' Jets 6xll Interval Ftg Hours Condition 2525'-4950' 2425' 16.69 4950' - TVD Depth Incl. 00000.00' 00000' 00000.00' 00000' 4954' 5005' 5028' 5031 ' 4994' 9.0 81 7 66 641 LOW at at at at at ( DRilLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 GAS SUMMARY: Total Ditch Gas (units) Methane (C-l) (ppm) Ethane (C- 2) Propane (C-3) Butane (C-4's) Pentane (C-5's) Background Gas: Connection Gas: HIGH 11 5.9 at 16756 at 1289 at 1 011 at 526 at 385 at 4989' 4989' 4989' 4989' 4989' 4989' LOW at at at at at at 1.8 308 20 3 4 2 10 units 116 units @ 4989' Trip Gas: Wiper Gas: Azimuth TVD 00.0 000.00 00.0 000.00 5028' 4997' 4954' 4989' 5005' 4962' 4962 ' 4962' 4962' 4962' 4962' o AVERAGE 32.6 min/ft 89 amps 7 Klbs 77 rpm 655 psi FC 2/32 OIL 0 AVERAGE 13.2 units 2009 ppm 139 ppm 86 ppm 62 ppm 31 ppm 118 units at 4950' units at 0000' Oil & GAS SHOWS: 4950'-T.D.pale dull yellow flor, immed strmg milky yellow cut, mod yel resid ring cut, decreasing w/depth @ 5020' LITHOLOGY: 80 % Sand and Sandstone 00% Chalk 20% Shale/Siltstone 00% Claystone/Mudstone DAilY ACTIVITY SUMMARY: Drill ahead to 4936'. Circulate bottoms up. Drill ahead to 4950'. Trip out of hole to core. Pick up core barrel. Trip in hole. Core to 5032'. Barrel jammed. Trip out with core #1 . ( SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $22650.00 Epoch Personnel on site: 4 Report By: Paul R. Stiles ARCO Geologist: Paul Decker ARCO Drilling Foreman: Bobbie Morrison EPOCH WELL ( LOGGING MORNINf 2-15-98 ( ARCO Kalubik #2 REPORT 05:00 Depth: 5224' Yesterday: 5028' 24 Hour Progress: 196' BIT INFORMATION: No. Size Type Ser No. Core1 8.5" HTC ARC412 1901130 RR#2 8.5" HYCA DS70FGV 20908 Jets Interval Ftg Hours Condition 4950'-5122' 172' 7.61 5122'- IN HOLE 6x11 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' TVD Depth Incl. 00000.00 I 00000' Azimuth TVD 00.0 000.00 00000.00' 00000' 00.0 000.00 DRilLING PARAMETERS: HIGH LOW Rate of Penetration (ft/hr) 46.5 at 5061 ' 2.2 at 5033' Torque 103 at 5117' 75 at 5041 ' Weight on Bit 5 at 5121' 3 at 5061 ' Rotary RPM 87 at 5045' 28 at 5033 ' Pump Pressure 730 at 5116' 267 at 5033' ( DRilLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 GELS 0/0 FL 0.0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 Pf/Mf 0.0/0.0 CI- 0000 AVERAGE 24.3 min/ft 99 amps 4 Klbs 83 rpm 676 psi FC 2/32 OIL 0 GAS SUMMARY: HIGH LOW A VERAG E Total Ditch Gas (units) 31.8 at 5055' 8.2 at 5120' 15.9 units Methane (C-1) (ppm) 4797 at 5055' 11 43 at 5120' 2353 ppm Ethane (C-2) 337 at 5055' 80 at 5034' 177 ppm Propane (C-3) 207 at 5055' 46 at 5043' 115 ppm Butane (C-4's) 174 at 5055' 0 at 5088' 87 ppm Pentane (C-5's) 108 at 5072' 0 at 5120' 34 ppm Background Gas: 10 units Trip Gas: 23 units at 5122' Connection Gas: 0 units @ 0000' Wiper Gas: 0 units at 0000' Oil & GAS SHOWS: 50320'-T.D.pale dull yellow flor, immed strmg milky yellow cut, mod yel resid ring cut liTHOLOGY: 80% Sand and Sandstone 00% Chalk 20% Shale/Siltstone 00% Claystone/Mudstone DAilY ACTIVITY SUMMARY:Lay down core. Recovered 77.25' of 82' total. Trip in hole. Core to 5122'. Trip with Core #2. Lay down core. Recovered 65.25' of 90' total. Trip in hole. Drill ahead to 5224'. ( SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $24915.00 Epoch Personnel on site: 4 Report By: Paul R. Stiles ARCO Geologist: Paul Decker ARCO Drilling Foreman: Bobbie Morrison EPOCH (' ARGO WELL ( LOGGING MORNIN(( 2-16-98 Kalubik #2 REPORT 05:00 Depth: 5650' Yesterday: 5224' 24 Hour Progress: 426' BIT INFORMATION: No. Size Type Ser No. RR#2 8.5" HYCA DS70FGV 20908 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00 ' 00000' 00.0 000.00 00000.00' Jets 6x11 Interval Ftg Hours Condition 5122'-5650' 528' 5.42 1-1-1 TVD Depth Inct. 00000.00' 00000' Azimuth TVD 00.0 000.00 00000.00' 00000' 00.0 000.00 DRILLING PARAMETERS: Rate of Penetration (ft/hr) 294.1 Torque 101 Weight on Bit 1 2 Rotary RPM 263 Pump Pressure 2927 HIGH at at at at at LOW at at at at at 5285' 5229' 5611 ' 5608' 5232' 27.2 69 o 238 2479 5153' 5318' 5535' 5630' 5123' DRILLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 GAS SUMMARY: Total Ditch Gas (units) Methane (C-1) (ppm) Ethane (C-2) Propane (C-3) Butane (C-4's) Pentane (C-5's) Background Gas: 22 Connection Gas: 0 ( GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 AVERAGE 118.6 min/ft 90 amps 3 Klbs 257 rpm 2765 psi FC 2/32 OIL 0 HIGH LOW A VERAG E 145.6 at 5256' 4.6 at 5156' 23.8 units 21200 at 5256' 725 at 5126' 3859 ppm 1988 at 5256' 31 at 51 58' 248 ppm 1108 at 5256' 20 at 5156' 123 ppm 626 at 5256' 13 at 5158' 81 ppm 385 at 5256' 0 at 5506' 28 ppm units Trip Gas: 0 units at 0000' units @ 0000' Wiper Gas: 0 units at 0000' OIL & GAS SHOWS: 5640'-T.D.pale dull yellow flor, immed strmg milky yellow cut, mod yel resid ring cut LITHOLOGY: 30% Sand and Sandstone 00% Chalk 70% Shale/Siltstone 00% Claystone/Mudstone DAilY ACTIVITY SUMMARY: Drill ahead to 5650'. Circulate and build MW to 9.8. Trip out of hole for electic logs. Run electirc logs. ( Epoch Personnel on site: 4 SERVICES PROVIDED: RIGWA TCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $27180.00 Report By: Paul R. Stiles ARCO Geologist: Paul Decker ARCO Drilling Foreman: Bobbie Morrison WELL ( LOGGING MORNINf 2-17-98 EPOCH ( ARGO 05:00 Depth: 5650' Yesterday: 5650' BIT INFORMATION: No. Size Type Ser No. RR#2 8.5" HYCA DS70FGV 20908 Jets 6x11 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' Kalubik #2 REPORT 24 Hour Progress: A' Interval Ftg Hours Condition 5122'-5650' 528' 5.42 1-1-1 TVD Depth Incl. 00000.00' 00000' Azimuth TVD 00.0 000.00 00000.00' 00000' 00.0 000.00 DRilLING PARAMETERS: HIGH Rate of Penetration (ft/hr) 294.1 at 5285' Torque 101 at 5229' Weight on Bit 12 at 5611 ' Rotary RPM 263 at 5608' Pump Pressure 2927 at 5232' DRilLING MUD REPORT: Report Depth: 000' ( MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 GAS SUMMARY: HIGH Total Ditch Gas (units) 145.6 at 5256' Methane (C-1) (ppm) 21200 at 5256' Ethane (C-2) 1988 at 5256' Propane (C-3) 1108 at 5256' Butane (C-4's) 626 at 5256' Pentane (C-5's) 385 at 5256' Background Gas: 22 units Connection Gas: 0 units @ 0000' Oil & GAS SHOWS: LITHOLOGY: 00 % Sand and Sandstone 00% Chalk 00% Shale/Siltstone 00% Claystone/Mudstone 27.2 69 o 238 2479 lOW at at at at at 5153' 5318' 5535' 5630' 5123' A VERAG E 118.6 min/ft 90 amps 3 Klbs 257 rpm 2765 psi FC 2/32 Oil 0 lOW AVERAGE 4.6 at 5156' 23.8 units 725 at 5126' 3859 ppm 31 at 5158' 248 ppm 20 at 5156' 123 ppm 13 at 5158' 81 ppm 0 at 5506' 28 ppm Trip Gas: 0 units at 0000' Wiper Gas: 0 units at 0000' DAilY ACTIVITY SUMMARY: Run electirc logs. Trip in hole to condition for casing run. Cut and slip drilling line. GELS % Fl 0.0 Pf/Mf 0.0/0.0 CI- 0000 ( Epoch Personnel on site: 4 SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLaGGING SYSTEM Daily Cost: $2265.00 Total Cost: $29445.00 Report By: Paul R. Stiles ARCa Geologist: Paul Decker ARCa Drilling Foreman: Bobbie Morrison WELL ( LOGGING MORNINf 2-18-98 EPOCH ( ARCO 05:00 Depth: 5650' Yesterday: 5650' BIT INFORMATION: No. Size Type Ser No. RR#2 8.5" HYCA DS70FGV 20908 Jets 6x11 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' Kalubik #2 REPORT 24 Hour Progress: 0' Interval Ftg Hours Condition 5122'-5650' 528' 5.42 1 - 1-1 TVD Depth Incl. 00000.00' 00000' Azimuth TVD 00.0 000.00 00000.00' 00000' DRILLING PARAMETERS: HIGH Rate of Penetration (ft/hr) 294.1 at 5285' Torque 101 at 5229' Weight on Bit 12 at 561 1 ' Rotary RPM 263 at 5608' Pump Pressure 2927 at 5232' DRILLING MUD REPORT: Report Depth: 000' MW 0.0 VIS 00 PV 00 YP 0 ( pH 00.0 SOL 00.0% Sand 00 Pm 00.0 GAS SUMMARY: HIGH Total Ditch Gas (units) 145.6 at 5256' Methane (C-1) (ppm) 21200 at 5256' Ethane (C-2) 1988 at 5256' Propane (C-3) 1108 at 5256' Butane (C-4's) 626 at 5256' Pentane (C-5' s) 385 at 5256' Background Gas: 22 units Connection Gas: 0 units @ 0000' OIL & GAS SHOWS: LITHOLOGY: 00 % Sand and Sandstone 00% Chalk 00% Shale/Siltstone 00% Claystone/Mudstone 00.0 000.00 27.2 69 o 238 2479 LOW at at at at at 5153' 5318' 5535' 5630' 51 23' AVERAGE 118.6 min/ft 90 amps 3 Klbs 257 rpm 2765 psi FC 2/32 OIL 0 LOW AVERAGE 4.6 at 51 56' 23.8 units 725 at 51 26' 3859 ppm 31 at 5158' 248 ppm 20 at 5156' 123 ppm 13 at 5158' 81 ppm 0 at 5506' 28 ppm Trip Gas: 165 units at 5650' Wiper Gas: 30 units at 5650' DAILY ACTIVITY SUMMARY: Circulate and conditon hole for production casing run. Run casing. Circulate through casing. Cement casing. GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 ( Epoch Personnel on site: 4 SERVICES PROVIDED: RIGWA TCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $31710.00 Report By: Paul R. Stiles ARCO Geologist: Paul Decker ARCO Drilling Foreman: Bobbie Morrison WELL ( LOGGING MORNINf 2-19-98 EPOCH (' ARCO 05:00 Depth: 5650' Yesterday: 5650' BIT INFORMATION: No. Size Type Ser No. RR#2 8.5" HYCA DS70FGV 20908 Jets 6x11 SURVEYS: Depth Incl. Azimuth 00000' 0.00 000.00 00000.00' 00000' 00.0 000.00 00000.00' Kalubik #2 REPORT 24 Hour Progress: 0' Interval Ftg Hours Condition 5122'-5650' 528' 5.42 1-1-1 TV D Depth Incl. 00000.00' 00000' 00000.00' 00000' DRilLING PARAMETERS: HIGH Rate of Penetration (ft/hr) 294.1 at 5285' Torque 101 at 5229' Weight on Bit 12 at 5611 ' Rotary RPM 263 at 5608' Pump Pressure 2927 at 5232' DRilLING MUD REPORT: Report Depth: 000' ( MW 0.0 VIS 00 PV 00 YP 0 pH 00.0 SOL 00.0% Sand 00 Pm 00.0 GAS SUMMARY: HIGH Total Ditch Gas (units) 145.6 at 5256' Methane (C-1) (ppm) 21200 at 5256' Ethane (C-2) 1988 at 5256' Propane (C-3) 1108 at 5256' Butane (C-4' s) 626 at 5256' Pentane (C-5's) 385 at 5256' Background Gas: 22 units Connection Gas: 0 units @ 0000' OIL & GAS SHOWS: LITHOLOGY: 00% Sand and Sandstone 00% Chalk 00 % Shale/Siltstone 00% Claystone/Mudstone 27.2 69 o 238 2479 LOW at at at at at Azimuth TVD 00.0 000.00 00.0 000.00 5153' 5318' 5535' 5630' 5123' GELS % FL 0.0 Pf/Mf 0.0/0.0 CI- 0000 Report By: Paul R. Stiles ARCO Drilling Foreman: Ray Springer A VERAG E 118.6 min/ft 90 amps 3 Klbs 257 rpm 2765 psi FC 2/32 Oil 0 LOW AVERAGE 4.6 at 5156' 23.8 units 725 at 5126' 3859 ppm 31 at 5158' 248 ppm 20 at 5156' 123 ppm 13 at 5158' 81 ppm 0 at 5506' 28 ppm Trip Gas: 165 units at 5650' Wiper Gas: 30 units at 5650' DAILY ACTIVITY SUMMARY: Change out rams. Run tubing in hole. Epoch Personnel on site: 4 SERVICES PROVIDED: RIGWATCH/RIGTRAK MUDLOGGING SYSTEM Daily Cost: $2265.00 Total Cost: $33975.00 ( ARCO Geologist: Paul Decker (" I( , "DlLAB JrlU CORE LABORATORIES OR\G\NAL Core Lab New Orleans File No.: 57161-12404 September 16, 1998 Core Laboratories, Inc. 929 Howard Avenue New Orleans, Louisiana 70113 (504) 581~5222 (504) 586-9476 Fax Tho analytical rÐsulls, opinions or Intorprolotlon3 conlnlnmJ In this roport 01'0 l)[1sod upon In[ornli1l1oll und molorlal ¡_~uppliod by 1110 cllont lor whoso oxcluslvo and conlldontlnl Ul~O IIll:~ roport 1101:; boon rnnc10. TI10 QIKllyllcnl rURulls, opinion::: 01' Inlorproln lIon:-:; Gxpro,ssÐd I'oflrosont tho bast judnmonl of Cora Lflboro1orlos. Cora LorJOrulorlos, 110WOVor, rnal<OB no wmrnn!y or roprosontntloll, oxprÐGS or Impllod, of OIlY lype, Ullcl ()xpI'08~~ly íllf,ckJlrœ ~mno as to 1110 pmclllctlvlly, propm opornllorm or pro!ltublol'lü:ìs 01 tiny 011, gus, coal or othor minami, proporty, wall or sand In connoctlon with Wlllcll such rÐporll:i lJsod or rolled upon for any WC.won wlmtsoDvor. ThIL~ roporl Gllall not bD roprodllGod, In WllOlo or In port, wltllOtlllllO wrltlon npprovnl 01 Corn LnboriJlorlos. (' (~ ApPENDIX C Project Protocol (as provided by Areo Alaska, Ine.) C1 ( March 5, 1998 CORING OPERATIONS jÕcX)w.,d Core point will be picked in the Moraine Interval using the LWD resistivity log. Low- invasiorr coring procedures when convenient will be used for the core taken from this well. Low- invasion can be achieved in most sands so long as coring rate exceeds 30 to 60 feetJhr:- Higher rotary speed 80 to 100 rpm, and higher bit weights, 8000 to 12000 Ibs will produce coring rates which easily reach 120 feetJhr in good quality sandstone. Rotary speed and bit weight needed will depend on rock properties with lower rotary speed and higher bit weight in poorer quality rock. A RC 412N FD Is the recommended bit for this well. It should core at 60 to 120 feetJhr in sand and has given low invasion relia~up to 5000 md. Aluminum barrels are-recommended because of the greater mechanicat- stfenQUt:-\'The spacing between the catcher shoe and core bit should be 0.125 inches at bottom-hole circulating conditions. A larger spacing is set on the surface to compensate for differential expansion between the steel outer barrel and the aluminum inner barrel. Material and Site Preparation in Heated Work Space Upon amval at the rig site, the required core handling_ equipment will be set up in an indoor work space by the Core Lab and Drilling personnel, preferably in the pipe sheet Inner barrel marking and cutting equipment will be set up and tested. This core handling must take place in a heated space. The core will start to free~e after 30 minutes exposure to sub.freezing temperature. Do not oennit the core to f,t.ß¿ð. Upon completion of the above preparations, the core boxes should be put together and marked with client name, well name, core number, and box number. Inner Barrel Laydown, Cutting, Capping. Transportation at the Rig Site The aluminum inner barrel will be laid down in the core barrel shack and transported to the catwalk with a crane or cat line. Wipe down the outer surface of the inner barrel to remove mud. Locate the top of the core and mark inner barrel. Double stripe red and black, red on right looking up-hole. Mark depths each foot on outer barrel starting from core top and cut inner balTel into 3..foot lengths using the pipe cutter or chop saw and barrel support/clamp. Geoscience will chip off a piece of core for description at the 3' intelVals. Cap one end of the barrel. Place rubber caps on the upper end of core with stainless steel hose damps to hold caps in place. If core sticks out too far for the cap, then use a triple thickness of polyethylene core tubing and clamp with a steel hose clamp. I Load 3' sections of inner barrel into core boxes and transport inside a heated vehicle to Kuparuk for transportation to Anchorage. This should be as soon as possible after coring to obtain the most reliable routine and special Core plug. Total elaDsed time between cuttino the core and Dreservina it in Anchoraae should not exceed 48 hours. DO NOT ALLOW CORE TO FREEZE DURING TRANSPORTATION FROM THE; WELLSITE TO ANCHORAGE. CORE PROCESSING IN ANCHORAGE General Core Handling: 1. Core sampling will be conduded as soon as possible after cutting the core. Sample the core immediately upon arrival at the service laboratory regardless of the time of day. The service company personnel will be notified when the core is on the way and will pick up the core shipment at the airport once the freight company releases it. The service company should be notified that they may receive up to two 90..foot cores in a single 24-hour period. 2. Exposure to air should be minimized to avoid evaporation of fluids and wettability .changes. 1 March 5, 1998 3. All routine plug drilling will be done using lsopar L to remove cuttings. Routine core plugs will be cut and analyzed every one-foot over the entire length of core. 4. Sawing will be done with a dry saw for small samples such as plugs or when cutting out full diameter core sedions. Slabbing of the core for geology can be conduded with cooled nitrogen gas to cool the saw blade. Surface Core Gamma Log in Anchorage The core is laid out on tables in depth order while still inside the aluminum tubes. The core remains preserved whife-·it is QII.fiIM Io(¡,~.:' The core gamma unit is calibrated with a 200 API gamma ray emitter before every core. The core is placed on a conveyor belt (beginning with the bottom of the core) which moves the core at a constant speed under the gamma detedor. The pieces are butted tight to one another, with no breaks in measurements, until the core is completely logged. Now the recorded gamma ray response is digitized and plotted~ Core Lay.Qut, Marking and Sawing in Anchorage Processing should begin immediately upon arrival in Anchorage so the core can be rapidly sampled and analysis can be expedited. Place core inner barrel sections in depth order convenient to the layout bench. The core should be laid out on the counter in 5- or 10-foot lengths bya Service Company Lab representative. Dump core out of inner barrel sections onto lay-out bench. Core pieces are wiped with dry rags to remove mud.. fatted. together, oriented. with the apparent up dip. at the top, depth marked and double sb ipoo for ortentatlon. Depths shall be marked below the corresponding foot line· and orientation lines marked with white on the right and yellow on the left using waterproof markers. It is recommended that lumber crayons be used for marking core surface and Marks-A-lot markers (red and black, red on right) for foil wrapped core. Mark the locations for the routine core plugs. A 3 inch long routine sample will be marked and sawed to separate it from the core having its top at the foot mark each foot. If vertical plugs are cut these will be obtained from the 3 inch sample located at the foot mark. The slabbing of the core can precede the separation of the routine samples from the core using the saw. In this way the slab will be more continuous and higher quality. Core Slabbing in Anchorage Core slabbing will be conducted as soon as the Gamma Ray is completed. Do not open the inner barrel until you are ready for core layout, marking and slabbing. Since this core is only preserved in capped aluminum barrels, core processing must not be delayed when the core arrives in Anchorage. Water can move out of the core as a vapor during daily cycles ·of heating and cooling in the laboratory. The core pieces will be fit together so that the same side of the core is always presented in the slab. The core will be slabbed 1/4-3/4 so that the bedding and dip angle. are clearly observable. The 3/4 slab should retain the white and yellow stripe and depth markings made previously (not a wellsite). Rotate the core 90° from these markings and cut the slab. Slabbing should be conducted using cooted nitrogen to cool the saw blade. Double stripe the 1-inch slab for orientation. If scribe lines are present, do not use them as cutting guides; try to preserve them on the 3/4-slab as they will be used to calculated paleocurrent directions. The 3/4 butt end of the core will be immediately preserved in order to minimize exposure. The 1/4 slab should be placed in a slab box with styrofoam inserts to prevent breakage and in depth sequence. After photographing the 1/4 slab (white light and ultraviolet), the 1/4 slab should be repackaged and sent back to ARCO's Bayview Warehouse in Anchorage for detailed description work at the following address: Bayview Warehouse Building Attn: Dan Przywojski 619 East Ship Creek Ave. Anchorage, AK 99501 2 March 5, 1998 Core Preservation in Anchorage The 3/4 core butt is placed with the top to the left on the bench. This will help insure that the proper core orientation is maintained. When moved to the wrapping stations this orientation is maintained. The wrapping stations must be covered with Oilsorbent tissue to provide a soft surface which will not damage Saran and foil. Wrapping should begin as soon as possible after the core has been slabbed. All of the 3/4 core butt is wrapped with Saran wrap (6 layers), then wrapped with aluminum foil (3 layers) and marked. Wrapped core will be marked with depth using white stick-on labels and a black Marks-A-Lot and with red and black (red on right) orientation lines. The routine samples (3" pieces) should be preserved separately from the other. core samples in a given foot in Saran and aluminum foil depth marked and stripped for orientation. These can then be used for cutting plugs as time and manpower pennit. If the plugs will not be cut from a routine core sample until the next day, then it should be coated with CoreSeal to prevent evaporation over night. Next, the 3/4 core butt should be coated with CoreSeal. Coreseal coating should be complete on all samples in 3 to 4 hours except for samples awaiting core plugs. No samples should remain without CoreSeal protection longer than 8 hours. Glass strapping tape is placed on the foil under the wire to prevent puncture of the foil. Bailing wire is wrapped tightly around the center of the core to facilitate the dipping of the samples in Core Seal. Monitor CoreSeal temperature in melting pot. Temperature should not exceed 330°F. If discolored by being too hot then replace the CoreSeal. The core should be completely submerged in the dip tank for 1-2 seconds and then hung on the cooling rack. After the Core Seal has cooled (3-5 minutes), the sample should be redipped to insure a proper seal and to help proted the core from damage during shipment. After the second dip, the wire is cut at a point just above the preserved piece and a small amount of Core Seal should be placed over the exposed wire to eliminate a wicking effect. Once all the 3/4 core butt has been preserved and placed in the open core boxes, it should be checked for proper preservation and markings. Occasionally the CoreSeal will be too thick to read the markings. Therefore, if possible, a waterproof marker should be used to mark the appropriate designations on the outside of the sample. Cutting and Trimming Core Plugs in Anchorage· The routine core plugs will be cut from the 3/4 slab at 1-foot intervals over the entire length of core. Routine core plugs should be cut at approximately the same place at each foot, moving only when an obvious fracture or core rubble is observed. Cut the 1.0-inch diameter horizontal plugs parallel to bedding plane using Isopar L. The plug will be cut from the butt portion starting at this saw-cut face. The diagram below illustrates the slab and horizontal plug locations. 3 ¡( March 5, 1998 ROUTINE CORE SAMPLE ~ 4" ... stABBED FAC ~ "f 3" "' II'" ,~ 1.0" X 1.5" PWG " ~ / The plug should be cUt completely through the center of the core and as close to the depth mark as possible. Take care to be sure the plugging bit is perpendicular to the slab face, otherwise the plug may need to be trimmed. Dab core plug, if necessary, with an Oilsorbent tissue to remove excess oil immediately after plugging. Trim one end of the core plug with a dry saw so that the final plug is 1.5 inches long. If the plugging bit was not perpendicular to the slab face, first trim the slab side of the plug 1/8 inch (the width of the saw blade) and then trim off the end piece so that the resulting plug is 1.5 inches long. Identity plug number on the core plug and end piece. Preserve plug in Saran wrap (6 layers) and aluminum foil (3 layers). Relabel with plug number on the foil. Place wrapped plug in pre-weighed bottle, seal, tape and weigh. Label the bottles with well name, depth, plug number, tare and total weight. Routine Core Plug Ends: Plug end-pieces will be batch cleaned with toulene for 4 days. The end-pieces will be dried over night in a convection oven. Place end-piece in a zip-lock bag and mark depth and plug number on the package. Indicate en-piece with' EP following plug number. Please ship by overnight mail to the address listed below: Steve C. Johnson ARCO Oil & Gas Company (PEC-4) 1600 Summit Avenue Piano, TX 75074 (972) 50~;.4482 Please call Ken Helmold at (907) 265-1491 before shipping plug ends so he can coordinate with the Piano Lab. The figure on the next page shows the plug and trimmed end. 4 ( March 5,1998 SC SAMPLE -< 27/S" >- 1.25" 1.5" ROUTINE t END 1.0" PI ECE CORE PLUG f II. Vertical Core Plugs: . The routine vertical core plugs will be cut once every foot. These will be 1 inch diameter by 1.5 inches long cut perpendicular to bedding from the same 3/4 butt section of core used to obtain the horizontal core plug. The location of this core plug in the sample is not critical since mud filtrate invasion will not be measured. This plug can go directly to extraction. Use toluene and batch extract these plugs. Continue extraction until these plugs do not fluoresce when trichloromethylene is placed on the plug. The plugs can then be dried and brushed in the same manner as the horizontal plugs and penneabilities are then measured. PDPK Mini Penneability to Air in Anchorage The % slab will be measured using the PDPK minipermeameter in Anchorage. The core will be measured at 5 points per foot down the center of the core. Core breaks and surface imperfections will be avoided. Core Photography in Anchorage I The core will be photographed in white and UV light, with 15 feet per frame. The % slab will be used for the photography, so plug holes will be visible. The Iso par will affect the fluorescent for each plug remnant. Four sets of photographs will be required. ROUTINE CORE ANALYSIS IN THE BAKERSFIELD LABORATORY All horizontal and vertical core plugs will be shipped preserved to Bakersfield for routine core analysis. Dean Stark Analysis The Dean Stark method is used to determine water saturation. The flasks and glassware must be cleaned from the previous use to ensure there is no residual water. Rinse condenser, core chamber and flask with fresh toluene and discard the rinse. Weigh a clean, dry Dean Stark flask. Add toluene 120:1:1 cc and pre-boil. Check sidearm for water and transfer pure toluene in side arm to flask. Dry side ann. To keep toluene loss to a minimum, keep the system closed except when adding or removing sample. 5 ( March 5, 1998 The core plug is removed from its preservation materials. The core plug is weighed to an accuracy of ±O.001 g. placed in a pre-dried and pre-labeled thimble to trap lost grains and reweighed to the same precision. If core plugs are soft or poorty consolidated in some intervals. then encase them in Teflon tape. aluminum or lead foil and screens prior to the last weight. Obtain individual weights on Teflon, foil, and screens. The plug is then loaded into the Dean Stark apparatus without further delay. Then, seal the apparatus. Perform all tasks for one plug at a time. Toluene is refluxed until no further change in the water volume in the receiver is observed for four hours. Take readings at 8. 12. and 24 hours. Continue with daily readings if necessary. Soap dispersed in toluene may be used to wash water from the condenser. Record the volume of the water to within ±O.025cc (1.2% PV @ 10% porosity). If water volume is less than 0.5 cc. pull water from receiver with a syringe and weigh it. Extrad with toluene for at least 2 days in the Dean Stark. Extraction and Drying Change to chloroform (use a second Dean Stark device if that is more convenient). Change chloroform after the first forty-eight hours; then, change it every twenty-four hours. Continue extradion until clean chloroform shows no crude oil color after eight hours. A clean core plug should not fluoresce when trichloromethane is dropped on it under ultraviolet light. Extradion time should be a minimum of two days and may require as long as a week. Do not use batch cleaning techniques in this step. Dry core plug. and thimble in a convedion oven at 180 F for 4· hours. Then. dry the core plug. bag and thimble in a vacuum oven for 24 hours at 180 ~F and then to constant weigh %0.02 grams. after four hours additional drying. Cool the plug and thimble over desiccant. Weigh the plug and thimble within ±O.001 g. Remove plug from thimble. Brush plug to remove fines and weigh again. Porosity Porosity is calculated from the difference in bulk volume and grain volume divided by the bulk volume. The pore volume is the difference between bulk volume and grain volume. That is the value used to calculate saturations. Grain Volume The helium porosimeter will be used to determine the grain volume of all samples. Plugs from drying are kept over desiccant until ready for grain volume measurement. If the plugs are exposed to laboratory air for more than 30 minutes, they should be redried and reweighed. The helium porosimeter should be recalibrated to :to. 1 % twice a day. The porosimeter should be checked with a steel cylinder with a known volume to %0.1 % after every five samples and after a break in instrument usage of greater than one hour. If drift between successive calibrations will .cause grain density to vary :to.OOS glee, calibrate before every plug. Bulk Volume Bulk volume for all plugs will be measured using mercury immersion. Bulk volume will be measured within %0.01 cc (±O.05% BV). Maximum depth of immersion in mercury will. be the minimum required to yield an accurate bulk volume. The plug must be weighed within ±O.001 g before and after the mercury immersion to check for mercury intrusion. Any weight gain greater than 0.04 g (0.0030 cc out of 42 cc . approximate bulk volume) will be significant intrusion. Bulk volume will be increased to correct for the calculated mercury intrusion. Penneability to Air Permeability to air is measured on all routine horizontal and vertical core plugs. The fine materials generated while sawing should be cleaned from the plug faces before this measurement is made. Brush the plug faces and blow clean with dry compressed air before measuring permeability. - 6 March 5, 1998 Penneability is measured with 400 psi net overburden pressure. Complete recaUbration of penneameter will be performed every two wells. Check plugs of known penneability will be used to check calibration daiJy. Permeability should be measured with a stable air flow rate. Routine horizontal core plugs will be used in this measurement only after the completion of bulk volume. 7 ( 'II' (' March 5, 1998 CORE TRANSPORT Core Transport From Exploration Drilling Rigs Transport of boxed core samples from the Alpine and Kalubik drill rigs to the Materials Warehouse for shipping will be coordinated through the Kuparuk Drilling Tool House and the Kuparuk Materials Warehouse The Kuparuk Drilling Tool House will arrange transportation of the cores in a heated van from the Alpine and Kalubik drill rigs to the KRU Materials Warehouse where they will be weighed and readied for shipment to Anchorage and then transport the core samples to the Deadhorse airport. The following procedure should be adhered to: 1.The well site geologist should notify the Kuparuk Drilling Tool House two days in advance of anticipated coring. A second call should instrud the Kuparuk Drilling Tool House as to date and pick-up time of the cores at the drilling rig. Terry BeanlLewie Allmon 659-7367) 2. An FR (materials transport requisition) filled out on location by the drilling superyisor should read : Ship to: Core Laboratòries 600 West 58th Ave. Unit D Anchorage, Alaska Hold for pick up by Core Lab. (Scott Kehlar) NOA (907) 349-3541 Do Not Freeze The word Priority should be printed boldly on the FR. The FR will accompany the shipment. 3. Core Lab will supply wooden boxes that hold two three-foot pieces of core. These boxes will weigh appx. 130 LB when full. 4. Dave Childress/Pete Richards (659-7459) at the KRU materials warehouse should be notified a day in advance of the shipment. They should be notified again on date and pick-up time of the core and on the departure of the core shipment to KRU materials. 5 Materials will infonn Scott Kehlarwl Corelab (work 349-3541) as to the flight number, ETA, and airway bill number. Note: Do not allow the core to freeze during transportation from the well site to final destination. _ Destination address must be written on each Core Box shipped. Sample shipments in cardboard boxes will be handled in a similar manner. 8 { ~:' March 5, 1998 Kalubik #3 CORING OBJECTIVES Analysis by Core Lab will indude a gamma-ray scan over the entire core, slabbing and photographing in white and ultraviolet light, and analysis of core plugs (1 horizontal plugJfoot and 1 vertical plugJfoot). The core will provide core gamma-ray log, in-situ water saturation, porosity, grain density, horizontal penneability, vertical penneability, and lithology. Micropenneameter measurements (every 0.2 feet) will be collected on the 1/4 slab. Part of the core will be preserved for future engineering studies. Below are general guidelines. The on-site geologist or Renee Hannon may modify these procedures at any time. GENERAL GUIDELINES The wellsite operations will be minimized and conduded quickly so the core can be transported to Core lab in Anchorage and then on to Core lab in Bakersfield, Texas for all other operations. A summary of operations is listed below: At The Ria Site A. Use low invasion core bits, 60-foot aluminum inner barrel, 4-inch core diameter, bland water base mud. B. Lay down, depth mark, double stripe, cut, and cap inner barrel in 3-foot lengths. Place in core crates, two or three 3-foot lengths to the crate so two men can lift them. C. Minimize rig site operations and transport the core immediately to Anchorage for immediate processing. Durina transDortation. the core must not be allowed to freeze. Notify personnel to be at-the airport in Anchorage for pick-up. . In Anchoraae A. Core Lab should meet the core at the airport and begin core processing. B. Layout aluminum core barrels and run suñace gamma ray log while the core is still preserved in inner barrel. C. Remove core from inner barrel sedions, layout, and depth mark core. D. Slab the core 1/4 - 3/4. Mount the 1/4 slab in slab boxes for photographing and viewing. Run the Micropenneameter measurements (every 0.2 feet) on the 1/4 slab. E. The 3/4 slab needs to be processed and preserved immediately after slabbing each 3' sedion so that special core analyses are not compromised. E. Cut the 3/4 slab into three 1 foot pieces. The top 3" of each 1 foot piece should be cut off of the slab for routine core analysis and the required samples for the State of Alaska. F. The remaining 9" of each 1 foot piece should be immediately preserved for future SCAl work. Preservation should be done within 48 hours of when the core reached the suñace at the 'well site. G. Cut and trim the plugs for routine cor.é analysis. Routine core samples are to be sent to Bakersfield for analyses. I. After photographing the 1/4 slab, repackage it and send it to Anchorage Bayview for detailed description work. 1 Author: coreanch@alaska.net Date: 4/23/98 3:37 PM Priority: Normal TO: Howard Okland at DOA-AOGCC Subject: Kalubik #2 Update 10tt Kehler) at CC2MHS1 ) cantwel@ix.netcom.com wrote: > > Scott, > > Attached is the same document in txt, rtf, and Word 6 for ms-dos. Let me know if there are further problems. > > Regards, > Wes > > --------------------------------------------------------------- > > > > Alaska Oil & Gas Conservation Commission > 3001 Porcupine Drive > Anchorage, Alaska 99501 April 23, 1998 > > Attention: Mr. Howard O~kland Re: Arco Routine Core Analysis Status > Kalubik No. 2 & 3 Wells > Core Lab File No.: 57161-12404 > > Dear Mr. O~kland; > > On March 6, 1998 Core Lab's New Orleans facility received 126 (101 horizontal 'and 25 vertical) plugs from cores taken in the above referenced wells. Routine core analysis (Dean Stark Saturation, grain density, and CMS-300 permeability an d porosity me asurements) commenced immediately, and progressed as per the procedures outlined in the protocol provided by Arco Exploration. > > Each plug has taken approximately two+ weeks to clean ique. We are currently running two banks of eight Dean , one bank with toluene and the other with chloroform. 'menced once a sufficient number of samples had been ave been completed on approximately 22 he report for which is in preparation. e initial via the Dean Stark techn Stark distillation units CMS-300 measurements com thoroughly cleaned. These measurements h horizontal plugs and 25 vertical plugs, t The release of preliminary data for thes > > Should you have any questions about the project progression or forthcoming res ults, please do not hesitate to contact me at the 504-581-5222 or via email (can twel@ix.netcom.com) . > > Sincerely, > CORE LABORATORIES, INC. > > Wesley Cantwell > Laboratory Supervisor > Reservoir Geologist > --------------------------------------------------------------- > > > > Part 1.3 Name: progress1.doc Type: zz-application/zz-winassoc-doc ) ) DARCO Exploration Company <> D ARCO Oil and Gas Company <> ŒJ ARCO Alaska, Inc. Record O~ Shipment Of Confidential Information Air. 'V District: Alaska To: From: AK Oil And Gas Conservation Commission ARCO Alaska, Inc. Attn.: Lori Taylor Attn.: Joy Burk ATO-1455 3001 Porcupine Drive Post Office Box 100360 Anchoraç¡e, AK 99501 Anchoraç¡e, Alaska 99510-0360 (X) Enclosed q~ - Dd-O ( )Under separate cover ( )Via KALUBIK #2 / (1) MWD SURVEY/FINAL Y'^~ \)~. t5 ~ ~ -6~ 9~ / DISC - AS PREPARED BY SPERRY-SUN /(1) LDWG FORMATTED W/VERIFICATION LISTINGS " DISC - AS PREPARED BY SPERRY-SUN (2) RATE OF PENETRATIONlDGRlEWR4 1 ~ 0,,"- BLUE LINE/& SEPIÁ - AS PREPARED BY SPERRY SUN (2) DGRlELECTROMAGNETIC WAVE RESISTIVITY ,., ;' BLUE LINE & SEPIA - AS PREPARED BY SPERRY SUN )~~ Note - Please verify and acknowledqe receipt, by siqninq and returninq a copy of this transmittal. Signed by Date 4/9/98 Date ReceìV~o-ô-- 0 "" . . ç JIS"\ Remarks: Please ~ ~1-in~IUded information is CONFIDENTIAL. Page 1 ) ) DARCO Exploration Company <> o ARCO Oil and Gas Company <> ŒJ ARCa Alaska, Inc. Record Of Shipment Of Confidential Information A V District: Alaska To: AK Oil And Gas Conservation Comm ission Attn.: Lori Taylor 3001 Porcupine Drive AnchoraQe, AK 99501 From: ARCO Alaska, Inc. Attn.: Joy Burk ATO-1455 Post Office Box 100360 AnchoraQe, Alaska 9~51 0-0360 (X) Enclosed ( )Under separate cover ( )Via Kalubik 2 '1~-O~O /(1) Formation (Mud) LOQ - Blue Line - Prepared by EPOCH 11) Formation (Mud) LOQ - Sepia - Prepared by EPOCH Kalubik 3 erZ . coS- /(1) Formation (Mud) LOQ - Blue Line - Prepared by EPOCH / (1) Formation (Mud) LOQ - Sepia - Prepared by EPOCH ~ Note - Please verify and acknowledqe receipt, by siqninq and returning a copy of this transmittal. Signed by Date 4/6/98 Recewed btX~ ~ Dale'i(7 frg Remarks: Please Note that all included information is CONFIDENTIAL. Page 1 '-1 ) ') D ARCa Exploration Company ¢ D ARca ail and Gas Company ¢ ŒJ ARCa Alaska, Inc. Record Of Shipment Of Confidential Information A V District: Alaska To: AK Oil And Gas Conservation Commission Attn.: Lori Taylor 3Q01 Porc9pine Drive AnchoraQe, AK 99501 From: ARCO Alaska, Inc. Attn.: Joy Burk ATO-1455 Post Office Box 100360 AnchoraQe, Alaska 99510-0360 (X) Enclosed S't . O?D { )Under separate cover ( )Via Kalubik 2 (' (1) Dipole Shear Sonic Imager Upper Dipole/P&S Modes Blue Line - Schlumberqer / (1) Dipole Shear Sonic ImaQer Upper Dipole/P&S Modes Sepia - SchlumberQer /' (1) Dipole Shear Sonic ImaQer Upper Dipole/P&S Modes (Quality LOQ) Blue Line - SchlumberQer ./ (1) Dipole Shear Sonic ImaQer Upper Dipole/P&S Modes (Quality LOQ) Sepia - SchlumberQer (" (1) Combinable MaQnetic Resonance ImaQer Raw Data/Quality Control Blue Line - SchlumberQer r (1) Combinable MaQnetic Resonance ImaQer Raw Data/Quality Control Sepia - Schlumberger Note - Please verify and acknowledqe receipt, by si~ninq and returninq a copy of this transmittal. Signed by Date 4/2198 Received by d~~ Date Remarks: Please Note that all included information is CONFIDENTIAL. \..' Page 1 ') ) WELL SUMMARY q ß-O';}O Well Name: ARCO Kalubik #2 API #: 50-1 03-20252-00 Rig: Doyon 141 Elevation: G.L. = 4.7' K.B. =34' Total Depth: 5650' MD (-5616' 55) driller Completion Status: Plugged & Abandoned Geological Tops: MD SSTVD C-80/K-1 0 2942' 29081 C-40/K-5 3163' 31291 C-35/K-3 4155' 41211 K-2 5130' 5096' Total Depth 5650' 56161 Conventional Cores: Aluminum barrel 4" inner diameter Core #1 - Cut 49501-50321 Recovered 49501-5027.251 (821/77.251) Core #2 - Cut 5032'-5122' Recovered 5032'-5098.25' (90'/66.25') Sidewall Cores: none . ....,.J' \ ~ ~ , "''"'1:'" r..q 10 " ,.., " ' II r~c. '1 .____."._.""'_______,~'...._,__.____,.__~."H,."__~"...H__~._,_.,~"_,_ .__.___..._.._._,'_____,_.__..'n.~""..."..""._~~._.___""'____._'~HH .._._."_,."_,._"",__"~"_,...,.__.",.",".__,___.,,._~_......____"'.'H·_ ./., -'--"-""--'--~-~-~-~-"-""-"'--~"'---"'-"''''-'-'- SENT BY: 3- 5-98 ; 12 : 55PM . AReO Alaska, Inc. ') . Post Office Box 10036( Anchorage, Alaska 995'1..., 360 Telephone 907 276 1215 ARCO ALA~I(A~ ) 907 276 7542;# 2/ 4 ,~~ '~~' £ liÞ Cb flJG V"M March 5, 1998 David W. Johnston~ Chairmali Ala~ka on and Gas· Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ("Z, 1J- / )-0 qt:¿/ Rc: Weekly Operations Report ARCO Kalubik #2 Pernlit No. 98-20 ARCO Kalubik #3 Permil No. 98-05 Dear COIDlnÌssÌOl1er Johnston, Auached is the weekly operations sUffilnary for the ARCa Kalubik #2 and Kalubik #3 wells being drilled in the Colville River delta area with the Doyon 141 rig. Operations remained shut down on Kalubik #2 pending the results of the Kulubik #3 well. Ka1ubjk #3 has been drilled to 7000' TO and logged. Kalubik #3 is presently being plugged and abandoned. Plans are being m,ade plug and abandon Kalubik #2. 1 r you have questions or require additional information, please conta.ct Fred Johnson at 265-1492. Sincerely, .~.j JI~ Fred Johnson Drilling Engin.eer ", "'r"~, ~II.:.I ~,~~'. :Iii¡~~: r: U', ',285'., ~ :~:, ~:t~~f,r(C' ~~';H :~ :~~;Q~ ...1,,: ~ .,,1. ~.Ji' "T¡~[n~~~':'~' ~~' .'~r'~~i""~"rt' SENT BY: Date: 3/2/98 3- 5-98 ;12:55PM ) ARCO ALA~I{A~ ) 907 276 7542;# 3/ 4 Mca ALASKA INC. WF.1.,T.. SUMMARY REPORT pt.{ge: "). ~=========~~~==========~~~~==========~~~~============~~~~~~~============~~-~==~= WELL: KAL'UBIK #.3 WELL_ID: AX9 B 2 6 'rYPR: ST.i\TE:ALASKA AREA/Cr,n'y; NORTH SLOPE WEST FIELD: UNLIS'1'ED Sl'UD:02f?O/9B START COMP: RIG:bOYON RIG 141 WI: 0% SECUHITY:O AVI NUMBER: 50-103-20251-00 ==========~...~-;._----------~~=============~~~~~~~============~--~~==:============ BLOCK: !:,'l.l\IAL: 02/20/9H (Dl) TD : 3 0 6' ( .3 06 ) I:mpV~ RWS 02/21/98 (D2) TD: 19:32' (16'-6) StTPV~RW~ 02/22/98 (DJ) 1fT) :' 2955' (1023 ) SUPV:RW8 02 / 23 / 9 8 ( D4 ) TD : 3 050' ( 95 ) SUPV~RWS 021 ;>, 11./ 9 8 ( D5 ) TD: 3 O!) 0' ( 0 ) SUPV:}{WS 02/2519 B (1)6 ) TD:30é~'( 11) SUPV:RWS MW: 10.0 VIse: 137 PV!YP: 14/36 APIWT, ~ 10 _ A DRILLING 12.25" @ 752' Rig accepted 0900 hrs. 2/20/98. Function test diverter system, Pre job safety meeting. DriU out: conductor pipe from 54'-·148'. Drill f.rom 14B'-306'. Trouble shoot MWD problem - failed - lay down ~::H.uu~. MW: lO.O VISC: '78 PV!YP: 12/15 R1H W/NEW BIT & MOTOR @ 2028' Rotary and slide drilled f.r.om :~06' -1932' . APIWL: 8.0 MW: 10.0 VISC; 105 PV/YP: 1.5/"8 APJ:WL: 7.2 RUN CASING & CEMENT Drilled from 1932'-2028'. 700 psi pressure loss, check su.r(ace equipment, OK. Washout in bit and mot.or. Wash and roam 30' to bottom. Drill from 2028' to ?-581.'. Pump preSSUI'è dr:op (rom 7.500 to 2000 psi. Check surface equipment for leaks. Inspected MWD, motor, bi.t, jars, no wasnouts. H1H to jars. Kelly up, check for leaks @ jars, none. Drilled from 2561' to ?563'. MW: 10.0 vrsç; 55 PV/Y~: 13/24 FINISHINC CEMENT CLEANUP Pre job safety meeting. Drill.ed from 25B]' hi-vi~ sweep. Circulate hole clean. Rig up PJSM. RUIl 9-5/8" cü~in9' APIWL: 6.8 to 3050'. Pump to run casing. MW: 10.0 VISC: 55 PV!YP: 13//.~ APIWL: 6.8 FTNTSHI~G (:BM.h:N'l' CLEANUP Pre job safety meeting. D:r·illed II'om 2583'-3050'. Pump hi vis sweep. Ci,rc hole clean. Circ and condition. Pre job safety meeting. Run 9 .5/811 Cë:1sing. MW: 9.S VISC: 46 PV!YP: 12/14 APlwt: 11.6 DRILLING 8.5» @ 3260' I)r~-job safety meeting. Test casing to 2000* for 10 m,Í,n @ stage tool. D:r'ill stage L:.ool pl'Jgs. Millon float ~quipment and push to baffle plate. Mill aluminum baffle @ 2913'. ~! :~::-' ~:\j {.,: ;\~l~D I"", "':~{Y,j .1·~ .' ' ,IV "J\t¡~J {~~;fJt.r~f2 '~~~}~ & .I::;a~f wC ~..; ,'~. CI(~rq!n~t.~¡:·· I ,1"; ¡!1"r:¡t"":";::1(\i..1 ,.:i1~.~,?~? :~)j1 ~~ '~(j~ ~¡;;ì;. \,f(\mmi$¡=:'~ ' j t~c~:~~i'~1'r" ,~ ~ 1\ L') "', ',:. ..:! i;;-t; ,~ \11 HI, (, \1 ~....;¡~~:~ . t1'~ :~:~f" ~i ~~?".,',.!. b:Ild of WellSumma:r.y for: Well :l\X9826 POI·} TO LOG Pre-job safety meeting_ Hearn fr,om 6310'-6331'. Core from Ed31'-hlr=:;7.'. POOH. n~am and lory from 6292'-6362' _ Drill~d wI motor from 6367./-67901. APIWL~ 3.8 MW: 10.5 VT.SC: 50 PV!YP: 20/24 MW: 10.0 VISC; 116 PV/YJ:1: 16/20 .hPIWL: 4.4 CORING @ 6361' Pre-j ob safety maeti.ng. Cont.inue drilling from S3 84' -6331' _ Inc:t:ease mud weight to 10.0 ppg. P/U coring aHA and RIH. MW: 9.5 VISC: 45 PV/YP: 15/19 APIWL: 4.2 ROTAkY VRILLING pre-·job safety meeting. LWD log from 4580' to 4624'. Rotary drilled from 1624' 5384'. Perform t.o 4624'. MW: 9.5 VISC: 45 pv/yp; 1.5/14 DRII.LT.NG 'ro CORE POINT Pre job safety meet:lng. Dx:ll1 fr.'om 3062'-30'/0'. Leak off test to 1'7 _ 0 ppg EMW. Dr; 11 fn10\ .3070' Conduct saf.ety SLand down. APIWL: 9.2 Drilled cement from 2913 '·-2953'. Drilled float collar and cement to 2974'. t~st casing to 2000~, QK. Drilled cement and ShOè from 2974'-3046'. Drilled new formatj.on from 3050'-3062/. Page: .2 ARca ALASKA INC. WELL SUMMARY REPORT ARCO ALA~)A~ ) 907 276 7542;# 4/ 4 3- 5-98 ;12:56PM 03/01/9R (-D1.0) TD~ 6790' ( 459) SUPV:RWS 02/28/9A (U9) TD: 6331' ( 941) SUPV.RWS 02/2'1/98. (DB) 'I'D: 5384' ( 760) SUPV.RWS 02/2 6/9 8 ( D7 ) TD: 4624 I (1562) SUPV:RWS Da t c: 3 12 / 9 8 SENT BY: ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair we" _ Plugging _ Time extension Stimulate Change approved program Pull tubing _ Variance përforate Other 2. Name of Operator 5. 'I ype of Well: I 6. Uatum elevation (UI- or KIj) Development _ I ARCO Alaska, Inc. Exploratory ~ 32' RKB' above Sealevel feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Kuukpik Unit 4. Location of well at surface 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E, UM At top of productive interval 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E, UM At effective depth At tota I depth 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E, UM 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 83' 2485' 5605' measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Wellbore schematic 8. Well number Kalubik #2 9. Permit number 98-0020 10. API number 50-103-20252 11. Field/Pool Exploration 5650 feet Plugs (measured) None 5650 feet 4940 feet Junk (measured) 4940 feet Size Cemented Measured depth True vertical depth 16" Driven 111' 111' 9-5/8" 284 sx AS JilL 2513' 2513' & 250 sx Class G 7" 250 sx Class G 5633' 5633' t: f., ", ~ ~I II",", "', . ~ if 'f.,,, "". ~,.¡;", ORIGINt._ I. ~, .r". ('" '9 C,ll (, } '".,Id ~ ...;ò \Ia:::':<a Qi:ï & Gas Cons. C'\mcÜ:~;:;' Anchorage fll.t '-" ) L. ¡ Description summary of proposal _ BOP sketch 14. Estimated date for commencing operation March 7,1998 16. If proposal was verbally approved Chuck Scheve Name of approver Detailed operation program ...ð.. : 15. ~tus of well classification as: : Oil.Q. Gas_ Suspended _ March 5, 1998 Date approved Service 17. I her~y cert~.fy th t the foregoing is true and correct to the best of my knowledge. Signed Jd rbl'l. ~/(Æ..iA#6H/ Title Drilling Superintendent I-UK CUMMISSIUN Ut)~ UNL Y Date /'fAA-CII oS' /99B ., Conditions of a~prov~l: Notify Commission so representative m~y witness . /' Plug integrity ~ BOP Test K Location clearance.::. Mechanical Integrity Test _ Subsequent form require 10-~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 IAPproval N~·l ~8 --Ob~ Original Signet] d~i Cùv:ò \'J. Johnston Commissioner Date g II C)~ SUBMIT N RIPLlCATE ~pproved COþy 1~~ed ~ ) KALUBIK #2 PROPOSED P&A WELLBORE DIAGRAM t>'· -'~"" ~'~'>~..~.\?~;"·:-:.~:~--~.-.:.;:'<~Ú~~~; ',>.',,/' ."_:;~~~~~~. /"x ~'p~. ',::~.:.'~~.:::~)~...<._" "" ,~ ,. "--"~ ..... " . , ì:,;}'~~¡{~t~1i¡~;:t~,¡~;i~~,~~I~t~r~~i .. \;, >- .¿i!y)l~ . · 'r·'i!{~f;::.::::,;;.t~;¡;::\";:i~\ .~.~'. 'JI~,:I. : ~i~ .,.~" - ~'" . ',.'/;':.:;......:- ".~'. ~J.,"';,:~: ::.~~J,;.:j.~!,~~: ".:' ""/~~':" ( i;JH+ /' ;;;,};~j~ ¡~. ····F:@ ~ ' ,;:\~t.f :......~.~.'.~./...'.:....:...:.":.'. . ~.<> 1:'iiit '0 . ..:..../.,.~..;.;./..~~:.~.....~...~.¡.;.. ..~.i.i..·. i:$! '''/:' '/~;";' , 4t. '>:~;<~ ;© :';.,~:'? ) 3/4/98 9-5/8" SURFACE CASING AND 16" CONDUCTOR CUT OFF 15' BML, 50' RKB 16" CONDUCTOR 76' BML SURFACE CEMENT PLUG 75'-275' CEMENT RETAINER AT 275' 7" CASING CUTOFF AT 3251 9-5/8"x7" ANNULUS CEMENT DOWN TO +/-1300' 9-5/8" SURFACE CASING AT 2513' TVD(MD) MUD ESTIMATED CEMENT TOP: 4400' TVD(MD) PBTD AT 5487' TVD(MD) TO AT 5650' TVD (MD) ]i . , FLOAT COLLAR AT 5550' TVD(MD) 7" PRODUCTION CASING AT 5633' TVD(MD) ) ') KALUBIK #2 PLUG AND ABANDON PROCEDURE 3/5/98 Prepared By: General Information Permit No.: API No.: Geometry: Status: Objective: Drlg. Engineer Date KRU DSD Date 98-20 (Permit to Drill) 50-103-20252 16" @ 111' RKB 9-5/8" 40 Ib/ft, L-80, BTC @ 2513' 7" 26 Ib/ft, L-80, BTC @ 5633' MD RKB PBTD @ 5487' MD RKB (approx) TO @ 5650 ' MD, 5650 TVD RKB: 28ft KOP @ Straight Hole Maximum Hole Angle = 2.15 Deg Angle through Tarn sand = 1.0 Deg Drilling AFC: AX-9824 Wellhead is FMC Kuparuk Gen IV 16" Landing Ring 9-5/8" 3M Speed Head, 11-3/4" Buttress x 11" 3M C-29 with 2" 3M Wing Valve 11" 3M x 7-1/16" 5M "TCM-ET" Tubing Spool with 2-1/16" 5M wing valve 7 -1/16" 5M x 3-1/8" 5M A-4 Tubing Head Adapter Tree is FMC Gen IV 3-1/8" 5M Wellbore fluid is filtered seawater with 3% KCL Plug and abandon Kalubik #2 per AOGCC regulations. Procedure: 1. Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. AOGCC has option to observe all plug setting operations. AOGCC Field Inspector Contact Numbers: Pager:659-3607 Truck: 659-3870 Office: 279-1433 Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. Save mud from Kalubik #3 well or contact Parker for 9.5 ppg kill weight mud. 2. MIRU Doyon Rig 141. KALUBIK #2 PLUG AND ABANDON PROCEDURE ') ) 3/5/98 3. Check for pressure on 7" casing and 9-5/8"x7" annulus. NO dry hole tree. Nipple up BOP. Pull BPV and tubing hanger. Set test plug and test BOP to 250/3000 psi. 4. RIH with 3-1/2" drill pipe to PBTO at 5487'. Displace diesel and completion fluid (SW+3%KCI) out of 7" casing with minimum 9.5 Ib/gal kill weight mud. POOH. Lay down excess drill pipe. 5. Check for pressure on the 9-5/8"x7" annulus. Pickup 5-1/2" hydraulic multi string casing cutter assembly dressed to cut the 7" casing. RIH on 3-1/2" drill pipe to 325' RKB. 6. Cut 7" casing at 325'. Monitor well. POOH. 7. PU BOP. Nipple down tubing head. Remove 7" packoff. PU spear. Spear 7" casing. Remove 7" casing hanger slips. NU BOP. 8. LO 7" casing. 9. RIH with 9-5/8" cement retainer on drill pipe. Set cement retainer at 275'. Sting into cement retainer and establish injection rate. Squeeze 46 bbl (278 sx) AS-I cmt thru retainer into 9-5/8"x 7" annulus. Sting out. Set 15 bbl (92 sx) AS-I surface plug from 275'- 75'. 10. POOH to 75' RKB and circulate on top of cement plug. 11. RIH with 8-1/4" multistring cutter dressed to cut 9-5/8". Cut 9-5/8" casing at 55' RKB (20' BML). Use bridge crane to support weight of BOP while cutting casing if required. 12. NO BOP. LO 9-5/8" casing cutoff. 13. RIH with 11-3/4" multistring cutter with jets blanked off. Cut 16" conductor at 50' RKB (15' BML). 14. RU slings and pull 16" conductor. 15. Remove cellar. Back fill remaining hole with ice or snow. Clean ice pad location and demob all material and equipment for season. ) ) á3 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 901 276 1215 ~~ ~~ February 23, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501- 3192 Re: Weekly Operations Report ARCO Kalubik #2 Permit No. 98-20 ARCO Kalubik #3 Permit No. 98-05 Dear Commissioner Johnston, Attached is the weekly operations summary for the ARCO Kalubik #2 and Kalubik #3 wells being drilled in the Colville River delta area with the Doyon 141 rig. Production casing was set on Kalubik #2 and operations were shut down pending the results of the Kalubik #3 well. The drilling rig was moved to Kalubik #3 and this well was spudded on February 20, 1998. Kalubik #3 has been drilled to surface casing point. If you have questions or require additional information, please contact Fred Johnson at 265-1492. Sincerely, j~~ Fred Johnson Drilling Engineer M~ r: ;("'. r r~ I:·~- t"'''' E .\\ L \.,,' to ¡i V,,~ I':"~ x Q 'u· oJ. ~ ~ L., t~J. 'I ~) "',Ii;Ìs.«a Cd ,t~ (;(;s Cans. Commí,ssì(H1 l\nchcr2ge AR3B-6003-93 242-2603 Date: 2/23/98 ') ) ~~ E··,"'" ·f- ~ \f F [) ~\. t",,.~ .= ".'-- 1."\ 1"" " ::-- 1.·"1 ',: /1 '. L _) ,... T Page: 1 ARCO ALASKA INC. WELL SUMMARY REPORT - "I (} f', c: COI...'" f'ommis:;\on i1.\~aska Oil \;;¡t ,ÛL.. , Ii"- I.J Anchorage -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL~KALUBIK #2 WELL_ID: AX9824 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: SPUD:02/07/98 START COMP: RIG:DOYON RIG 141 WI: 0% SECURITY: 0 API NUMBER: 50-103-20252-00 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- BLOCK: FINAL: 02/07/98 (D1) TD : 21 7' ( 21 7 ) SUPV:RLM 02/08/98 (D2) TD : 1 7 8 3 ' (15 6 6 ) SUPV:RLM 02/09/98 (D3) TD : 2 5 2 5' ( 7 4 2 ) SUPV:RLM 02/10/98 (D4) TD: 2 5 2 5' ( 0 ) SUPV:RLM 02/11/98 (D5) TD : 2 7 5 0' ( 2 2 5 ) SUPV:RLM MW: 10.0 VISC: 165 PV/YP: 24/22 APIWL: 12.8 DRILLING AHEAD AT 610' Accept rig at 0200 hrs. 2/7/98. Function test diverter system approved by Larry Wade. Held pre-job safety meeting. Drill 12.25" hole from 111' to 217'. MW: 10.0 VISC: 84 PV/YP: 24/21 APIWL: 11.6 DRILLING AT 2300' Drill and survey with MWD from 217' to 1783'. Circulate bottoms up and pump slug. Wipe hole from 1783' to 859'. Work through tight hole at 1300', remainder of trip free. CBU. MW: 10.0 VISC: 62 PV/YP: 19/18 APIWL: 0.0 CEMENTING 2ND STAGE ON SURFACE Pre-job safety meeting. Drill 12.25" hole and survey with MWD from 1783' to 2525'. Wipe hole from 2525' to 1177', hole free. Wash 30' to bottom, hole free, no fill. Pump hi/low vis sweep and circulate hole clean, pump slug. Rig up to run 9-5/8" casing. Held pre-job safety meeting. Run 9-5/8" casing. MW: 9.5 VISC: 43 PV/YP: 10/11 APIWL: 2.0 MAKE UP BHA Pre-job safety meeting. Finish running 9-5/8" casing to 2513'. Perform 2nd stage cement job. First stage through shoe at 2513' and second stage through stage collar at 1703'. ND diverter and set back. Wash cement out of 16x9-5/8" annulus. NU BOPE. Test BOPE. Bottom pipe rams failed. Remove bottom rams and redress. MW: 9.5 VISC: 43 PV/YP: 10/11 APIWL: 0.0 DRILLING Pre-job safety meeting. NU BOPE. Install fresh set lower rams. Test lower pipe rams to 500/5000. BOPE test witnessed and approved by Larry Wade (AOGCC). Drill out stage collar at 1703'. Test casing to 2000 psi. RIH tag cement at 2316'. Test casing to 2000 psi for 30 minutes. Drill out cement baffle at 2386', float collar at 2422', and float shoe at Date: 2/23/98 02/12/98 (D6) TD : 4 7 91' (2 041 ) SUPV:RLM 02/13/98 (D7) TD : 5 03 2' ( 2 41 ) SUPV:RLM 02/14/98 (D8) TD : 512 2' ( 9 0 ) SUPV:RLM 02/15/98 (D9) TD : 5 6 5 0' ( 52 8 ) SUPV:RLM 02/16/98 (Dl0) TD : 5 6 5 0' ( 0 ) SUPV:RLM 02/17/98 (Dll) TD : 5 6 5 0' ( 0 ) SUPV:RWS ) ) ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT 2513'. Drill new hole from 2525' to 2545'. Change over to fresh 9.5 ppg mud. LOT shoe at 2513' MD, EMW 12.48 ppg. Drill 8.5" hole from 2545' to 2750'. MW: 9.5 VISC: 51 PV/YP: 14/23 APIWL: 0.0 RIH ROTARY ASSEMBLY Pre-job safety meeting. Drill 8.5" hole survey with MWD, log with LWD from 2750' to 4791'. Pump hi-vis sweep. Circulate bottoms up. Observe well and pump slug. POOH to shoe, hole free, observe well. MW: 9.5 VISC: 50 PV/YP: 11/16 APIWL: 5.0 LAY DOWN CORE Pre-job safety meeting. Wash to bottom at 4791', no fill. Circulate bottoms up 600+ units gas. Rotary drill from 4791' to 4950'. Circulate, bottoms up gas 600+ units, no free oil in mud. Pumped hi-vis sweep, observed well, pumped slug. POOH, hole free. RIH with coring BHA to 4820'. Wash to 4941', hit small soft bridge, rotate through wash to 4950'. Core with 8.5" x 4" core bit from 4950' to 5032'. MW: 9.5 VISC: 50 PV/YP: 11/14 APIWL: 5.2 DRILLING AHEAD @ 5300' Pre-job safety meeting. POOH with core barrel #1. Core #1 cored 82', recovered 77.25'. RIH with core barrel #2 to 4992'. Core #2 from 5032' to 5122'. Core #2 cored 90' recovered 65.25'. MW: 9.8 VISC: 51 PV/YP: 12/20 APIWL: 4.0 RUNNING SCHLUMBERGER 'E' LOGS Pre-job safety meeting. Drill from 5122' to 5650'. Circulate and condition mud and hole. Had sloughing silty shale, splintery to blocky. Hole would not clean up. Weighted up to 9.8 ppg. Pump slug. Worked through to clean up. Pump hi-vis sweep. Mud weight increase reduced size and amount of sloughing silty shale. Circulated hole clean. Hole free. Ran DSI, GR and Sp from 5630' . MW: 9.8 VISC: 52 PV/YP: 12/21 APIWL: 3.8 CIRC & COND HOLE FOR 7" CASING Pre-job safety meeting. Continue running DSI/GR/Sp from 5630' to 2513'. Run #2 CMR/PEX/GR from 5630' to 2513'. Gran GR from 2513' to surface. Run #3 FMI. Ran #4 RFT. MW: 9.8 VISC: 51 PV/YP: 13/18 APIWL: 4.4 NIPPLING UP BOPE Pre-job safety meeting. Wash from 5562'-5650'. Run 7" casing. Date: 2/23/98 02/18/98 (D12) TD : 5 6 5 0' ( 0 ) SUPV:RWS 02/19/98 (D13) TD : 5650' ( 0 ) SUPV:RWS ') '> ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 FREEZE PROTECT ANNULUS Install packoff. N/U BOPE. Tag cement @ 5487'. Run tubing. Freeze protect tubing and annulus. MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED TO KALUBIK #3 Pre job safety meeting. Test 7" casing to 3500 psi/30 min, OK. Land tubing hanger. Test BPV. ND BOPE. NU tubing head adaptor flange and dry hole tree, test flange to 5000#. Set tree test plug and test to 5000#. Freeze protect annulus. Secure well. Release rig @ 0900 hrs. 2/19/98. -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL:KALUBIK #3 WELL_ID: AX9826 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: UNLISTED SPUD:02/20/98 START COMP: RIG:DOYON RIG 141 WI: 0% SECURITY: 0 API NUMBER: 50-103-20251-00 BLOCK: FINAL: -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 02/20/98 (D1) TD : 3 0 6' ( 3 0 6 ) SUPV:RWS 02/21/98 (D2) TD : 19 3 2' (162 6 ) SUPV:RWS 02/22/98 (D3) TD : 2 9 5 5' (1 0 2 3 ) SUPV:RWS MW: 10.0 VISC: 137 PV/YP: 14/36 APIWL: 10.8 DRILLING 12.25" @ 752' Rig accepted 0900 hrs. 2/20/98. Function test diverter system. Pre job safety meeting. Drill out conductor pipe from 54'-148'. Drill from 148'-306'. Trouble shoot MWD problem - failed - lay down same. MW: 10.0 VISC: 78 PV/YP: 12/15 RIH W/NEW BIT & MOTOR @ 2028' Rotary and slide drilled from 306'-1932'. APIWL: 8.0 MW: 10.0 VISC: 105 PV/YP: 15/28 APIWL: 7.2 RUN CASING & CEMENT Drilled from 1932'-2028'. 700 psi pressure loss, check surface equipment, OK. Washout in bit and motor. Wash and ream 30' to bottom. Drill from 2028' to 2581'. Pump pressure drop from 2500 to 2000 psi. Check surface equipment for leaks. Inspected MWD, motor, bit, jars, no washouts. RIH to jars. Kelly up, check for leaks @ jars, none. Drilled from 2561' to 2563'. End of WellSummary for Well:AX9826 " SENT BY: 2-19-98 ;11:25AM ARCO ALASKA~ ') ) ARCO Alaska, Inç. Post 0 ffiCe Box '10036U Anchorage, Alaska 99510',0360 TE!Iephone 907 276 121!i Pebruary 19, 1998 Davíd W. Johnston. Chaínnan Alaska Oil and Gas' Conservation Conunission 3001 Porcupine Drive Anchorage, Alaska 99501 "3192 Re: Sundry NOlice for Shutdown orWell Operations ARCa Kalubik #2 Permit No. 98-0020 Dear ConunissioßfjT Johnston, 907 276 7542;# 2/ 4 ~~ ~~ The ARca Ka1ubik #2 well has been drilled to 5650' M 0, 5650' TVD. The 7" production casing has been run and cemented at a depth of 56331. ARCO Alaska, Inc. hereby applies tc.)r sundry approval tor the Shutdown of Wen Operations of ARCü Kalubik #2, permit nllmb~r 98-0020. The shutd()wn is requested to allow time tn drill the Kalubîk #3 prior to deciding whether or not to test the Kalubik #2 well. Operations wìU be resumed on the KaJubik #2 wet1 this winter season and the we) 1 will be plugged and abandoned prior to the end of the winter exploration season as originally planned. A wellborc schematic is attached which depict~ the secure shutdown status of the well. The 7" production casing was nUl and cemented as shown in the wellbore diagtau1. The casing is plugged at the bottom with the float shoe~ ±80' of cenlcnt, the float collar, and 60' ofadditíunal cement. Plug back depth is 5481'. The casing has been pressure tested as per AOGCC regulations. The casing has not bee,r\ perforated. The wellhead, tubing hanger with back pressure valve, and tower tree valve have been instal1ed on the well. The 7" casing and 7"x9...S/S" slU'face casing annulus have heen freeze protected. If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sit:c~rdy '1 tile~ Drilling Superintendent '. ('''' '( I \1 C D RE' (~ :,f L'· ,- ,-- r,¡ "1 (~\I '\9 q R \:.~ tl) ~,'. .'> ~ \V \ m'\S'::'lon . on 8· Gas Cons. l¡oHì\l¡ ... A)asKa ' þ,nchorage ^] t;\I \ (¡nO: ¡ n:\ :'/1:) :,'(;0:\ AR3B-6003-93 ) ) úò ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 901 276 1215 ~~ ~~ February 16, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501- 3192 Re: Weekly Operations Report ARCO Kalubik #2 Permit No. 98-0020 Dear Commissioner Johnston, Attached is the weekly operations summary for the ARCO Kalubik #2 well being drilled in the Colville River delta area with the Doyon 141 rig. Kalubik #2 well was spudded on February 7. Surface casing was set at 2513' as per wellplan. The well was drilled to TD at 5650' and open hole logs were run. The well is presently being completed in preparation for production testing. If you have questions or require additional information, please contact Fred Johnson at 265-1492. Sincerely, ~~ Drilling Engineer R,'~ 'E"" ;11"'''' E'" rv E D' \.. .- ~ -~,. FEß 1 9 lQq~ --~, \~i ....... t... ¿\ïaska Oii & Gas Cons. Commission Anchorage 24~~2G03 Date: 2/17/98 ) ) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL:KALUBIK #2 WELL 10: AX9824 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: SPUD:02/07/98 START COMP: RIG:DOYON RIG 141 WI: 0% SECURITY: 0 API NUMBER: 50-103-20252-00 BLOCK: FINAL: -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 02/07/98 (01) TO: 217' ( 217) SUPV:RLM 02/08/98 (02) TO: 1783' (1566) SUPV:RLM 02/09/98 (03) TO: 2525' ( 742) SUPV:RLM 02/10/98 (04) TO: 2525' ( 0) SUPV:RLM 02/11/98 (05) TO: 2750' ( 225) SUPV:RLM MW: 10.0 VISC: 165 PV/YP: 24/22 APIWL: 12.8 DRILLING AHEAD AT 610' Accept rig at 0200 hrs. 2/7/98. Function test diverter system approved by Larry Wade. Held pre-job safety meeting. Drill 12.25" hole from 111' to 217'. MW: 10.0 VISC: 84 PV/YP: 24/21 APIWL: 11.6 DRILLING AT 2300' Drill and survey with MWD from 217' to 1783'. Circulate bottoms up and pump slug. Wipe hole from 1783' to 859'. Work through tight hole at 1300', remainder of trip free. CBU. MW: 10.0 VISC: 62 PV/YP: 19/18 APIWL: 0.0 CEMENTING 2ND STAGE ON SURFACE Pre-job safety meeting. Drill 12.25" hole and survey with MWD from 1783' to 2525'. Wipe hole from 2525' to 1177', hole free. Wash 30' to bottom, hole free, no fill. Pump hi/low vis sweep and circulate hole clean, pump slug. Rig up to run 9-5/8" casing. Held pre-job safety meeting. Run 9-5/8" casing. MW: 9.5 VISC: 43 PV/YP: 10/11 APIWL: 2.0 MAKE UP BHA Pre-job safety meeting. Finish running 9-5/8" casing to 2513'. Perform 2nd stage cement job. First stage through shoe at 2513' and second stage through stage collar at 1703'. NO diverter and set back. Wash cement out of 16x9-5/8" annulus. NU BOPE. Test BOPE. Bottom pipe rams failed. Remove bottom rams and redress. MW: 9.5 VISC: 43 PV/YP: 10/11 APIWL: 0.0 DRILLING Pre-job safety meeting. NU BOPE. Install fresh set lower rams. Test lower pipe rams to 500/5000. BOPE test witnessed and approved by Larry Wade (AOGCC). Drill out stage collar at 1703'. Test casing to 2000 psi. RIH tag cement at 2316'. Test casing to 2000 psi for 30 minutes. Drill out cement baffle at 2386', float collar at 2422', and float shoe at Date: 2/17/98 02/12/98 (D6) TD: 4791' (2041) SUPV:RLM 02/13/98 (D7) TD: 5032' ( 241) SUPV:RLM 02/14/98 (D8) TD: 5122' ( 90) SUPV:RLM 02/15/98 (D9) TD: 5650' ( 528) SUPV:RLM 02/16/98 (DI0) TD: 5650' ( 0) SUPV:RLM ') ) ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT 2513'. Drill new hole from 2525' to 2545'. Change over to fresh 9.5 ppg mud. LOT shoe at 2513' MD, EMW 12.48 ppg. Drill 8.5" hole from 2545' to 2750'. MW: 9.5 VISC: 51 PV/YP: 14/23 APIWL: 0.0 RIH ROTARY ASSEMBLY Pre-job safety meeting. Drill 8.5" hole survey with MWD, log with LWD from 2750' to 4791'. Pump hi-vis sweep. Circulate bottoms up. Observe well and pump slug. POOH to shoe, hole free, observe well. MW: 9.5 VISC: 50 PV/YP: 11/16 APIWL: 5.0 LAY DOWN CORE Pre-job safety meeting. Wash to bottom at 4791', no fill. Circulate bottoms up 600+ units gas. Rotary drill from 4791' to 4950'. Circulate, bottoms up gas 600+ units, no free oil in mud. Pumped hi-vis sweep, observed well, pumped slug. POOH, hole free. RIH with coring BHA to 4820'. Wash to 4941', hit small soft bridge, rotate through wash to 4950'. Core with 8.5" x 4" core bit from 4950' to 5032'. MW: 9.5 VISC: 50 PV/YP: 11/14 APIWL: 5.2 DRILLING AHEAD @ 5300' Pre-job safety meeting. POOH with core barrel #1. Core #1 cored 82', recovered 77.25'. RIH with core barrel #2 to 4992'. Core #2 from 5032' to 5122'. Core #2 cored 90' recovered 65.25'. MW: 9.8 VISC: 51 PV/YP: 12/20 APIWL: 4.0 RUNNING SCHLUMBERGER 'E' LOGS Pre-job safety meeting. Drill from 5122' to 5650'. Circulate and condition mud and hole. Had sloughing silty shale, splintery to blocky. Hole would not clean up. Weighted up to 9.8 ppg. Pump slug. Worked through to clean up. Pump hi-vis sweep. Mud weight increase reduced size and amount of sloughing silty shale. Circulated hole clean. Hole free. Ran DSI, GR and Sp from 5630'. MW: 9.8 VISC: 52 PV/YP: 12/21 APIWL: 3.8 CIRC & COND HOLE FOR 7" CASING Pre-job safety meeting. Continue running DSI/GR/Sp from 5630' to 2513'. Run #2 CMR/PEX/GR from 5630' to 2513'. Gran GR from 2513' to surface. Run #3 FMI. Ran #4 RFT. End of WellSummary for Well:AX9824 · SENT BY: 2-19-98 ;11:26AM ; 907 276 7542;# 3/ 4 ARCO ALASKA~ «3 Co ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ SU$pènd'~'·-"- "Operation Shutdown x Re-enter suspended well_ Alter casing _ Repair well _ Pluggina _ 'Tiffi.e ex\enslon _ Stimulaw_ Change approved program.... Pull tubing _ Vêlrlanœ Perforate Other 5. 'ype 6fWëll: mn__ ð. lJatum elevatìon (UfO or Kts) Oavelopment _ Exploratory ~ Stratigraptlic _ Service 2. Name of Operator 'ARGO Alaska...J.nç. 3. Add ress. P. O. Box 100360, Anchorage, AK 99510 4. location of well at surface 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E, UM At to-.p of ~l"Qd\Jctlve Intervel 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E,UM At effective depth At total d!Wth 1099~ FNL, 21241 FWL, Sec. 15, T13N, R7E, UM 12. J~sent well cooditíon summary"'''' Total Depth: measured (apprQx) true vertical Effective depth: measured (approx) true vertical Casing Structural Conductor Surface Intermediate Production Liner )y.ërfur~d¡ôn depth: Length 83' 2485' 5605' measured None true vertical None Tubing ($Ï%e. grade, 3r1d measured depth) None Packers and SSSV (type and measured depth) None 13. Atlaehment!l Wellbore schematic 32' RKB' above Sealevel 7, Unit or PròpIÚty'ñå'me Kuukpik Unit feet 5650 5650 4940 4940 6. Wel' number Kalubik #2 9:-'permit numb8f 98-0020 "...... "' ..,.·····n· 10. API number 50-1 03~20252 11. Field/Pool Exploration feet Plugs (measured) None feet fø~t Junk (measured) feet Cemented Meásured depth True vertical depth Driven 111' 111' 284 sx AS IIIL 2513' 2513' & 250 sx Class G 250 sx Class G 5633' 5633' Size 16" 9-5/811 7" The Kalubik #2 well has been cased and cemented. The well has been freeze protected. ARCa plans to drill the Kalubik #3 well prior to completing and testing or P&A the Kslubik #2 well. Operation5 will be shutdown on this well while the Kalubik #3 well Is drllll!ld. ARCO plans to resume operations on thi$ well by April 15, 1998. De$(:r;ptiO., summary of proposal _ Detailed operation program_ BOP skétch 14. Estimated date far commencing operation (Shutdown Date) Februarv 19. 1998 '16. If proposal was verbally approvfi'd Name of approver fJate approved Service 17. I hereby CëftUy tNJt~1'I ~gOing is tr'ùe and correct to the best of my knowledge. .Sig'.'ecl 'ð . Pc Title Drilling Superintendent " , \ t-OK COMMISSION US~ ONL t Conditions of approval: N . Commission so represeDtative may wItness Plug integrity BOP Test"r Location{q~M~ MechanicallnregrityTest_ Subsequeñfform require 1'CI!~' ""5:~ David W. Jo,. Approved by the order of the Commission Form 10-403 Rev 06/15/88 15. Status of well classification as: Oil Gas Suspended _ D~te ~-~ IAP~.r~V~1 N~-1ft9-N3 Commissioner Date:Jj 11J~t SUBMIT IJTRI~LlCATE 1\-\' .." ",. \\ '\ ~r. '!) 't''') \-> '~, ~ ,~ t' ì;", \"., \.. " ~~~ \-- , ~,(c\ Ü\\ ~\\ ~\'P.~~ ORIGN.-L i """\ "- -.';\O~ " (,1\';)';> \).)\ \\1" , SENT BY: 2-19-98 ;11:26AM ; ) KALUBIK #2 WELLBORE DIAGRAM ARCO ALASKA~ ) 907 276 7542;# 4/ 4 ACTUAL WELLBORE STATUS FOR SHUTDOWN OF OPERATIONS 2/19/98 5000 PSI WELLHEAD AND LOWER TREE PBTD AT 54871 TVD(MD) TD AT 5650' TVD (MD) TUBING HANGËR ..J AND BPV -' W INSTALL¡;O W en en W w a ë DIESEL -..........--------- COMPLETION FLUID E ",.', , , ,-', ," :~' '," <,";, ':' " ".', ':::':',::, :",:, ~.. .' , " ......'.' .. ....., .. .:.>,; " , . ¡ , : .:': '.::':~:",' ;~.:::'~:::~..:'.T>:::::' f.;:.:;.~': ':::;:':..~ .:.:.: :, " >r:~::.:,> :.·~~~:~i:·::~~ :~':':~ ",; .r' ..'. ::.····::T. M;':';ì c. !.. . . . . .., .,' ',',' '~""'-;'.'.~~ .," ,:"'-",' '. .~~: ,:', , -;~ ','- ':',", :,,: :.,_', 1. .;.:.:i~::; ~:~</~ 16" CONDUCTOR 76' BML 9~5/8" SURFACE CASING AT 2513' TVD(MD) W ESTIMATED CEMENT TOP: 44001 TVD(MD) ':'.:".' ~:!{ ;~\~\ ~. tt ',..',' ...~. ~~~:: ~" ,,""" ';,~. " :·:~·:tl :..... ';", f' t.·: ;':< ::;:;; ,', ';".-:", I:~ :,' '.: ~ ~{, ~.':':" ,~ . .' , ..... FLOAT COLLAR AT 5550' 1VD(MD} 7" PRODUCTION CASING AT 5633' TVD(MD) ') ) TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 F ebnlary I R. 1 ~q8 .\1ikc ZanghI Drilling Superintendent ARC a Alaska PO Box l00360 Anchorage. AK 99510-0360 C:¡~~ê)?-O Re: Waiver to disposc of ccmcnt rinsate from Kalubik cxploration wclls and 1998 Alpine wells down annuli of wells situated on other pads. Dear ~1r. Zanghi: \Vc havc reviewed ARCa's letters dated January 27 and 30. 1998. as supplemented by your Fcbnmry 9 letter. for a waiver to 20 AAC 25,080(d)(4), 1l1e waiver \\'ould allow ARCa to dispose of cement rinsate from Alpine (Pool #6) and Kalubik (Doyon # 141) exploratory wells down the annuli of wells located on another pad. specifically whichever \vell Parker #245 is drilling at time of disposal. Altcmativcly~ ARCa requests authorization to dispose cement rinsate down the annulus of well CD 1-22 after it is drilled and meets annular disposal criteria. Cement rinsate is generated from washing cement-mixing equipment aftcr cementing operations. The yolume of rinsate is small. about 30-40 barrels per cementing operation, While not exempt, it is primarily water and does not exhibit any characteristics of a hazardous waste. Becausc cement rinsatc has not been downhole. it cannot be considered a Class II fluid and therefore cannot be disposed of in a Class II well. Consequently, if not disposed down the annulus of an approved well, it must be hauled to Pad 3 for disposal. The commission docs not believe it is prudent to use Pad:' for disposing of cement rinsate. As thc principle Class I facility on the North Slope. Pad 3 handles non-hazardous. industrial oily wastes. The limited capacIty of Pad 3 should not be squandered in processing cement rinsate. which is essentially watcr. The commission concludes that cement rinsatc from Alpine and Kalubik exploratory wclls may be transportcd to Parkcr #245 for disposal. or alternatively to CD 1-22 aftcr meeting disposal criteria. ll1Ïs approval is for the following ,vells, Kalubik arca Kalubik #2 Kalubik #3 j )' ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DaVi¿on, Chairman DATE: February 10, 1 998 THRU: Blair Woñdzell, ~~ P. I. Supervisor FILE NO: .doc Confidential : Yes _, No -.X , Attachment Only_. FROM: Larry Wade~<.t.M1 Petroleum Inspector / SUBJECT: BOP test, PTD 98-20 If....{ u (.? ~ -2 February 10 Traveled to Kalubik #2 to test the stack on Doyon 1 41. Started the test with the bottom pipe rams and2 valves on the choke manifold. We couldn't get it to hold pressure and suspected the plug, pump, or air in the system. It ended up being the pipe rams. Went on and tested everything else while they made sure they had 5" elements for the rams. Everything else passed. The location is small but looks clean and well kept. The ice road to the location is being maintained very well. SUMMARY: Tested BOP's on Doyon 141 which is on Kalubik #2. 1 failure. Attachment: a9wgbjfe.xls ~, , '. ) ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8 Test: l,nitia X Workover: Doyon ARGO Kalubik #2 Set@ Weel<ly Rig No. 141 PTD # 98-20 Rep.: Rig Rep.: Location: Sec. 15 T. DATE: 1 O-F eb-98 Rig Ph.# 263-3160 Bobbie Morrison Pat Krupa 13N R. 7E Meridian Umiat 2,513 Other .. ···;TESTDATA·¡ .... Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. P ressu re P/F Location Gen.: ok Well Sign yes Upper Kelly I IBOP 1 250/5,000 P Housekeeping:....E.L (Gen) Dr!. Rig yes Lower Kelly I IBOP 1 250/5,000 P PTD On Location yes Hazard Sec. yes Ball Type 1 250/5,000 P Standing Order Posted yes I nside BOP 1 250/5,000 P BOP STACK: Quan. Test Press. P/F Test Annular Preventer 1 250/2500 P CHOKE MANIFOLD: Pressure P/F Pipe Rams 1 250/5,000 P No. Valves 15 250/5,000 P Lower Pipe Rams 1 250/5,000 F No. Flanges 38 250/5,000 P Blind Rams 1 250/5,000 P Manual Chokes 1 Functioned P Choke Ln. Valves 2 250/5,000 P Hydraulic Chokes 1 Functioned P HCR Valves 2 250/5,000 P Kill Line Valves 2 250/5,000 P ACCUMULATOR SYSTEM: Check Valve 1 250/5,000 P System Pressure 2900 Pressure After Closure 1625 MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 40 sec. Trip Tank X X System Pressure Attained 2 minutes 50 sec. Pit Level Indicators X X Blind Switch Covers: Master: X Remote: X Flow Indicator X X Nitgn. Btl's: 5~21 00 Meth Gas Detector X X Psig. H2S Gas Detector X X TEST RESULTS Number of Failures: 1 ,Test Time: ~ Hours. Number of valves tested ~ Repair or Replacement of Failed Equipment will be made within days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Bottom pipe rams wouldn't pass. Opened the doors and found the elements bad. Parts on location. Left while being repaired. Distribution: orig-Well File c - Oper.!Rig c - Database c - Trip Rpt File c - Inspector FI,021 L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO Waived By: Witnessed By: Larry Wade 24 HOUR NOTICE GIVEN YES X NO A9wgbjfe.xls ') f ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David JOhn5~ Chairma;&'" DATE: February 7, 1 998 THRU: Blair Worìdzell,~{ ... P I S . -t.. £ß . . upervlsor FILE NO: .doc Confidential : Yes _, No X , Attachment Only_" SUBJECT: Diverter Function Test PTD 98..20 ~ ~ ,-,=- -2... r;J IJ'(Ø\ I "It February 7 I traveled to ARCQ's Kalubik #2 to witness a diverter function test. The location is on an ice road approximately 7miles outside the Northwest corner of the Kuparuk River Unit. The drilling location is very compact but orderly. Some of the ancillary drilling equipment is stored outside the primary location. The diverter function test went well and the rig looked clean for just being through a rig move. FROM: Larry wadq""'1t Petroleum Inspector SUMMARY: Witnessed a successful function test on ARCQ's Kalubik #2. Attachment: e9wgbgfe.xls ') f ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Drlg Contractor: Operator: Well Name: Location: Sec, Doyon ARCO Kalubik #2 T 13N Operation: Rig No. Oper. Rep.: Rig Rep,: 7E Development 141 PTD # 98-20 Bobby Morrison Pat Krupa Merdian Umiat Date: 2/7/98 Exploratory X Rig Ph, # 263-3141 15 R TESTQ~;TI::' MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok Reserve Pit: nla Well Sign: (Gen.) Drlg. Rig: Flare Pit: X ok nla ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: 2 Nitrogen Bottles: 5@2000psi 2950 1825 min. 33 min, 15 psig psig sec, sec. DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: yes Valve(s) Auto & Simultaneous: yes Vent Line(s) Size: 20 Vent Line(s) Length: 108 Line(s) Bifurcated: nla Line(s) Down Wind: yes Line(s) Anchored: yes Turns Targeted I Long Radius: nla in, psig in. ft. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: GAS DETECTORS: Methane Hydrogen Sulfide: Light Alarm X X X X X X Light Alarm X X X X 11j.I"ERTER1S~HEM~iIC Doyon 141 substructure North . 10 divert line Wind Direction .---- Non Compliance Items Remarks: Repair Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - OperlRep c - Database c - Trip Rpt File c - Inspector AOGCC REP,: Larry Wade OPERATOR REP,: Bobbie Morrison DVTRINSP.XL T (REV, 1/28/97) L.G. E9wgbgfe,xls Report prepared 2/18/98 l I) ) TONY KNOWLES, GOVERNOR ALASKA OIL AlQ) GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501·3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 5~ 1998 Michael Zanghi Drilling Superintendent ARCa Alaska, Inc. POBox 100360 Anchorage, AK 99510-0360 Re: Kuukpik Unit Kalubik #2 ARCO Alaska, Inc. Permit No. 98-0020 Sur. Lac. 1099'FNL. 2124'FWL, Sec. 15, T13N, R7R UM Btmholc Lac. l099'FNL, 2 I 24'FWL, Sec. 15, T13N. R7E. UM Dear Mr. Zanghi: Enelosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies. and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the wcek's activities and is exclusively for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~ BY ORDER OF THE COMMISSION dlflEnclosures cc: Department of Fish & Game. Habitat Seetion w/o encl. Department of Environmcntal Conservation \v/o encl. < .f, AFi3B-6003-93 ARCO AlaSka,.} ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 901 276 1215 ') ) ~~ ~~ Qf-ðð2.0-0 January 30, 1998 David W . Johnston, Chairman Alaska ail and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 R E ( E I V E D Re: Application for Permit to Drill ARCa Kalubik #2 JAN 30 1998 Dear Commissioner Johnston, Alaska Oil & Gas Cons. Commission Anchorage ARca Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the ARCa Kalubik #2, on State Lease ADL 355036 near the mouth of the Colville River. ARca will act as operator for itself and Union Texas Petroleum in evaluating this acreage. The proposed surface location is approximately 1 mile southwest of the ARca Kalubik #1 drilled in 1992. The wellsite will be accessed via ice road as shown on the attached map. ARCa plans to use the Doyon Rig 141 to drill this well from an ice pad during the winter of 1998. Attached find the information required by 20 AAC 25.005(c) and 20 AAC 25.061. All waste drilling mud and cuttings generated during the drilling of this well will be hauled to either the Kuparuk River Field or Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Nuiqsut Formation which directly underlies the Kuparuk Formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARca 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. ARca also requests an exception to the shale density requirement in 20 AAC 25.033(e,2,D). The shale density technique does not work well in Alaska due to the variable composition of the shales and the chemical used in the shale density column is listed as an exceptional health hazard. The surface location of the Kalubik #2 well is in very shallow water offshore of the Colville Delta and is subject to offshore well design regulations. ARca requests a waiver of the requirement to install both structural casing at 100' below the mudline and conductor casing in the interval from 300' to 1000' below the mudline. ARca proposes to set a conventional well conductor at 100' below the mudline and drill the surface hole to 2500'. It is our opinion that the well can be safely drilled with a conductor set at 100' and that setting both the structural pipe and the deep conductor does not add any additional level of safety. This opinion is based on the following comments. The water depth at the well location is estimated to be 3' -4' . This seawater will all be frozen during the entire well operation. The well will be drilled from a grounded ice pad that will be constructed to have 3' of freeboard over the surrounding grounded sea ice. With the pad surrounded by grounded ice there are no horizontal ice loading forces. The well will be drilled using a conventional 242-2603 I ì AR3B-6Q03-93 )) )) ARCa Alaska, .'he. ..oiIIIIIIIIIII1III... Post Office Box 100360 ø ..... Anchoragej Alaska 99510-0360 , , Nortlr~wþQ~~m.ti1t5drilling rig. Although the well is technically offshore, t~~ ~,.. well should only experience the normal forces that an onshore well would experience thus eliminating the need for higher structural strength at surface. This well is an expendable exploration well and will be plugged and abandoned this season. Therefore the well would not be subj ected to breakup and open water sea forces. The review of the offset exploration wells and the shallow hazards review from seismic data do not identify any unusual drilling hazards in the surface hole interval which might require heavier mud weights. Geotechnical and log information indicate that permafrost is not present at the surface in this area but does exist in the deeper interval from approximately 700' to 1500'. Therefore the planned conductor at 100' will be set in unfrozen firm soils which will provide good anchorage for the conductor and should not be subject to permafrost melting. Eliminating the deeper offshore conductor will result in significant time and cost savings that would be incurred to both install the additional casing string and to remove the string during the abandonment operations. The Commission is requested to keep confidential the following attachments to this permit application which are drawn from research and data proprietary to ARCO Alaska, Inc.: Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program Finally, the following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Weekly Status Report Fred Johnson, Drilling Engineer 265-1492 2) Completion Report Fred Johnson, Drilling Engineer 265-1492 (20 AAC 25.070) 3) Geologic Data and Logs Ken Helmold, Explorationist 265-1491 (20 AAC 25.071) Due to a recent change in our drilling schedule, the Kalubik #2 well will be drilled first. Anticipated spud date for this well is February 5, 1998. Your prompt review of this application would be appreciated. If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely, I h'~\ Mike ~gJ Drilling Superintendent Kuparuk Drillsite Development 242-2G03 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2. 1 a. 1 ype of Work urill ~ Re-Entry _ Name of Operator ARCO Alaska, Inc. Add ress P. O. Box 100360, Anchorage, AK 99510-0360 Kedrill Deepen _ 20 AAC 25.005 1 b. I ype of Well I=xploratory-lL- Stratigraphic I est _ lJevelopment Oil_ Service Development Gas _ Single Zone _ Multiple Zone _ 5.Datum Elevation (DF or KB) 10. Field and Pool DF elevation above SL 30 feet Kuukpik Unit 6. Property Designation ADL 3550361,/' ALK 4539 3. 4. Location of well at surface t. Unit or property Name 11.1 ype l::Sond (see 20 AAC 25.025) Statewide Number 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E, UM At top of productive interval Kuukpik Unit 8. Well number 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E, UM At total depth Kalubik #2 9. Approximate spud date #U630610 Amount 1099' FNL, 2124' FWL, Sec. 15, T13N, R7E, UM 2/5/98 $200,000 12. lJistance to nearest 13. lJistance to nearest well 14. Number of acres in property 15. Proposed depth (MIJ and 'I VIJ) property line Kalubik #1 MD 7000' 2124' @ TD feet 1 miles feet 5760 TVD 7000' feet 16. 'lobe completed for deviatec wells 1t. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth feet Maximum hole angle Maximum surface 1480 psig At total depth (TVD) 3640 psig 18. Casing program Setting lJepth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MIJ IVIJ MIJ IVIJ (include stage data) 20" 16" 621b B Weld 105' 27' 27' 135' 135' Permafrost Cmt or Driven 12-1/4" 9-5/8" 40lb L-80 BTC 2473' 27' 27' 2500' 2500' +1- 480 sx AS3L, 340 sx G 8-1/2" 7" 261b L-80 BTC 6973' 27' 27' 7000' 7000' +1- 400 sx G 19. 'lobe completed for Kedrill, ~e-entry, and lJeepen Uperations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured true vertical feet feet Junk (measured ir---¡ " Casing Structural Conductor Surface Intermediate Production Liner Lengt~ Size Cemented Measured depth True Vertical depth RECE'VE~ Alaska Oil & Gas Cons. Comm~ ssim Anchorage 20. Attachments riling fee ~ Property plat -lL- BOP Sketch ~ lJiverter Sketch ~ IJrilling program ~ Drilling fluid program ~ T,ime vs depth plot ~ Refraction analysis -lL- Seabed report _20 AAC 25.050 requirements _ 21. is true and correct to the best of my knowledge ORrGrNAl I ,1\ ~I 7,. 1QQ8 '\..¡ ¡-, ¡\~ I.; -.l v Perforation depth: measured true vertical Signed f~ · Date (~qr Title Drilling Superintendent Commission Use Only Permit N,l, mber P. number II APpr~l~c1a ~ ()ð ~-ðl'J¡tcJ -J03-aOÂ.);t. I {¿? 70 cond~ons of approval Samples required )iYes _ No Mud log r uir .x Yes Hydrogen sulfide measures _ Yes ){., No Directional survey required ~ Yes No Required working pressure for BOPE _ 2M; ){ 3M; 5M; _ 10M; 15M Other: See cover letter for other requirements No Approved by I-orm 10-401 Kev.t-24-89 UI\Jiìì:¡: òll~¡rku r)~1 David W. Johnston by order of Commissioner the commission Date ~-6 /f19 Submit in triplicate -(EV DAlE ~y CK ~... ) .' l LJE~O<I'" liON o(EV DA It. . <0 I.{) I""') I.{) o I.{) F A.IRBANKS . ANCHORAGE ~. r--- ~ } CK ~... I IJI:.~I"'IION KALUBIK #2 LAT. 70-29'05.57"N LONG. 150·18'21.82"W KAKTOVlK ~ )'" <'" ~~ "'~ ;t u _ 69. . J".. ~ ~ ~ ~ . or- <t- or- «« ~O (j)« «Z -1« «U . ..- ~ ..- /.f) <0 Øl·· LOUNSBURY ^ & ASSOCIATES, INC. · E~EERS PLANNERS SURVEYORS Q') I.() I""') I.{) ARCO Alaska, Inc. <> Subsidiary of Atlantic Richfield Company CADD FILE NO. I DRAWING NO: LK601257 01/06/98 KALUBIK #2 DEVELOPMENT WELL PERMIT EXHIBIT I SHEET: I REV NSK 6.01-d257 1 OF 2 : 0 ) ), ~EV DAII:. !::IY CK AI-'P Dt. SCI<I I-' 1 ION I<EV DATE CK Al-'I-' , 31 32 33 34 35 36 31 6 5 3 4 ) 8 9 #2 o 18 15 22 27 SCALE: ,. = 1 MILE BASEM AP: COLVILLE - ASP ARCO Alaska, Inc. <> Subsidiary of Atlantic Richfield Company CADD FILE NO. I DRAWING NO: LK691,257 01/06/98 )t.~Q(11-' liON 32 T14N T13N 2 ;;0;;0 '-J(X) f'Tlf'Tl 6 5 t- LOCA TED WI THIN PROTRACTED 7 8 SEC.1S, TWP.13N., RGE.7E., UM. LA T. 70·29'05.S7"N -'Ý LONG. 1S0·18'21.82"W -~~ y: 6,027,050 ~S; x- 462,SSO 13 18 0/1 J 17 1099" F.N.L. ' V 2124' F. W.L. 23 <9~ 19 )- 20 24 o 26 25 30 29 36 31 ~ ~ ;;0;;0 ~\ç O~2 \ ~ ~~ 8 Uf ø- LOUNSBURY ^ & ASSOCIATES, INC. , E~NEERS PLANNERS SURVEYORS ~º 9(g KALUBIK #2 DEVELOPMENT WELL PERMIT EXHIBIT NSK 6.01-d257 I SHEET: 2 Of' 2 I REV: 0 J \ 1: AAI 64/0 + 6 00/00/00 + V 00/00/00 + 00/00/00 T6~¡ 00/00/00 if) ., ,_ Do/cio/aD + + + ADL38.8573 ADL.3~8.572 AD't~8571 25 2~INT~ER, J. 18' Isqþäfu OÔÎOO/OO- / 00/00 0 "<. // '....-"'-1~ ADU§8~~o ADI_.39~-IB--'~... . ~g8576 _ OOI+O<:8:~jv' . _=-=___~ADL¡~},~04 __ tx~ AAI J ~. ....-:.... . ~.' /---:---.J:os::"/---' - AAI. B¡:)~ ,._-....,,~------ .-// ",:", 'V' ..\,.'-~-,' .\' " :- + o)ihetT.s ì ,;nUBBP" 13 /slanæc AN 1-pt ~3P) AAI. EXXÖN I/J 36 7-31-93 /\LI<4537 .31 ALK4535 ADL 3550.3'J· A9L 355021 I I 1:- I IC AAI UTI;) I{J AAI, BPX KllUkpik Unit -1- _.- + .+ I P.:···rOiP.Ö..·.·9se.d 6 ï IcEtRoad AAI -----....,.....- ". ...'{'-.l6.(,I.:.;:...--- ~ Iii 1319p 7-319.3 lØ ADL3~8566 AÄJ 7·31-93 1\1,1<4543.36 ....,. ADL 3 r)50/IO AAI. UTP -+- ~Kalub1< #3 \ .. AU<453S \ ADL 355035 \ : I M,UTP \ \ \ "'\-. 7 +- 16 "" OOIOOIOll 00/00/00 IØ 5- 31- 3/ .36 ADL38B57B ADU88577 .. AAI.SPx 10 6 A 7 <\1- g,~ -¡. + -+ 45-.3'1-93 +- ,;,t"'.. ·.u'.'¡S.f~ . ' i \ :'I?/, 3'::.!.+ 71" . I ¡'. J. t ,/\:.1. l.Jï¡:' '-li' " '.." /1' +:- -17, I· j.¡. -i~", 1,1 I I. .' II I . ¿LV 1 ",'j,: " "híJl :.':'''4?~ 'I . .\', ..' : ... .:I,~,~.:.JI,-.'!I:\;. :JT,r );, / ~' 11-11-92.' \ 7·31-9:S ._ \:aIU~ik . #2 -+1 AU\3575 ADL 355030 " I MI. BPX .\> +~, :::1· )·1 ¡ .. .. -I. !?I='. ,..~:: - " ,,~~I_I .\':;:,'~"~'¡ ..\ Iii,; '" " ¡.O " ,+ ',:1 J: " ,,/ .....1. " ..¡ ,:. ~·.I: - [II. ::' ~.'y, :: I ! L ~ 5k -I- "'18"" , . ." - ~ II . ! I_I . ~I::- " "LI -' .~-' , "¡'L I' - /)- + + ',u+-- " >.',-:',1 nìt~.3'~ _~,- ,'LI'~~5~.c,.,:,~~~r?~J~"~':.4.1--'" 3"'~ ::·.:..~,I.¡~I_I~-.17.-'~~,-,'~- ':'1,.1,,'::6:::', AU-::5¡::,9 ... \\ ,_. :r,-,:,,_::, /_~--............... :.[lL q2:':"~4 ¡:.Dl q:>§.52.5 , .: ': :' - "'IL",(~1".: t-1...)Il· '( I '.' ~þJ.ep(.I:,NC":.>J.. t\Ä 8 'r- ~ . >;¿ç;/-> -. "-, 8P' P 8P' "1, "'.'~.:JNc.'-"- . P I 11-1 . ~,~~ . "11-' -:' _j" ',1'11'02 (--;,-;~~.t ,~\- ,¿.~ D~~H _ ·'1'- ",1--' .--/" .~-;. ',.1 +- - ¿. ~~ \.0, .~~ :'()~¡'~~ ," - ,J~~' i...!/~ -~;-, ../,r---::;¿; "._. _ :_;~,.: ., ·.t, ~ '(; \ / "-',: "" Iv. ~ . ALl ¿,ig., I "'.Þ'3'µ& ... . .ÄLK2.-..~::;.s' -' r "'L ._~'4~ ~L"'~t;'-'j I ¡lJ"....l62:. ALK.:::6~8 ~~~... . _, ~I'>')25~,.:F,¡>!1[ 3~fJOC\./ ~~)~.::/ )iIÇ1t:.:.!-~::~.3 ADL tfJ2.5526 r.D-T_ 380101:; ADL ':''::15.3':: j""'" -" . ADL 925531. . AD-O: '.-- . . ,." .. . .' ::.ALK2539\:·' ,~DL .:J::!S5~" ~')'P':'~':t~~~~/ ...',:",:;~; .....~..~l!~~i. - i~~:<!I~ K:J!i~ii:~ell;3' , )f~f(:.t.P i6tKl~!t,;. . ··lt~~~:!.5~p.~~K~!~~L~~~:~¡::,i, NORTH ~~~~E2 ALASKA . ·:\;~..:·)·r'· ""'.'. ~~~~~~tl°6fbY~ è~~~: Alaô~t ~~~. 97102203802 ~ ~ :;,,-,<,-,',":" ; ;" .-..~ '-- :........:.',. ;:, - r'~ .',;:_~:. ...' . '''I' '..: .~\';.~ ;,.-.--.... ....:~. .~. .:.:", ':..." :..~.. ) ) GENERAL DRilliNG PROCEDURE ARCO KAlUBIK #2 1. Move in and rig up Doyon #141 over pre-installed 16" conductor casing. 2. Install and function test diverter system. Rig up mudloggers. 3. Drill 12-1/4" hole to 9-5/8" surface casing point (2,500' TVD) according to wellplan. 4. Run and cement 9-5/8" casing. 5. Nipple down diverter. Install 11" 3000 psi casing head. Install and test BOPE to 3,000 psi. Test casing to 2,500 psi. 6. Drill out cement and 20' of new hole. Perform leak off test. 7. Drill 8-1/2" hole to 7,000' TVD, coring as necessary, according to wellplan. 8. Run open hole evaluation logs as required to evaluate prospect. 9. If the well is to be tested, run and cement 7" production casing. (If significant hydrocarbon zones are present above the Morraine interval, sufficient cement will be pumped for isolation in accordance with Rule 20 MC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing. If the well will not be tested, P&A it per AOGCC regulations. 10. Complete the well with tubing and packer. NO BOPE. NU tree and pressure test tree to 5,000 psi. 11. Shut in and secure well. RDMO Doyon #141. 12. Hook up well for flow testing to surface tanks. Produced fluids to be trucked to Kuparuk production facilities or reinjected into the producing formation. 13. Test zones as appropriate. When complete, plug and abandon the well as per AOGCC regulations. 14. Thoroughly clean location and ice road. ) ) ARCO KALUBIK #2 PRESSURE INFORMATION AND CASING DESIGN (Per 20 AAC 25.005 (c) (3,4) and as required in 20 AAC 25.035 (d)(2» DISCUSSION The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling of Kalubik #2. Casing Pore Casing Setti ng Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling 16" 135' TVD 11.0 ppg 8.5 ppg 60 psi 62 psi 9-5/8" 2,500' TVD 13.5 ppg 8.5 ppg 1 ,105 psi 1 ,480 psi 7" 7,000' TVD 16.0 ppg 10.0 ppg 3,640 psi N/A Expected Maximum Mud Weights: 12-1/4" Surface Hole to 3,000' 1 3,000': 10.0 ppg 8-1/2" Production Hole to 7,000' 1 7,000': 10.5 ppg Procedure for calculating Anticipated Suñace Pressure (ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.11] D Where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft. RKB OR 2) ASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing point - 1 - ) '\ ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11] D = [(11 x .052) - 0.11 x 135' = 62 psi lesser OR ASP = FPP - (0.11 x D) = 1,105 -(0.11 x 2,500') = 830 psi 2. Drilling below surface casing (9-5/8") ASP = [(FG x 0.052) - 0.11] D = [(13.5 x .052) - 0.11 x 2,500' = 1 ,480 psi lesser OR ASP = FPP - (0.11 x D) = 3,640 - (0.11 x 7,000') = 2,870 psi Casing Performance Properties Size 16" 9-5/8" Weight 62.58 ppf 40 ppf 26 ppf Grade B L-80 L-80 Connection PEB BTC BTC-M Internal Yield Tensile Strength Collapse Joint Body Conductor Casing 3,090 psi 947 M 916 M 5,410 psi 641 M 604 M 7" 5,750 psi 7,240 psi Casing Setting Depth Rationale 16 in. - 135' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. 9-5/8 - 2,500' RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. 7 in. - 7,000' RKB Production casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if logs indicate the well is a dry hole. - 2 - ) ARCO KALUBIK #2 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' RKB 1214" Hole 9-5/8" Surface Casing at 2,500' MD/TVD 8~" Hole 7" Production Casing at 7,000' MD/TVD .... WI ········L W Base of pennafrost at 1,510' RKB Stage Tool at 1710'RKB Top of West Sak at 2,200' MD/TVD Top of Cement at 4,250' MD/TVD a It ') Casing Size I Hole Size Depth: Top of Cement Excess Calculated: 16" 120" 135' MO / RKB Surface 100% Volume Calculations: (135 If)(0.7855 cf/lf)x2 = 212 cf (212 cf)/(0.93 cf/sk) = 228 sx ARCTIC SET I Slurry Volume: Slurry Weight Slurry Yield Casing Size I Hole Size Depth: Top of Cement Stage Collar: Excess Calculated: BHT (Static): BHT (Circ.): Stage 1: Lead Volume None 228 sx 15.7 ppg 0.93 cf/sx 9-5/8" 112-1/4" 2,500' Surface 1 ,710' 45% Stage 1, 400 % Stage 2 50° F 50°F System: Tail Volume (2,500'-1,710')(0.3132cf/lf)(1.45) = (359 cf)/( 1.16 cf/sx) = 310 sx + 30sx for shoe jnt Slurry Volume: Tail Slurry Weight Slurry Yield Thickening Time 340 sx 15.8 ppg 1.16 cf/sx 3.5 - 4.5 hours Stage 2: Volume (1,710')(0.3132 cf/lf)(4) = (2,142 cf)/(4.41 cf/sx) = 480 sx System: (457 sx Class G cement + 3.5% D44 (NaCl) + 30% D53 (gyp) + 50% 0124 (spheres) + 1% SI (CaCI2) + 1.5% D79 (extender) + 0.2% 046 (defoamer) Slurry Volume: Slurry Weight Slurry Yield Thickening Time Casing Size I Hole Size Depth: Top of Cement Excess Calculated: BHT (Static): BHT (Circ.): 480 sx 10.5 ppg 4.41 cf/sx 6.0+ hours 7" 18-1/2" 7,000' 4,250' 50% (depending on OH volume) 160° F 130° F Volume (7,000' - 4,250')(0.1268 cf/lf)( 1.50) = (523 cf)(1.19 cf/sx) = 440 sx + 15 sx for shoe joint System: (313 sx Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 D47 (defoamer) + 3% 053 (Gyp) + 0.7% 065 (dispersant) + 0.15% 0800 (retarder) Slurry Volume: Slurry Weight Slurry Yield Thickening Time 454 sx 15.8 ppg 1.19 cf/sx 3.5 - 4.5 hours ) \) I DRilliNG FLUIDS PROGRAM ARCa KAlUBIK #2 1:==-~~=::::=-~:=-=-:::F:!~~~~¿~~~=r1-'J~~W!~l "" Dënsity" - -._-.- - -.. - - .._-.. ;"" --. 9.0-10.0 .. ..... i ..- . .. 9-'-0-10.5'" d_.''._ ï 0,IÓ Solids'- - -- n. i - - -100/0 ---;. - "4-70/õ --: l"".."_.,,,.............,,,,,,,,,,.,,,,,,... ......._.__...__._..___............1...._.".".._.._.._._.............................._.............""",.,.. 1...".._,""'''..''''.......".''''''',.,........,.,..,....._..,.''''''',.,.,.,.."",...I Drilling Fluid System: 3 - Derrick Flo-Line Cleaners Pioneer Model S2-12 Oesander Tri-Flo 'Low Profile' Oesilter Alpha-Laval Model OMNX 418 Centrifuge Pit Level Indicator (wI visual and audible alarms) Trip Tank Fluid Flow Sensor 8 - Brandt pit stirrers ') 21%" 2,000 psi WP DRilliNG SPOOL w/16" Outlet ARCO KALUBIK #2 Diverter Schematic Doyon 141 Flowline þ '1 I ( I 21%" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER ( 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER liNE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ) '), ARCO KALUBIK #2 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS ~ L 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER wI companion flange to bell nipple ~ ~ < ~ ~ ~ 3" 5,000 psi WP OCT ~ MANUAlGATEV~~ KILL LINE ~-? 3" 5,000 psi WP Shaffer GATE VALVE ~ wI hydraulic actuator ~ þ þ DOUBLE 13-5/8" 5,000 psi WP, , HYDRIL Magnum BOP wI pipe rams on top and blind rams on bottom ~ ¿~ CHOKE LINE ~~OPSiWPOCT ~ ~ MANUALGATEVALVE L, 13-5/8" 5,000 psi WP I DRILLING SPOOL ~ ~ wI two 3" 5,000 psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, Hydril MPL BOP wI pipe rams ~ DSA 13-5/8" 5m x 11" 3m I o - -1000-- -2000 ----- 9-5/8" SURF 1..... CSG L -3000 -;...- - I- U. - J: l- e. W C -4000 .J <C o ¡::: 0:: w > -5000 - -6000 -7000 --- -8000 ' 8 ) ') I ARca KALUBIK #2 EXPECTED PORE PRESSURE, MUD WEIGHT, FRAC GRADIENT --+- PORE PRESSURE . o LOT/FIT DATA o ___ MUD WEIGHT --.- FRAC GRADIENT n--fI t r I----t- 0, I I .;.- .... I I I I I i I --;---~-- ..-~ --\ 9 10 12 13 15 18 16 17 14 11 MUD WEIGHT EQUIVALENT( LB/GAL) 0- r -1000 -i---- -2000-- -3000 -4000- ::J: t: -5000 -- W C -6000 ---- -7000 -8000 -9000 . -10000 - 8 - -:. 9 ) ¡' 't, I KALUBIK #1 MUD WEIGHT ARCO 1992 POOL RIG #6 48" SCREW PIPE AT 48' I 30" CONDUCTOR AT 102' 20" CONDUCTOR AT 525' 13-3/8" SURFACE CASING AT 2758' LOT 14.0 LB/GAL AT 2763' - - ___..___M_ I I 11 I I I Y, ! 9-5/8" INTERMEDIATE CASING AT 6820' LOT 15.9 LB/GAL ----- 10 12 13 14 11 MUD WEIGHT (LB/GAL) -.------ 15 16 17 18 o -1000 r------ -2000 -3000 -4000 J: l- n. W C -5000 -6000 -7000 1 -8000 - -.,. --.-------- ) THETIS ISLAND EXXON 1993 POOL RIG 4 20" CONDUCTOR SET AT 491' FIT 13.9 LS/GAL - 01 -..1----- ! I i I I 13-3/8" SURFACE CASING SET AT 3031' FIT 13.9 LS/GAL - --I I \ 1_- \ I ! - - - ------.----------. - -9000 --- --- 8 9 ~~ ----~._-'._._--_._--_._'--'--- 10 11 12 13 MUD WEIGHT \~ " ----.,- 14 15 "'I 16 17 18 o -1 000 ~--- -2000 .---- -3000 -4000----- J: I- a. -5000 -- W C -6000 . -7000 - -8000 ---- -9000 ------ -10000 8 .') '~: TEXACO COLVILLE DELTA #1 1985 I r ~ ' ~O" CONDUCTOR AT 86' 20" CONDUCTOR AT 390' FIT 12.5 LS/GAL ~ . I --~-----+----- .. 1 13-3/8" SURFACE CSG AT 2500' FIT 13.4 LS/GAL 4' \ ~ 9-5/8" INTERMEDIATE CSG AT 7542' .' . . ~ -.------ --- ~ 7" LINER AT 9454' 9 10 11 12 13 14 DRilliNG MUD WEIGHT 15 16 17 18 0' 1,000' 2,000' . 3,000' 4,000'--- :J: to- [L 5,000'- W C 6,000' 7,000' 8,000' -- 9,000' - 10,000' 8 9 ) ) COLVILLE DELTA STATE #1 UNION OIL 1970 I 30" CONDUCTOR AT 69' 16" CONDUCTOR AT 794' --- i I 10-3/4" SURFACE CASING AT 2550' - ----¡ I - - . 4, - - . . i~_~RODUCTION CASING AT 8300' 10 11 12 13 14 DRILLING MUD WEIGHT 15 16 18 17 o -1000 ) ) EAST HARRSION SAY UNION Oil 1977 30" CONDUCTOR AT 112' 20" CONDUCTOR AT 137' - -2000~-- -3000 .------ -4000 - J: l- n. -5000 W C -6000 ------ I I I I ! -7000 ---' I ! -8000 - -9000 -- -1 0000 8.0 ------ Y· : I ! . : 13-3/8"SURFACE CSG AT 2646' ---1--- FIT 13.2 LS/GAL __.L- I I i - - - 4 Þ . ; ~,-,-,-- ---,---.-------- £.' - LOST SOME MUD AT 9085' - - - - - 9.0 10.0 12.0 14.0 11.0 13.0 DRilliNG MUD WT 15.0 16.0 17.0 18.0 '- --- _".- T ~ ,'-, .- f"'"' . ¡ }: lJ i : . --' ... .-.,. .......... - .... , ) TONY KNOWLES, GOVERNOR " : , " . .~ \ , . J ,.~ .~ '- - "\"'--' OFFICE OF THE GOVERNOR OFRCEOFMANAGEMENTANDBUDGET DIVISION OF GOVERNMENTAL COORDINATION Mr. Mark Major ARCO Alaska, Inc. P.O. Box 100360 Anchorage AK 9951 0-036è1aska Oil & Gas Cons. Commission , Anchorage / C13/éP> JAN 2 G 1998 "'~/PELINE COORDINÅ TOR'S OFFICE ð ~11 WEST 4TH AVENUE, SUITE 2C ANCHORAGE. ALASKA 99501·2343 PH: (907) 271-4317/FAX: (907) 272-0690 ~ÕM~~"':wi"~,"- ~ . - CO~~ COMM ,--~ , Co ' --:=-- ..-, L~ :' Rt::g~,-?_, f.òJ,'~ S... r-~,.... ~. I"{ ~¡'I;;\~ ' : .---..........-...-.....:"1.... , N.RO ~: IV', -Sr:- ....f::j;:::......... t'~ !..jr(;~....J,~. ··....".-_...........r....." ". ~ G!:Œ AS,:...·'¡·' :,; i S·~A:~~::~~rt-..: : 31' Al :rL\~ . ' ,~, -"~'''--, -¡, - """.....;............'......-.- ~: ,~ ': CJ SOUTHCENTRAL REGIONAL OFFICE 3601 ·C· STREET, SUITE 370 ANCHORAGE, ALASKA 99503-5930 PH: (907) 269-7470/FAX: (907) 561-6134 CJ CENTRAL OFFICE P.O. BOX 110030 JUNEAU. ALASKA 99811-0030 PH: (907) 465-3562/FAX: (907) 465-3075 RE(~VfD 1998 Dear Mr. Major: D 9~ /' 07 SUBJECT: ARCa 1997-1998 North Alaska Exploration Program Kalubik #2 and Kalubik #3 Exploration Wells FINAL CONSISTENCY DETERMINATION State ID No. AK9711-010G , ~ILE 1 '~", .~ The Division of Governmental Coordination (DGC) has completed coordinating the review of the proposed exploration wells for consistency with the Alaska Coastal Management Program (ACMP) and has developed this final consistency determination based on reviewers' comments. Project Description ARCO Alaska Inc., (AAI) proposes to drill two exploration wells in Harrison Bay, offshore of the Colville River Delta in the Kuupik Unit, these locations are still proposed, but are not expected to change significantly. Kalubik #2 Section 15, Township 13N and Range 7E of the Umiat Meridian. Kalubik #3 Section 28, Township 14N and Range 7E of the Umiat Meridian. The wells will be drilled from two ice pads that will be accessed by an ice road. AAI hopes to drill in early to mid-February. The wells will be plugged and abandoned upon completion of the project. A more complete description of the project may be found in the Plan of Operations and other permit applications originally distributed by AAI. 01·A35LH ") ") Mr. Mark Major January 21,1998 Kalubik Wells AK9711-010G 2 Scope of this Review Your November 5, 1997 letter to me identified four existing state permits that will apply to this project: Temporary Water Use Permits (LAS 18597 and LAS 14396), Air Quality Control Permit to Operate (No. 9673-AA002), and Fish Habitat Permit (FG97-III-0285). The Fish Habitat Permit is no longer required because the ice roads and the ice pads are located outside of the AS16.05.870 jurisdictional boundary of the DFG. In addition, as authorized by General Concurrence (GC)-34 and GC-5 on the "B" List, permit (LAS 21669) related to the ice roads has been issued by DNR. As described in GC-34, activities related to ice roads have already been found consistent with the Alaska Coastal Management Program (ACMP). This review addresses activities related to the proposed drilling of oil and gas exploration wells Kalubik #2 and Kalubik #3. Permits covered by this review are listed below: Alaska Department of Environmental Conservation - Temporary storage of Solid Waste - Oil Discharge Prevention and Contingency Plan (amendment to Kuparuk Field and Pipeline Plan Number 9734-CP-4125) - PSD Avoidance Air Quality Control Permit to Operate for an Exploration Well Alaska Department of Natural Resources - Lease Operations Approval - Geophysical Exploration Permit Alaska Oil and Gas Conservation Commission (AOGCC) - Permit to drill Consistency Determination Based on the review of your project by the Alaska Departments of Environmental Conservation (DEC), Fish and Game (DFG), and Natural Resources (DNR) and the North Slope Borough coastal district, the state concurs with your certification that the project is consistent with the ACMP provided the conditions outlined in the following stipulations are met. The following stipulations will be placed on the amendment to the Kuparuk. Field and Pipeline Oil Discharge Prevention and Contingency Plan (9734-CP-4125) issued by DEC: 1) Exploratory oil drilling operations are prohibited after April 1, 1998. 2) Prior to the onset of drilling operations, provide as part of the plan a description of each ') ) Mr. Mark Major January 21, 1998 Kalubik Wells AK9711-010G 3 oil storage container greater than 10,000 gallons used in conjunction with the operation, including specifics regarding the number, type, capacity, product stored, age, design, construction, and condition. Storage tanks greater than 10,000 gallons used for well flow tests must also be included. Note: The oil storage tanks over 10,000 gallons used in connection with this operation must be inspected and meet all applicable spill prevention requirements prior to being placed into service. Oil storage tanks over 10,000 gallons in capacity, including portable tanks, are subject to the API 653 inspection and spill prevention requirements of 18 AAC 75.065 and 18 AAC 75.975. The dates of any required API 653 inspections for regulated oil storage tanks must also be noted in the plan. Inspection reports must be available at the facility for DEC examination once operations begin. 3) Prior to the onset of drilling operations, provide as part of the contingency plan the following: (a) The precise description of the geographic location of each well to be drilled [18 AAC 75.425(e)(3)(A)]; (b) As-built drawings depicting the physical layout of each well pad, including drill rig, oil storage tanks, camp facilities and access points [18 AAC 75.425(e)(l)(H)]. 4) Notice of Chaneed Relationship with Response Contractor. Because the plan relies on the use of response contractor(s) for its implementation, the plan holder must immediately notify the DEC in writing of any change in the contractual relationship with the plan holder's response contractor(s), and of any event including but not limited to any breach by either party to the response contract that may excuse a response contractor from performing, that indicates a response contractor may fail or refuse to perform, or that may otherwise affect the response, prevention, or preparedness capabilities described in the approved plan. Rationale: Stipulations 1 through 3 are required to protect water quality, [6 AAC 80.140 Air, Land and Water Quality standard]. The following conditions are attached to the Lease Operations Approval and Geophysical Exploration pennit for this project issued by DNR: ) ) Mr. Mark Major January 21, 1998 Kalubik Wells AK9711-010G 4 5) Operation of Vehicles. a. Vehicles must be operated in a manner such that the vegetative mat is not disturbed, and the blading or removal of vegetative cover is prohibited except as approved by DNR. b. Filling of low spots and smoothing by the use of snow and ice is allowed. c. The use of grouÍld contact vehicles for off-road travel is subject to regional cross- country travel openings and closure notices issued by the Department of Natural Resources (DNR). Operations are restricted to the winter seasonal opening. After April 15, the use of ground contact vehicles is subject to termination within 72 hours of written notification from DNR. d. The winter operation of ground contact vehicles for off-road travel must be limited to areas where ground frost and snow cover are adequate to prevent damage to the vegetative mat and underlying substrate. Rationale: This stipulation is intended to protect the vegetation from being removed from the underlying substrate exposing soils to thermal degradation or hydraulic erosion and to protect the surface waters and habitat from possible contamination through the loss of hydrocarbons or any other hazardous substance, [6 AAC 80.040, Coastal Development standard; 6 AAC 80.130, Habitats standard; 6 AAC 80.140, Air, Land, and Water Quality standard]. 6) Solid Waste and Debris. a. Trails, campsites, and work areas must be kept clean. All solid waste including incinerator residue and fuel drums shall be back hauled to a solid waste disposal site approved by the Department of Environmental Conservation. b. Trash, survey lath, roadway markers, and other debris shall be picked up and properly disposed of prior to freeze-up of the following winter. Rationale: This stipulation is intended to prevent accumulation of solid waste on the tundra and to prevent the loss of and/or contamination of habitat and to protect state lands from unauthorized solid waste disposal or burial, [6 AAC 80.130, Habitats standard; 6 AAC 80.040, Coastal Development standard]. ) ) Mr. Mark Major January 21, 1998 Kalubik Wells AK97 11-0 100 5 7) Fuel and hazardous substances. Secondary containment I shall be provided for fuel and hazardous substances2. a. Container3 marking. All independent fuel and hazardous substance containers shall be marked with the contents and the permittee's or contractors name using paint or a permanent label. (Note: The permittee is ultimately responsible for contractor's compliance with these standard conditions.) b. Fuel and hazaI:dous substance transfers. Secondary containment or a surface liner4 must be placed under all container or vehicle fuel tank inlet and outlet points, hose connections, and hose ends during fuel or hazardous substance transfers. Appropriate spill response equipment must be on hand during any transfer or handling of fuel and hazardous substances to respond to a spill of up to five gallons. Transfer operation shall be attended by trained personnel at all times. Vehicle refueling shall not occur within the annual flood plain or tidelands. c. Storing containers within 100 feet of water bodies. Containers with a volume larger than 55 gallons which contain fuel or hazardous substances shall not be stored within 100 feet of a water body. d. Exceptions. The review coordinating agency, after consultation with other resource agencies and affected coastal districts, may under unique or special circumstances grant exceptions to this stipulation on a case-by-case basis. Request for exceptions should be made to the review coordinating agency. 8) Spill notification. The lessee or permittee shall immediately notify DNR (or the appropriate land manager) and DEC by phone of any unauthorized discharges of oil to 1 Secondary containment means an impenneable diked area or portable impenneable containment structure capable of containing 110 percent of the volume of the largest independent container. Double walled tanks do not qualify as secondary containment unless an exception is granted for a particular tank. 2Hazardous substances are defined under AS 46.03.826(5) as a) and element or compound which, when it enters the atmosphere, water, or land, presents an imminent and substantial danger to the public health or welfare, including fish, animals, or vegetation, (b) oil, or (c) a substance defined as a hazardous substance under 42 V.S.C. 9601(14). 3Containers means any item which is used to hold fuel or hazardous substances. The includes tanks, drums, double-walled tanks, portable testing facilities, fuel tanks on small equipment such as light plants and generators, flow test holding tanks, slop oil tanks, bladders, and bags. Manifold tanks must be considered as single independent containers. Vehicles, including mobile seismic tanks, are not intended to be included under this definition. 4Surface liner is any safe, non-penneable container (e.g., drip pans, fold-a-tanks, etc) designed to catch and hold fluids for the purpose of preventing spills. Surface liners should be of adequate size and volume based on worst-case spill risk. ) ) Mr. Mark Major January 21,1998 Kalubik Wells AK9711-0 1 OG 6 water, any discharge of hazardous substances (other than oil), and any discharge of oil greater that 55 gallons solely to land and outside an impermeable revetment. If a discharge of oil is greater than 10 gallons but less than 55 gallons, it must be reported within 48 hours by phone or fax. If a discharge is less than 10 gallons, it may be reported in writing on a monthly basis. If an unauthorized discharge greater than 55 gallons is made to a secondary containment, if must be reported within 48 hours by phone or fax. 9) All fires and explosions must also be reported. The DNR 24 hour spilI'Feport number is (907)451-2678; the fax number is (907)451- 2751. DNR or the appropriate land manager and DEC shall be supplied with all follow- up incident reports. The DEC oil spill report number is (800)478-9300. Rationale: Stipulations 9 through 11 are intended to protect the surface waters and the chemical characteristics of habitat that contribute to its ability to support life from possible contamination through the loss of hydrocarbons or any other hazardous substance by reducing the escapement of fuel, promoting early detection, and decreasing response time, [6 AAC 80.040, Coastal Development standard; 6 AAC 80.130, Habitats standard; 6 AAC 80.140, Air, Land, and Water Quality standard). The following stipulations will only be attached to the DNR Geophysical Exploration Permit: 10) Movement of equipment through willow (Salix) stands must be avoided wherever possible. Rationale: This stipulation is intended to protect the area's sparse willow stands which contribute to biological diversity in the area, and are valuable for browse, cover, and erosion control, [6 AAC 80.130, Habitats standard). 11) Equipment, other than vessels, must not enter open water areas of a watercourse during winter. Ice or snow bridges and approach ramps constructed at river, slough, or stream crossings must be substantially free of extraneous material (Le., soil, rock, wood, or vegetation) and must be removed or breached before spring breakup. Alterations of the banks of a watercourse are prohibited. 12) The structures must be breached or fractured prior to breakup so that their breakup rate coincides with those of naturally occurring ice formations in the area. This should be accomplished so as not to damage or disturb the vegetation of the terrain nor introduce dirt or debris into the waterways. ) ) Mr. Mark Major January 21, 1998 Kalubik Wells AK97 11-0 1 00 7 Rationale: Stipulations 13 and 14 are intended to protect the water quality and habitat of overwintering fish by preventing the introduction of sediments into the water, and the disruption of natural drainage patterns, [6 AAC 80.130, Habitats standard; 6 AAC 80.140, Air, Land and Water Quality standard). 13) Unless approved by DNR, in consultation with the Department ofFish and Game, operations must avoid occupied grizzly bear dens by Yz mile. Known den locations shall be obtained from (DFG) Habitat and Restoration Division, Dick Shideler (Fairbanks 459- 7283) prior to starting operations. Previously undocumented dens encountered in the field must be reported to the above and subsequently avoided by a distance to be determined on a case by case basis through consultation with the applicant, DNR, and DFG. 14) Unless approved by the DNR in consultation with the U.S. Fish and Wildlife Service (USFWS), operations must avoid known polar bear dens by one mile. Known den locations shall be obtained from the USFWS (786-3424) prior to starting operations. Previously undocumented dens encountered in the field must be reported to the above and subsequently avoided by a distance to be determined on a case by case basis through consultation with the applicant, DNR, and the USFWS. Rationale: Stipulations 15 and 16 are intended to prevent the unnecessary disturbance of hibernating or denning bears that might result from interaction with equipment, personnel, and the vibroseis sweep, [6 AAC 80.130, Habitats standard). 15) To avoid additional freeze down of deep-water pools harboring overwintering fish, watercourses shall be crossed at shallow riffle areas from point bar to point bar. Compaction or removal of the insulating snow cover from the deep water pool areas of rivers must be avoided. Rationale: This stipulation is intended to avoid additionalfreeze down of deep-water pools harboring overwintering fish. Deep water pools that do not freeze solid during the long arctic winter are limited in abundance and fish depending on these sources may have few alternatives once the area freezes, [6 AAC 80. 130, Habitats standard). 16) Should any historic, prehistoric, or archaeological site, or camp, either active or abandoned, be discovered during the course of field operations, the Commissioner of DNR and the North Slope Borough shall be promptly notified. Rationale: [6 AA C 80.150, Historic, Pre-Historic, and Archeological Resource standard). ) ) Mr. Mark Major January 21, 1998 Kalubik Wells AK971l-0 1 00 8 Advisories 1) The DFG requests that AAI consider orienting ice pads and arranging pad layouts in relation to prevailing wind direction to minimize drifting snow that can provide hiding places for polar bears. BP Exploration (Alaska) Inc. has adopted this procedure as routine practice for its exploratory pads, and AAI may wish to do likewise. 2) The DFG requests that AAI provide final ice pad locations to reviewing state resource agencies prior to ice pad construction. 3) The Kalubik sea ice road staked route provided by AAI (letter, January 8, 1998) departs shore just outside the DFG's jurisdictional boundary for the Colville River mouth, and the locations of Kalubik #2 and Kalubik #3 also fall outside the jurisdictional boundary. The DFG therefore will not be required to issue Fish Habitat Permit FG97-III-0285 (draft provided with DFG ACMP consistency determination dated November 25, 1997) to AAI for Kalubik activities in the Colville River Delta. Please be advised that westward deviation from the staked ice road route in the vicinity ofPI-7 (AAI drawing NSK 6.0 1-d260) would intersect DFG's Colville River Delta jurisdictional boundary and require a Fish Habitat Permit. 4) The DEC, Air Quality Monitoring Program advises that in order for the well drilling program to be consistent with the Alaska Coastal Management Program, AAI may need to propose operationaVemission constraints upon the drill rig activities to comply with ambient air quality standards and increments. 5) The North Slope Borough advises AAI to form a Nuiqsut response team that will be trained to assist in an emergency. This group would also provide local knowledge of ice conditions in the river and early warning for the onset of break up. A specific time line to remove all equipment from the Colville Delta is highly recommended, preferably by April 1. The potential for ice override during the spring or if an early break-up occurs, is a likely scenario to happen due to the unusually warm winter conditions. 6) The North Slope Borough advises AAI to perform a study of the impacts by seismic and drilling operations on the young of the year of the dominant species of the local fishery, the Arctic Cisco. The potential for harm may exist to the smallest fish due to the location of the drillsite and seismic activities. The Colville is a rearing and staging area for Arctic Cisco, a main food source for the village ofNuiqsut and should be studied for effects. From a study of Arctic Cisco we can learn how to minimize the negative impacts for ') ) Mr. Mark Major January 21, 1998 Kalubik Wells AK9711-010G 9 future projects. A copy of this study should be sent to the reviewing parties for reference. 7) Please be advised that although the state has found the project consistent with the ACMP, based on your project description and any stipulations contained herein, you are still required to meet all applicable state and federal laws and regulations. Your consistency determination may include reference to specific laws and regulations, but this in no way precludes your responsibility to comply with other applicable laws and regulations. 8) If changes to the approved project are proposed prior to or during its siting, construction, or operation, you are reÇluired to contact this office immediately to determine if further review and approval of the revised project is necessary. If the actual use differs from the approved use contained in the project description, the state may amend the state approvals listed in this consistency determination. 9) This final consistency determination does not obligate DNR to issue authorization under AS 38.05 nor does it supersede the statutory obligations thereunder. You may not proceed with any specific land use activity on state lands until authorized by DNR. If you have any questions regarding this process, please contact me at 271-4317 or E-mail GPavia@pipeline.state.ak.us. Sincerely, j ?~~ Eugene (Gene) Pavia Project Review Coordinator cc: Jon Dunham, North Slope Borough Al Ort, DFG, Fairbanks Robert Dolan, DEC, Anchorage Brad Fristoe, DEC, Fairbanks Jim Baumgartner, DEC, Juneau Joe Sautner, DEC, Anchorage Paul McLarnon, DEC, Anchorage Glenn Gray, DGC, Juneau Gary Schultz, DNR, Fairbanks Jack Kerin, DNR, Fairbanks ) Mr. Mark Major January 21,1998 Kalubik Wells AK9711-0 1 OG 10 Kris O'Conner, DNR, DOG, Anchorage Judy Bittner, SHPO, Anchorage Steve Schmitz, DNR, DOG, Anchorage Matt Radar, DNR, DOG, Anchorage Lloyd Fanter, Army Corps of Engineers, Anchorage Jeanne Hanson, National Marine Fisheries Service, Anchorage Ted Rockwell, Environmental Protection Agency, Anchorage Eric Taylor, Fish and Wildlife Service, Fairbanks Alaska Oil and Gas Conservation Commission ) ) / \) Date: January 30, 1998 Subject: Pore Pressure Prediction for the Kalubik #2 & #3 Seismic lines WBA-1388, WBA-1562 From: R. Wydrinski PRC-D1139 509-4325 To: M. Mabry F.Johnson ATO-1486 ATO-1292 This letter is to summarize the pore pressure work done in the Kalubik area using the above data. The models and parameters used for this project were the same as the Kalubik project done on September 25, 1997. There are no apparent shallow hazards or large pressure anomaly for these prospect well. Seismic Processing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velocity field that is used as input. This velocity field is generated by picking velocities at selected CDP locations with an automated high resolution velocity analysis program (UHCI process developed by AEPT). This process produces an accurate and densely sampled velocity field to cover the selected CDP locations. The RMS velocities that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instabilities in the velocity field that might result from noise, lack of signal, or variations in CDP fold. Pressure Prediction Procedure: ARCO's PPFG software was used to calculate the predicted pore pressure. The models used to calculate the pore pressure and fracture gradient was determined from the Alpine study done in 1995 and the Kalubik study done in 1997. Pore pressure was computed from the Pleistocene model which is: PP = C2 * ~~ T 2 + C1 * ~~ T + Co where: 1) PP is the predicted pore pressure 2) C2 = -0.00025769 ; C1 = 0.119231 ; Co = 8.94231 3) ~~ T is the amount of increase in µsec between the Normal Compaction Line (NCTL) and the seismic ITT. An increase of the ITT above the is an indication of a pore pressure increase. Trend NCTL ) ) Fracture Gradient Procedure: The Eaton method was used to calculate the fracture gradient. The inputs to this method are pore pressure (PP) , overburden gradient and Poisson's Ratio. The overburden was calculated from a synthetic density created from the ITT. The Poisson's Ratio used was one developed for West Cameron Gulf of Mexico. These parameters were determined from the Alpine and Kalubik studies. WBA-1562 : Kalubik #3 (CDP 594 ) Figure #1 is the pore pressure prediction across this line. The warmer the color the higher the pressure. The NCTL used for this line has a slope of _4.5-05 and an intercept of 163. The location of Kalubik #3 is at COP 594. There appears to be no shallow hazards across this line. Figure #2 is the predicted pore pressure plot of the Kalubik #3 at proposed location (COP 594). On the left portion of the plot is the pore pressure (blue curve) and the fracture gradient (red curve). The right portion of the plot is the seismic ITT (black curve) and the NCTL (red line). The increase in pressure at about 6,250' is probably a change in lithology and not due to pressure. WBA-1388: Kalubik #2 (CDP 664 ) Figure #3 is the predicted pore pressure plot across this line. The NCTL used for this line has a slope of _4.5-05 and an intercept of 165. The location of Kalubik #2 is at COP 664. There appears to be no shallow hazards across this line. Figure #4 is the pore pressure plot for Kalubik #2 at proposed location COP 666. The pore pressure prediction (blue curve) shows a mud weight increase at 5,200' to 10 ppg. At 7,250' the pressure increase is probably a lithology effect and not a pressure change. Conclusions: 1) There are no shallow hazards for the Kalubik #2 and Kalubik #3 prospects. 2) Kalubik #2 will have an increase in mud weight at about 5,200'. If you have any further questions, please call me at the above number. Ray Wydrinski ~~ARCO Exploration and Production Technology ~~ Pore Pressure and Fracture Gradient System CDP 4 9 MSL 0.0 1 D 4000.0 E P T H (ft) 5000.0 1??oo.0< Project: KALUBIK Cross Section: WBA_1562 PP DataSet 163_ 45SPLE_PPG Seismic Dataset: LINE_1562_Z Method: Trend Curve NCTL:163_45S Model: PLIESTOCENE 01/26/98 Ray Wydrinski Scale: Vertical 1 in = 1753 ft, Horizontal 1 in = 54 cdp KALUBIK 3 ~ - 5 6 9 0 4 1 TEST 804 ! 66667777777777 8888888888999 678901234567890123456789011 1 1 1 1 1 1 1 1 1 1 1 1 1 1 4 1 1 1 1 1 1 1 1 1 1 1 9 ppg 6 4 1 1000.0 2000.0 3000.0 6000.0 7000.0 8000.0 9000.0, ~ 8.00 8.50 9.00 9.50 10.00 10.50 11.00 11.50 12.00 12.50 13.00 13.50 14.00 14.50 15.00 15.50 16.00 -16.50 117.00 17.50 18.00 18.50 19.00 "~-~ i I "~AM\"U I:XplOral10n ana fJrOaUCI10n I ecnnology ~,... Pore Pressure and Fracture Gradient System 01126/98 Ray Wydrinski t70Ject: IV\I.UDII\. Well: KALUBIK_3 NCTI..:163_45S DEPTH (Datum set to MSL) -70 I I ' :' "I i i i ';' iii' ";' i -r jllllll' f-j'A'!':ï"~ r - r r I I ! I : IT 1000 I: I - ¡ ! i II I I n' · :"1·1" ".... .....~....l......... "'~"-"~"'r'" ..1.....J·.. .". ...~.L·~·r; .¡I·¡..l.r' ;·r~;·,~·~~~;r I I I 1 ' I I I I 1 I, I ," I Î Ii! : I i-II i:rll, If,I·' :-rl~: : II ~1! 11 III II Jj I,ll ! !t~;I:! b!~: q;~;, . : 'I : It· 1 I; l~:I_1 I¡!+ I I I , I I' ,I", r" - i ! I ! 1 I I II, ~ I; : 11: i _ ' l.l : 1 , - i 111 - e L ¡ II I f]t! !~! f II ft:, I II , ,I,,' " 11,1 , 1 I' 1 ' 'I ' " " I - t I I - : ). I : ~ - i ~ I , !; -I! I : -¡ ~ ~; II __ I 'I!I~I: _~!! ~':!11~: I I I I I I ~ Ii: I II I: I :" I I..' II ~ i i I it iii I il~l~ J)~":!j:: II _ill ~! I :~-I: ¡e':_,::I~,c I I I I I I I I,' I I," ! ;:1 _!~I Jill 1'1.'11 1~';_ 111 l' III I,' Ie::.:': ì:~' I' I 1 jl Iii L: I: I: 1-', I I', r I I I I I, I II :, , I ;, " I j I 1'1;' ¡ I ¡I,' I;il I ¡,lltï-. .I'I':ï,!-:,1 1,- I J::- 1 ~J I I jlllll~- :'''I~I:- l! I i ~: :;1 Ii! i: ¡: ¡;!: ¡!it I I 'I -t _I, ¡ 1f ï. : ¡ ¡ ¡ I: I; i>¡-: !__::_i,:.: I-tl¡ ft '1Iil~-;' 1'1 ",' I'I I ~, ,¡ I ~ lï: '~':·II I':~ I I; i ; ill ¡¡I I, : ~ r ¡ _:' I ' r t f : f _II III II ¡it: ~ : : I : -: : '; ~ ' Ii I j, 1:'-" 1"'1-','1': 40 60 80 100 120 40 160 NCTL Intercept at GL = 164.187 Logarithmic Slope = -4.5e-05 .... Casing Depth K Kick I Flow + Repeat Formation Test )( Drill Stem Test A Production Pressure I!I Leak-off Test 181 Lost Circulation Zones Formation Top ..... Stuck Pipe Location '\, Sidetrack Location X Freeform 2000 31)00 4000 5000 6000 7000 81)(1() qOOO ] (1))0 10900 Kalubik#3 (Line 1562, CDP 594) ________ m_____ ____UUh_uuuuuu___uu______u_~-: _________nn___________uu_n__. __u___u_u_m _u_uu__uu____umuu_u_ _u______u_u_____ mu________ u___ ____ m __m ~=:::::::::::~:::::::::::::::: ::::::::=::::::=::::: :::::::J\ ::::::::::::::::=:::::::::::::=:. ::::::::::::::::~:::::=:::::::::=:::::::::::::::: .::::::::::::::::=:::::::::::::::: ::::::::::::::::: :::::::::::::2::::::::: :::::::::::::::::::::::::::::::: :::::::~~~:::::~:::::=:::::::' ::::::::::::=:::::::::::~:::::::::::: '::::=:::::::::::::~~::::: ::::::::::::::::: .-------------_. --------------- --------------------------.---.-. -------._-- -----------------. --------- ------ --------------------------------- ------------ -------------------- --- -------------- ----- ------------ --------- -------- .----------- .-.---------- ------- ---------------- -------------. --------------- --- .----.- -------------_.-..--.... -.----.---~-----_.._----..-.--..- ----_.._..---..- .__0000_00_ m-c----nun- m__ '_n___h___ ______unn__mu_u _nu_nnnu__n_nn ______ _000000_00_______ _____n_____________n_u__h_____ ___uu___u__u__un_____m _ _u ___UUh__U_ 3000 .--------- ------ ----- .----------- - ----------------------------. -- .--------- .----.- .----------- ---- ----------- ------ .-------------------------------. ---------------.--.--.--.---- --- . ---- --.-..- -...- .---------------- ----.------------ --------------------------------- -------.-.-..---- ._-._-------.- --- ----------------- .----------------. ---------------- ._------------------------------- ----------------- .--------------- ------------- ---- ---------_.__._-----_..--.--.-- ------------------- -- --------- ----------------- .......-.-._-----_........._-_.-.. -----.----. ..-.---....-.-..------ .---- .-.-.-.....- C ------------- -- ----------- ------ --_..----.-----._-------- -------- --------------------------------- ---. -- -- ..--.--- ---------..-..-.----.--.-------- -------...--..------------- -. -.. - .--------------- .---------.--.-.------ --------- --------------------------------- ---------------- ..-.-------...---. .---...-- ---- .---.----------------------------- -.-----------.-.--.---.--.-.----. .---------.-..-.. ____m___unm_unmmun nPröoäl1e-töpuöf .títhö1ögycbmrge _mnnmnm_ _m nn_m_mnm____m _mmmm_______m____n_m ___m____um__ - - 6000 .- --- --------. -------------- -- - --- ------------ -.---. _.~------------_._-------------- ----------------- --n---n--h----~-u--u----....---PFõt5äl1et)öttöï10fLîtlïðtÖgY-CIï:üig-_m__m_ _m_m__u_____ ____mmnm_ m_mmmm_mnn__mm_ mmmmmu 8000 =~ ~ ~ ~~ ~ ~~~ ~~~ ~ ~~ = ~ ~ ~~ ~~~~ ~~ ~ ~ - - - - . ~~~~ ~~ ~~ ~ ~ ~ ~~~~~=~ ~~~ ~~~ ~ ~~ ~ ~ ~~~ ~ ~ ~ = ~ ~~~~~ ~~ ~ ~~~=~~= ~~~~~=~ ~ ~ ~ ~: ~ ~~~~~ ~~~~~ ~~~~~ ~~ ~ ~~~~~= ~~ ~ ~~~~~~~ ~ ~=~ ~-- - ~~~ ~ ~~~~ ~=~~~~~ ~~~~ =~~~~~~~~ ~~ ~ ~~ ~ ~ =~ ~~~~~ ~~ ~~~~ ~~- \ 9000 :::::::::::::::::=:::::::::::=:::~::=:::::::::::::::: ::::::::::::::::=::::::::::::::::: ::::::::::::::::: :::::::::::::::::~:::::::=::::::: _:::::::=::::::=::=:::::::::::: ::::::::::=::::: 1??oo .-------------- ---_._--.---------- -.-- - --- ----- ---- ------------- -- - --------------------- ------------ ------------------------------- ------------------ --------- ------------- - ----- -- -- --------------.-- . -------------- ----------------.-- -- - - ------ -------- --- --- - -- - ----- ---- --------------- --------- -----. ---- - ------------ .--- ------------------------------ ---------------._---.---------~-- -----------.--.-- ._---------~- -------...-.-------- ------- ---------------------- --- - --- ------------- -- ---------------. --------------- .--------------- ---- ------------ ------- -------------... --._.---.. ...------- ..---.- 8 9 17 10 12 13 14 PPG 15 16 18 19 11 -e- 163_ 45SPLE_PPG -e- 163_45SWC_FGEA (Sonic NCTL: 163_45S, Poisson Model: WEST_CAMERON) ;L FEET -70 1000 2000 ",-"I 4000 5000 7000 ---/ 10900 20 ~~ARCO Exploration and Production Technoloa\YToject: KALUBIK ...", Cro'§§'§ection: WBA 1388 ..,,,. Pore Pressure and Fracture Gradient Systel'ft>DataSet: 16S_4SSPLE_PPG Seismic Dataset: LINE_1388_Z CDP 6 o MSL 0.0 D 4000.0 E P T H (ft) 5000.0 1??oo.0 ' Method: Trend Curve NC1L:16S_4SS Model: OFF _SHORE_ TEXAS/- 01/26/98 Ray Wydrinski KALUBIK 2 ~ - TEST 1004 ~ 1 1 00 o 1 4 1 Scale: Vertical 1 in = 1753 ft. Horizontal 1 in = 62 cdp 1000.0 2000.0 3000.0 6000.0 7000.0 8000.0 9000.0 8.00 8.50 9.00 9.50 10.00 10.50 11.00 11.50 1200 12.50 13.00 13.50 14.00 14.50 15.00 15.50 16.00 ~16.50 117.00 17.50 18.00 18.50 19.00 '-........ __7' 3 .M",AM\"U exploration ana f-IrOaUCllon I ecnnology ~". Pore Pressure and Fracture Gradient System 01/26/98 Ray Wydrinski 17oJect: ~LUall\. Well: KALUBIK_2 NCTL:165_45S DEPTH (Datum set to MSL) -70 II I· , I' '1'1 '¡' I"" fl' II I !-III, t~"'::i 'I~' I r f - . ,~ I l' I, I ." ,- I 100( : r t Î' I -. I; I ~~ It::~;;, . , ...... .....~·...~....".."..t..t..Jl... "" ..~.".. ..j·..·JI... J·t~·¡·~il" i j'~1 ~~.L;·~tt~ r I ï I I I I I I ,-: -: I- I '111 ¡- 1- 1::1-, :" , I j 1 , I' I I t í t· I F I: -: Î I: ff I ffll ~. I~:¡-' ;:~ 11 II t11 L 1~111 ~:~ ! I i I Iii r W I:: !I~ I t- I 11. 1;'1-1 I'!' - I I l' ~ t- -rt~ !-::¡ '"T, f 1 I lïlltll;l- ï:,I-i,:,~':. If I 1111'·1 1. liÎ-,,'::~1 I I ~ I " I , ': I ~, -t -t Ii _I 'II I :~ I ~~!~ ::'-;,I, I : I ;': ~ ¡ ': ,:: I t t II t t I II ~ i ~: it: : ~: , :.; .: ,i I t I II . It - : ! : : -, ; I ¡ .J 111 í I I , , 'I " I "" ~ 1 Y I L I !lll_,;:,_~'ll ~! ".! ': L l~~:~¡~!'¡:I! I~III::.JII::' . ~ . j11 I~·! ~:,¡_,:,::,: (: III " ~I: ~¡II' I I '~~~,' ~¡:,I ::' ; I ¡ f; ; ~: : : ~ .~: : I .1 i:~~~,:~~::: , , ¡, : i : : -! : I: I: ' t l I i I Ii! . I I ' ; Ii: I , t i I ¡.jl !~~ :~¡ ¡;';~:::':i;: ]090{) 40 60 80 100 120 140 160 NCTL Intercept at GL = 166.201 Logarithmic Slope = -4.5e-05 ... Casing Depth M Kick I Flow + Repeat Formation Test )( Drill Stem Test A Production Pressure (!) Leak-off Test 181 Lost Circulation Zones - Formation Top ..... Stuck Pipe Location "" Sidetrack Location X Freeform 2000 ~f)OO .. ()()() 5000 6000 7000 8000 I I , I 1 I 9000 ~ O(li)() Kalubik #2 (Line 1388 ; CDP 666) FEET -70 .-- -- --- -------- ------------ ----- ._---._--_._---~ -----------.-. - -------- ------------------- ---- ---------------- ----- ----.----------------- --- ---- --------------- -------- ------ --- --- - ---------- --- .--------------- ----------------- ---_..----------------------- ----- --------------------------- ----. ---------------------------- ------.-.----------- ------.-------------------------- ----------------- .______uu_u_~__u_________u_ ______m___nn_n_nn_n__nn _ ____hh_____hhhu_____u_. ___________nnn_n__n_nnnn_nnnn__nno __nn_nnm____n________mu _____n______u_ 1000 ................., ................. ................................. .... ............................ ...................................._................. I................................. .................. .-- -------------, ------.---------- ---------- ---------------------- ---- -----------------.--.--.-- -------------------.----------------------.--- ---- --------.-.----.------.-----.-- .--------.--.---- .---- -- --------- ._------------ ---. . ._-_.--.-- -._-- ---------- ------- ------ -- --- --------------------. ----------------- .------ ----------- .-.--------- ---- -.-------- .-----------.. -- ------- --- - ---- ---- - ---- _n _ _m______ -C------- _ _ n __nU _no_nun _ n___nn_nnnnn _ m_n_ _nn_nnnnn______. ___________ ______ .__u____ _______________mn______ _ ________________________________ _________ ___0._0. 2000 --~ .------------ --. ------ -- ------ -- ------------- -------------------- -- -- .-.--.----- ----.----------- ---------------- .---- ----- -------------- - --- ------ ----------- --------------------- ----------------- .--------------- - ------------- --- .- ------------------------- ------ ----------.----- ._--- --------_. --.-------------- -------------------------------- .---- ----------------------- ------ ----------------- ._.m_nn____e___n___n_un_ .nnnnnnnn_nnnn____nn _mn_n__nn__n______n n_ u______nnn___ ._n___nn___n___nnnnn_n_n ,__n_u__nn_u_____nmnm mu___nnn_ 3000 .------ ---------.....----------..-.-- .---------..-- ------------------ --- - ------------------------- .. .--- ------.----- ._- .-----------------.- .--------- -------._-.-----_.----------- -. --._------------. .nn_nn m __n~nnn-n--- __ __ ___________n__ n__n n___nm n__ mnn_n______n__nnnn _n__n__h__________n_ _m _____ ________ ______m .__ ___h_nhn______u _______n__ ___nn___.. _____ ------------ --- --- --------------- ._---------- ---- ------- -------- ----.--.------ -----------------_. - -------------- .--------------- ----------------- -- ------ ----------------------- ---------- ------- n_ 4000 ~~~~~~~~~~~=~~~~~-~ ~-~~~~~~~~~~~~ .~~~~~~~~~~~~~~~~=~~=~~~~~~~~~~~~ ~=~~~~~~~=~~~~=~~~~~~~~~~~~~~~: ~~~~~~~ -~~~~~~~~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~=~~~~~~~~~~~~~~~~ ~~~~~~~~~~=~~~~~ -------------------.--- --._--------- ----.------------------ --- - ------ ---------- ---------------.------. -.--..--. _..--- -.._--_.-.._-.-- -.-----.----.---- .- ..-.-.---.--------.-----...-- -. --------- -------- I~ 5000 ~~ ~~ ~~ ~~~~ ~~ ~~~~ ~= ~~~~ ~ ~ ~ ~ - - ~ - -=~ .~~~~~~~~~ ~ ~ ~~~~~ = ~ ~~~~~ ~~ ~ ~ ~ ~~~ ~~ ~ ~ ~~ ~~ ~~ ~ ~= ~ ~~~ = ~ ~ ~ ~~~~~~~~~~ ~~~: ~ ~~~~~~ ~~ ~~ ~ ~~ ~~ ~ . - - -- -~~ ~~~ ~= ~=~~~ ~~~ ~ ~~~ ~ ~~ ~~~ . ~ ~ ~~ ~~~ ~ ~ ~ ~~ ~~~ ~ = ~~ ~~~= ~ ~ ~ ~~ ~~ ~~ ~~ ~ ~~~ ~~~ ~ ~ ~ ~~~ -- 6000 :~~~::~~~=~~:~~~=~:~~~~:~~::~~-::- ::~~:~~~::~~:~~-.:=~~::~~:~:~=~~~~ ~~~~~~~~~~~~~~~~=~=~~~~~~~=~~:. :::=:=:=:::::: :=:::~~~:: _::::~=:~:::::::~~::::: ~~::~:::::::::::=:::=::::::::::: :=:=::::::::::: 7000 ___n________n____nnnn_u_n~n . -LithGIGgy--Ghan~--------------. ______________m .________nnn__.. _____________ ____nn__n____n_nh_nnm mm_mnnm -- ------------------------------ ---. -.----------------- ------ ----------------------------- ------ ----------- ----------------- -------- ------ ------- --------------------- ----- ----------------- .nnn----mn--ž--------U------<--h ~_n_nn_n_m_ __n_nnn_n__nnn_nnnn n_nnm_n_n_._n_n_nnn_n___n nnn nnnnmh___nnn_n_n_n_ n_____mmm 8000 ---------- ------- ------------ -. ------------------------ ------- -------------------------------- ----------------- .------------------ --------- -------------------------------- -------- --------- .- ------------------- ----- ------ --------------.----------------- -------------------------------_. ----------------- ------------- --------- ------- -- -- ----------------- --- -- ------- --.-------- -. .-- .____muumn _u__m_n_m nnu__n_un__mmnuuun ______________n_u_h______u___. _______un_____ .m___u___________m__n __ __u_____u_________m___uu___ h_h_nu_nuh 9000 __.1'~ ._---------------~ ---------------- --------------------------------- ------------------------------- ---------------- .----------------. ------------- - ---------------------------.----- ----------------- .uu__ mu _ nn_~-u----n- ____u______n___n___U_UU_u_ u_ ___uu_u_____uuu_uuuu. uu____uuu_u ._u_n_u_u_u_u_____uunu_n _u_nu___u______u_uuuu__ u___u_u ____u_ 1??oo .--------- --_.- -- -- --------------- --- -- - --------------------------- -------------- ---------------- ---. ----------------- .---- -------------- - ----------- ---------------------------- .---- --- -------------- .- --------------- ---- ------------- -------------- ------------------- -.-. -- ------------. -- ------------ ------------------------.----..- -- ---- ------------ ---------- ----------------------- ----------------- .-------- -------- ----------------- -- .------------------------------ ----------------------- --------_. ---------------- - .-------------------------------- -----._-.-._-------------------- ----------------- 8 10900 20 9 10 11 12 13 14 PPG 15 16 17 18 19 -e- 165_ 45SPLE_PPG -e- 165_45SWC_FGEA (Sonic NCTL: 165_45S, Poisson Model: WEST_CAMERON) I ) ) ARCO KALUBIK #2 Drilling Hazard Section Surface Hole · Analysis of the seismic data in the surface hole interval d.oes not indicate any shallow gas or abnormal pressure drilling hazards. · Normal safe exploration drilling precautions for drilling below a diverter should be taken such as continuous monitoring of drill gas and mud weight, safe tripping practices, and proper hole fill. · Minor drill gas and hole sloughing should be expected at the base of permafrost. Base of permafrost is expected to be 1500'. Production Hole · Mud weight should be 10.5 lb/gal prior to drilling the Kuparuk formation which has a known reservoir pressure of 10.0 lb/gal equivalent (from Kalubik #1 DST data). · Normal safe exploration drilling precautions and procedures should be taken throughout this interval. :-- .'~ .il c-r í;::J'. .... . I , . : .: .\ '\ ¡! i !.-.., . ~.J U :,- .' . i fï \ ¡ .'~ . ._..J ......... _____ \ ,~ r;= ¡ /í ! ' ¡ ¡ ¡ ¡ ;:: , I . I , ¡ . ',,' / ¡ . -- ....: :M n n ¡.-;;, n 'l ,'\ I A I .J 1 \ f. I, ..) ¡ i¡ : ... \ I'"~ ~1 lj'~\ \~, \ '.1\ I ~ , ¡; . ~ \. ....\,;, '..' ;.J ': I :-' ~ . :_ !:.... \ ....\;; . :' : - , L..I \..J ~ u U __. ....... --...; ..... '), .\ TONY KNOWLES, GOVERNOR OFFICE OF THE GOVERNOR OFRCEOFMANAGEMENTANDBUDGET DIVISION OF GOVERNMENTAL COORDINATION CJ SOUTHCENTRAL REGIONAL OFFICE 3601 ·C· STREET, SUITE 370 ANCHORAGE, ALASKA 99503·5930 PH: (907) 269-7470IFAX: (907) 561-6134 CJ CENTRAL OFFICE P.O. BOX 110030 JUNEAU, ALASKA 99811-0030 PH: (907) 465-3562/FAX: (907) 465-3075 (PIPELINE COORDINA TOR'S OFFICE 411 WEST 4TH A VENUE, SUITE 2C ANCHORAGE, ALASKA 99501-2343 PH: (907) 271-4317IFAX: (907) 272-0690 November 12, 1997 c)f -, 1ð .r.(IJ)~:'" a;F~ ð q,' "1' i~~~"~ COMM CD RES ~NG '.~ SR ENG .úfJ I~~RQ_..". ..~_. kJ~1 SR GEOL Il~' -GEOL~ ~SST A' pAT T~!f-~ STAT.!~Ç~~ Mr. Mark Major ARCa Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Major: .-- - "....,-.."'- SUBJECT: Kalubik #2 and #3 Exploration Wells Extension of Review Deadlines State ID No. AK9711-010G FILE At the request of the Department of Environmental Conservation (DEC), the Division of Governmental Coordination (DGC) extended the review deadlines for the Kalubik Exploration Project today. Mike Lucky of the DEC Spill Prevention and Response Division requested the extension because the plans are missing information on Best Available Technology (BAT). We will continue this review as soon as the DEC notifies us that their application is complete. Should you have any questions, please contact me by telephone at 271-4317 or by electronic mail at GPavia@pipeline.state.ak.us. £:relY, b Ge~ia Project Review Coordinator cc: John Dunham, North Slope Borough Al Ott, DFG, Fairbanks Brad Fristoe, DEC, Fairbanks RECEIV'ED NOV 111991 *ka 011 & Gas Cons. commission Anchorage 01-A35LH ) ) 2 Mr. Mark Major November 12, 1997 Kalubik Exploration Project State ID No. AK 9711-01 OG Scott Bailey, DEC, Anchorage Frank Okamoto, DEC, Anchorage Jim Baumgartner, DEC, Juneau Joe Sautner, DEC, Anchorage Paul McLaron, DEC, Anchorage Glenn Gray, DGC, Juneau Gary Schultz, DNR, Fairbanks Jack Kerin, DNR, Fairbanks Kris O'Conner, DNR, DOG, Anchorage Judy Bittner, SHPO, Anchorage Steve Schmitz, DNR, Oil and Gas, Anchorage Lloyd Fanter, Army Corps of Engineers, Anchorage Jeanne Hanson, National Marine Fisheries Service, Anchorage Cindi Godsey, EP A, Anchorage Ted Rockwell, Environmental Protection Agency, Anchorage Eric Taylor, Fish and Wildlife Service, Fairbanks ~ Alaska Oil and Gas Conservation Commission FIELD & POOL WELL PERMIT CHECKLIST COMPANY A t<. to INITCLASS e~(7'- WELL NAME )~ ðttA.lkk ;t-;L PROGRAM: exp Œ( dev 0 redrll 0 serv 0 wellbore seg 0 ann. disposal para req 0 GEOL AREA R q (J UNIT# QWOFF SHORE cxJ* f'¡ G;-¿, l'-^d~ Lc.p [ ~ 16 L- ). . ADMINISTRATION APPR DATE ~OA;n.. -2.{2 ENGINEERING AP.fR_ DATE ~~ 21 e.. GEOLOGY APpR..-- Di\TE ~.v~ t:!/ '2- 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . , 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. " . . . . , _ . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6, Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . , . . . . . . 9. Operator only affected party.. . . , . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . _ . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval. . 13. 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 well bore 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 ~~OOCJ psig. 27. Choke manifold complies wlAPI RP-53 (May 84) . 28. Work will occur without operation shutdown. 29. Is presence of H2S gas probable., , , . . . . . . ~~ ebN Y® ®N CVN éVN ¥---N-" ®N tB~ WN ~ ffi~ <Y)N .y® \1)N ~~ y--r¢- @N ~ ~ 00/0/1 14 ( CON Y N ~~ Y€) 30. Permit can be issued wlo hydrogen sulfide measures. iN 31. Data presented on potential overpressure zones , 32. Seismic analysis of shallow gas zones. . . . . . . , , 33. Seabed condition survey (if off-shore). . . . . . . . . 34. Contact name/phone for weekly pro~ress reports . . . . . .. y ~ [expfora1ory only] GEOLOGY: ENGINEERING: COMMISSION: RPC~~ ~ BEW~- '2[~ DWt~ # JDH. v RNC ~ CO Cofl/t//qf HOW/ljt - A:\FORMS\ct1eklist rev 09/97 ~ (..HoA t.. P' I '" fI N f or * REMARKS F / .,L t'J..v,SHollT rl ~.ctt;lf/rfA'¡J';"'" ch. c: ~~. Y"-t l'd"'YJ J£v-c.I....,..Q t:""J~J ;Jt!- 2è:J 4-~C ¿($'.O,, ' ~~ 2-~h$ o o z o ~ ~ ~ ~ ~ ~ 2 ~ == ~ 00 00 ~ > n ~ ( J c..Cv'lkJ-s FI''-€.J Jo(,I'\~~v... 26~"'llf.9Z e; I=\~ HelW)n/Ä 26S--(lf 9( Commentsll nstructions: Ç)M-ðn~~ ~~ 2-(,033 (e-j 2J bJ &-Þk ¿GMfft /7) ) 6 [/~j'¡¡e-cI~ /I/::>.Æ S ~¡ ~ðÐn /Q~rI~ 1rA/J'l <qtq<fi'J Ne.)k c/'--///ed~rz.4'V1.V ~4'\Í ~;flc ~ 2-/08 ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ,MICROFILAiED Sate_ I / 50/0;;) ) ****************************** * * ALASKA COMPUTING CENTER ****************************** *----------------------------* *------- SCHLUMBERGER -------* *----------------------------* ****************************** COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO ARCO ALASKA, INC. KALUBIK #2 WILDCAT NORTH SLOPE ALASKA 501032025200 98100 ') <173 · o?-û Jt- q?~ \ ) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-MAR-1998 14:02 PAGE: 1 **** REEL HEADER **** SERVICE NAME EDIT DATE 98/03/30 ORIGIN FLIC REEL NAME 98100 CONTINUATION # PREVIOUS REEL COMMENT ARCO ALASKA, KALUBIK #2, WILDCAT, API #50-103-20252-00 **** TAPE HEADER **** SERVICE NAME EDIT DATE 98/03/30 ORIGIN FLIC TAPE NAME 98100 CONTINUATION # 1 PREVIOUS TAPE COMMENT ARCO ALASKA, KALUBIK #2, WILDCAT, API #50-103-20252-00 TAPE HEADER WILDCAT OPEN HOLE WIRELINE LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA KALUBIK #2 501032025200 ARCO ALASKA, SCHLUMBERGER 27-MAR-98 INC. WELL SERVICES RUN 1 RUN 2 RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 98100 V LOMAX W CAMPAIGN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 15 13N 7E 1099 2124 34.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ------------- --------- ---------- 1ST STRING 2ND STRING 8.500 9.625 2513.0 ) ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3RD STRING PRODUCTION STRING # REMARKS: 30-MAR-1998 14:02 PAGE: 2 THIS TAPE CONTAINS THE OPENHOLE WIRELINE DATA ACQUIRED BY SCHLUMBERGER ON ARCO'S KALUBIK #2. THIS DATA IS ORGANIZED INTO A MODIFIED LDWG FORMAT. $ $ **** FILE HEADER **** FILE NAME EDIT .001 SERVICE FLIC VERSION 001COl DATE 98/03/30 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH -------------- DAS CMR FMI $ ----------- ---------- 5605.0 5170.0 5352.0 2465.0 4899.5 4696.0 # BASELINE CURVE FOR SHIFTS: SDN CURVE SHIFT DATA (MEASURED DEPTH) ----------EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH DAS CMR FMI -------------- 88888.0 5571. 5 5563.0 5556.5 5550.0 5540.0 5534.5 5529.0 5521.5 5519.0 5516.0 5511.5 5509.5 5506.5 5498.0 5491.0 88887.0 5570.5 5563.0 5555.5 5548.0 5540.0 5536.0 5531.0 5523.0 5518.5 5517.0 5510.5 5508.5 5505.5 5496.0 5490.0 88887.0 88886.0 ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5484.5 5479.0 5474.0 5463.0 5456.5 5446.5 5430.5 5419.0 5403.0 5396.5 5388.0 5375.5 5362.5 5349.5 5342.0 5340.5 5338.5 5330.0 5328.0 5323.5 5323.0 5318.0 5311.0 5309.5 5307.5 5300.5 5298.0 5290.5 5289.0 5283.5 5283.0 5279.0 5274.5 5266.0 5260.0 5259.0 5258.5 5255.5 5255.0 5249.0 5246.0 5242.5 5242.0 5239.5 5238.0 5237.0 5235.5 5235.0 5228.0 5226.0 5225.5 5221.0 5218.0 5210.5 5205.0 5483.5 5482.0 5474.0 5462.5 5455.5 5448.0 5432.0 5417.5 5403.0 5395.0 5386.0 5376.0 5362.5 5350.5 5342.0 5339.0 5328.0 5321.5 5311.0 5304.5 5297.5 5290.0 5284.0 5278.0 5274.0 5265.5 5260.0 5257.5 5255.0 5248.0 5241.5 5236.0 5234.5 5225.0 5218.0 5209.0 5203.0 30-MAR-1998 14:02 5338.5 5330.5 5321.5 5317.5 5309.0 5300.5 5290.0 5288.0 5284.0 5274.0 5265.5 5257.0 5255.0 5248.0 5244.0 5241.5 5239.5 5237.5 5235.0 5228.0 5225.0 5218.0 ') PAGE: 3 ) ) LIS Tape Verification Listing 30-MAR-1998 14:02 PAGE: 4 Schlumberger Alaska Computing Center 5204.5 5204.0 5200.5 5197.5 5191.5 5192.5 5188.5 5189.0 5188.5 5187.5 5187.0 5184.5 5184.0 5177.0 5175.5 5175.5 5174.0 5163. 0 5160.5 5162.0 5161. 0 5158.5 5156.0 5157.0 5156.0 5156.0 5152.5 5149.0 5152.0 5149.0 5151.5 5152.0 5143.5 5143.0 5143.0 5143.0 5139.5 5139.5 5138.0 5137.5 5133.5 5132.5 5130.5 5130.0 5130.0 5130.0 5130.0 5128.5 5127.0 5127.5 5127.0 5126.0 5124.5 5121.0 5122.0 5119.0 5122.0 5119.0 5117.5 5119.5 5113.5 5113.5 5112.5 5113.0 5112.0 5111.0 5108.5 5108.5 5108.0 5108.5 5108.5 5102.5 5101.5 5101.5 5100.0 5099.0 5094.0 5094.0 5090.5 5089.5 5088.5 5088.5 5087.5 5086.0 5087.0 5086.0 5086.0 5084.0 5085.0 5083.5 5079.5 5079.0 5078.0 5078.0 5076.5 5075.0 5067.0 5069.0 5066.0 5064.0 5064.5 5064.0 5061. 5 5061.5 5053.5 5053.0 5053.0 5053.0 5049.0 5049.0 5049.0 5048.0 5046.5 5045.0 5044.0 5044.5 5044.0 5044.0 5042.5 5040.5 ) ') LIS Tape Verification Listing 30-MAR-1998 14:02 PAGE: 5 Schlumberger Alaska Computing Center 5039.0 5038.0 5038.5 5038.0 5035.5 5035.0 5030.5 5030.0 5026.5 5025.0 5026.0 5025.0 5015.5 5014.0 5014.0 5014.0 5011.5 5014.0 5008.5 5008.0 5007.5 5000.5 5000.0 5000.0 5000.0 5000.0 4998.5 4997.5 4997.0 4992.5 4992.0 4991.5 4992.0 4988.5 4988.5 4986.5 4985.5 4982.0 4982.0 4982.0 4980.5 4980.5 4980.0 4980.0 4976.5 4975.5 4976.0 4975.5 4974.5 4974.0 4972.5 4972.0 4969.0 4969.5 4969.5 4966.5 4966.0 4966.0 4966.0 4966.0 4963.5 4962.5 4962.5 4962.5 4959.0 4957.5 4957.5 4957.5 4952.0 4953.0 4947.5 4947.5 4947.0 4947.5 4942.5 4940.5 4941.5 4940.5 4940.5 4940.5 4929.0 4930.0 4929.5 4927.0 4926.0 4926.0 4926.0 4925.0 4926.0 4921.5 4920.5 4921.0 4920.5 4920.0 4920.5 4916.0 4916.5 4914.0 4914.5 4913.5 4914.5 4910.5 4909.5 4907.5 4907.0 4907.0 4907.0 4907.0 4898.5 4898.0 4898.0 4898.0 4893.0 4892.5 4889.5 4889.0 4889.0 4887.5 4887.0 4887.0 4887.0 -) LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-MAR-1998 14:02 4884.0 4883.5 4883.5 4881.0 4881.0 4881.0 4874.5 4876.0 4869.0 4870.0 4860.5 4862.0 4854.0 4853.0 4849.0 4847.5 4847.5 4845.5 4843.5 4843.5 4841.5 4839.5 4839.5 4839.0 4835.5 4835.5 4835.5 4834.5 4833.0 4829.5 4829.0 4826.5 4827.5 4824.5 4824.5 4822.5 4822.0 4820.0 4820.0 4812.5 4812.0 4811.5 4811.5 4802.0 4802.0 4801.5 4802.0 4798.0 4799.5 4793.5 4791.5 4789.0 4789.0 4788.5 4783.0 4783.0 4777.5 4778.0 4768.5 4769.0 4759.5 4761.0 4756.5 4756.5 4754.5 4754.0 4749.5 4749.5 4745.5 4744.0 4743.0 4741.5 4739.0 4738.5 4736.5 4736.0 4730.5 4732.0 4722.5 4723.5 4700.0 4700.0 4680.5 4679.0 4673.5 4670.5 4672.0 4668.0 4645.5 4644.0 4639.5 4639.5 4631. 0 4632.5 4628.0 4628.0 4626.0 4624.0 4618.5 4618.5 4615.5 4617.0 4607.5 4606.5 4594.0 4591.0 4571.5 4568.0 4563.5 4563.0 4555.5 4555.5 4550.5 4550.0 ) PAGE: 6 LIS Tape Verification Listing Schlumberger Alaska Computing Center ) 4542.0 4535.5 4527.0 4519.0 4517.5 4507.5 4499.5 4492.5 4489.0 4471.5 4462.5 4451. 5 4441.0 4431.0 4425.5 4422.0 4418.5 4416.0 4410.5 4405.5 4392.5 4382.0 4370.0 4363.0 4342.5 4329.0 4324.0 4320.5 4313.5 4303. 0 4297.0 4283.5 4270.5 4264.5 4252.0 4244.0 4235.5 4233.0 4222.5 4219.0 4207.0 4199.0 4195.5 4178.5 4171 . 0 4162.0 4159.5 4152.5 4149.0 4146.5 4143.0 4136.5 4134.5 4129.5 4126.5 4542.0 4535.5 4525.5 4518.5 4516.5 4507.0 4501.0 4493.0 4487.0 4473.0 4461.5 4451.0 4442.0 4432.0 4426.0 4421.0 4417.5 4412.5 4409.0 4402.0 4390.5 4382.0 4369.5 4363.5 4342.0 4330.5 4325.0 4321.0 4313.0 4302.5 4298.5 4284.0 4270.5 4265.5 4252.5 4243.5 4236.5 4232.5 4222.0 4218.0 4207.0 4198.5 4196.0 4178.5 4170.0 4160.5 4158.5 4152.5 4149.0 4147.5 4142.5 4137.5 4134.5 4130.5 4127.0 30-MAR-1998 14:02 ') PAGE: 7 ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 4120.0 4117.0 4114.0 4105.0 4095.0 4075.5 4071.5 4062.5 4059.0 4046.5 4041.0 4036.5 4028.5 4025.0 4017.5 4012.5 4010.0 4001.5 3995.5 3991.0 3985.0 3978.5 3974.0 3968.5 3960.0 3936.0 3932.5 3918.5 3912.0 3903.5 3884.5 3869.0 3866.0 3860.0 3852.5 3849.0 3845.5 3832.5 3827.0 3814.5 3808.5 3802.5 3794.0 3781.0 3778.0 3774.0 3769.5 3759.5 3753.5 3744.0 3742.0 3737.5 3724.0 3718.5 3708.5 4118.5 4116.5 4114.0 4104.5 4095.0 4075.5 4070.5 4062.5 4059.5 4046.5 4040.0 4032.0 4024.5 4022.5 4017.5 4012.0 4010.5 4002.0 3995.0 3990.0 3986.5 3978.0 3975.0 3972.0 3963.0 3935.5 3932.0 3918.0 3912.0 3903.5 3884.0 3868.5 3866.5 3858.0 3852.0 3846.0 3844.0 3833.5 3826.5 3814.5 3809.0 3802.0 3794.0 3780.0 3778.0 3774.0 3771.0 3763.0 3755.0 3744.0 3742. 0 3737.0 3725.0 3717.5 3709.0 30-MAR-1998 14:02 ~) PAGE: 8 ) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3699.5 3695.5 3682.0 3675.0 3665.0 3659.5 3652.5 3648.0 3639.5 3631.5 3623.5 3608.5 3594.5 3590.0 3586.0 3584.0 3577.5 3573.0 3567.0 3561.5 3553.5 3550.0 3544.5 3530.0 3524.5 3509.5 3492.0 3487.0 3484.5 3481. 5 3476.5 3464.5 3460.0 3449.5 3436.5 3435.0 3430.0 3424.5 3420.5 30-MÄR-1998 14:02 3699.5 3697.5 3682.5 3676.0 3669.5 3662.5 3653.0 3648.0 3639.5 3630.0 3624.5 3608.5 3597.0 3587.0 3580.0 3578.0 3572.5 3569.5 3566.5 3563.5 3553.5 3550.0 3545.5 3530.0 3525.5 3510.0 3492.0 3484.0 3481.5 3477.0 3473.5 3460.0 3457.0 3450.5 3438.0 3435.5 3431.0 3420.5 3417.5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 136 4 66 1 5 66 6 73 ') PAGE: 9 IY ) ) LI S Tape Verification Listing 30-MAR-1998 14:02 PAGE: 10 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ 7 65 8 68 0.5 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1197027 00 000 00 0 1 1 1 4 68 0000000000 DT DAS US/F 1197027 00 000 00 0 1 1 1 4 68 0000000000 DTSH DAS US/F 1197027 00 000 00 0 1 1 1 4 68 0000000000 GR CMR GAPI 1197027 00 000 00 0 1 1 1 4 68 0000000000 CFF3 CMR 1197027 00 000 00 0 1 1 1 4 68 0000000000 CFF4 CMR 1197027 00 000 00 0 1 1 1 4 68 0000000000 CFF5 CMR 1197027 00 000 00 0 1 1 1 4 68 0000000000 CFF6 CMR 1197027 00 000 00 0 1 1 1 4 68 0000000000 CMRP CMR PU-S 1197027 00 000 00 0 1 1 1 4 68 0000000000 TCMR CMR PU-S 1197027 00 000 00 0 1 1 1 4 68 0000000000 T2LM CMR 1197027 00 000 00 0 1 1 1 4 68 0000000000 C13 FMI IN 1197027 00 000 00 0 1 1 1 4 68 0000000000 C24 FMI IN 1197027 00 000 00 0 1 1 1 4 68 0000000000 DEV FMI DEG 1197027 00 000 00 0 1 1 1 4 68 0000000000 HAZI FMI DEG 1197027 00 000 00 0 1 1 1 4 68 0000000000 RB1 FMI DEG 1197027 00 000 00 0 1 1 1 4 68 0000000000 TENS CNT LB 1197027 00 000 00 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1197027 00 000 00 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1197027 00 000 00 0 1 1 1 4 68 0000000000 CRAT CNT 1197027 00 000 00 0 1 1 1 4 68 0000000000 GR CNT GAPI 1197027 00 000 00 0 1 1 1 4 68 0000000000 NRAT CNT 1197027 00 000 00 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1197027 00 000 00 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1197027 00 000 00 0 1 1 1 4 68 0000000000 DEV CNT DEG 1197027 00 000 00 0 1 1 1 4 68 0000000000 SP CNT MV 1197027 00 000 00 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1197027 00 000 00 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 1197027 00 000 00 0 1 1 1 4 68 0000000000 NPOR CNT PU 1197027 00 000 00 0 1 1 1 4 68 0000000000 CALl CNT IN 1197027 00 000 00 0 1 1 1 4 68 0000000000 PEF CNT BN/E 1197027 00 000 00 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1197027 00 000 00 0 1 1 1 4 68 0000000000 MSFL SDN OHMM 1197027 00 000 00 0 1 1 1 4 68 0000000000 SCRA DAS 1197027 00 000 00 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center '-' ) ''I J 11 30-MAR-1998 14:02 PAGE: --------------------------------------------------------------------------------------- ** DATA ** DEPT. 5626.000 DT. DAS -999.250 DTSH. DAS -999.250 GR.CMR -999.250 CFF3.CMR -999.250 CFF4.CMR -999.250 CFF5.CMR -999.250 CFF6. CMR -999.250 CMRP. CMR -999.250 TCMR.CMR -999.250 T2LM.CMR -999.250 C13 . FMI -999.250 C24. FMI -999.250 DEV.FMI -999.250 HAZI. FMI -999.250 RB1.FMI -999.250 TENS.CNT -999.250 CNTC.CNT -999.250 CFTC.CNT -999.250 CRAT. CNT -999.250 GR.CNT -999.250 NRAT. CNT -999.250 FCNT.CNT -999.250 NCNT. CNT -999.250 DEV. CNT -999.250 SP.CNT -999.250 NPHI.CNT -999.250 CPHI.CNT -999.250 NPOR.CNT -999.250 CAL1.CNT -999.250 PEF.CNT -999.250 RHOB.SDN 2.332 MSFL.SDN -999.250 SCRA.DAS -999.250 DEPT. 194.500 DT. DAS -999.250 DTSH.DAS -999.250· GR.CMR -999.250 CFF3.CMR -999.250 CFF4.CMR -999.250 CFF5.CMR -999.250 CFF6. CMR -999.250 CMRP.CMR -999.250 TCMR.CMR -999.250 T2LM.CMR -999.250 C13 . FMI -999.250 C24. FMI -999.250 DEV. FMI -999.250 HAZI.FMI -999.250 RB1.FMI -999.250 TENS.CNT -999.250 CNTC.CNT -999.250 CFTC.CNT -999.250 CRAT. CNT -999.250 GR.CNT -999.250 NRAT. CNT -999.250 FCNT.CNT -999.250 NCNT. CNT -999.250 DEV.CNT -999.250 SP.CNT -999.250 NPHI.CNT -999.250 CPHI.CNT -999.250 NPOR.CNT -999.250 CAL1.CNT -999.250 PEF.CNT -999.250 RHOB.SDN -999.250 MSFL.SDN -999.250 SCRA.DAS -999.250 END OF DATA ** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER EDIT . 001 FLIC 001COl 98/03/30 1024 LO **** TAPE TRAILER **** SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENT EDIT 98/03/30 FLIC 98100 1 ARCO ALASKA, KALUBIK #2, WILDCAT, API #50-103-20252-00 it ,_71,.1 ~'."1 LIS Tape Verification Listing Schlumberger Alaska Computing Center ) **** REEL TRAILER **** SERVICE NAME DATE ORIGIN REEL NAME CONTINUATION # PREVIOUS REEL COMMENT EDIT 98/03/30 FLIC 98100 30-MÄR-1998 14:02 -) PAGE: 12 ARCO ALASKA, KALUBIK #2, WILDCAT, API #50-103-20252-00 ) ') Wed Apr 01 16:23:02 1998 qg·o~o ," -::tt:- '3'7-'1 S- ( ONft""'§ , ; . it"' ø ¡f"ìJE'"'" i\gy· !JerAOW'C 11N,,~...q d i ¡tAL " re~l ,70 AAC 25 5 .1¡ Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name....... ... ...LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 9 8 / 04/ 01 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 Da t e. . . . . . . . . . . . . . . . . . . . . 98/ 04/ 01 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: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA KALUBIK #2 501032025200 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 01-APR-98 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-80119 M. GABEL B. HORRISON MWD RUN 3 AK-MM-80119 M. GABEL B. MORRISON MWDRUN 4 AK-MM-80119 M. GABEL B. MORRISON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 15 13N 07E 1099 \,~ ,. .1' 2124 MSL 0) 34.00 33.00 4.50 # WELL CASING RECORD ) ') OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 9.625 2513.0 2526.0 # 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, 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. EXTRA SHALLOW (SEXP) AND SHALLOW (SESP) CURVES FROM ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) SENSOR ARE NOT AVAILABLE FROM MWD RUN 2 DUE TO TOOL FAILURE. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5650'MD, 5649'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. $ File Header Service name.......... ...STSLIB.OOl Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation... ... .98/04/01 Maximum Physical Record..65535 File Type....... ..... ....LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM ROP RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2471.5 2513.0 2513.0 2513.0 2523.0 4737.0 4737.0 STOP DEPTH 5596.5 5606.0 5606.0 5606.0 5648.5 5606.0 5606.0 # BASELINE CURVE FOR SHIFTS: ) ) CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 2471.5 2481.0 2485.5 2498.0 2506.5 2509.5 2512.5 2514.0 2517.0 2518.5 2520.5 2522.5 2525.0 2539.5 2547.0 2555.0 2557.0 2558.0 2559.5 2585.0 2588.5 2591.0 2636.5 2639.5 2640.5 2691.0 2696.5 2699.5 2707.5 2710.0 2717.0 2723.5 2726.5 2729.0 2733.5 2738.0 2751.0 2755.5 2758.0 2762.0 2764.0 2766.5 2769.5 2770.5 2776.0 2780.0 2782.5 2784.0 2786.5 2789.5 2792.5 2797.5 2803.5 2805.0 2807.0 2808.5 2811.0 2813.0 GR 2475.0 2484.5 2488.5 2500.5 2509.0 2512.5 2514.5 2517.5 2519.0 2520.5 2523.0 2525.5 2527.0 2542.5 2550.0 2556.5 2558.0 2560.0 2561.5 2587.0 2590.0 2592.5 2642.5 2644.0 2645.0 2695.0 2699.5 2702.5 2710.0 2712.5 2719.0 2727.5 2729.0 2729.5 2735.0 2741.0 2755.5 2759.0 2760.5 2764.5 2767.5 2769.5 2771.5 2772.5 2778.5 2781.5 2783.5 2786.0 2787.0 2791.5 2793.0 2799.0 2804.5 2807.0 2809.0 2811.5 2813.0 2815.5 ') ) 2816.0 2818.0 2818.0 2820.0 2821.0 2823.5 2824.5 2826.0 2829.0 2831.0 2831.5 2833.5 2834.5 2836.5 2836.5 2839.0 2840.0 2843.5 2841.0 2845.0 2844.0 2846.0 2848.0 2850.5 2851.0 2853.0 2853.5 2856.0 2856.5 2858.5 2858.5 2859.5 2865.0 2867.0 2867.0 2868.5 2869.0 2870.5 2870.5 2872.0 2872.0 2873.5 2875.0 2876.5 2880.0 2880.5 2885.0 2887.0 2887.0 2889.0 2895.0 2896.5 2898.0 2899.0 2903.5 2905.0 2905.0 2906.5 2906.5 2907.5 2913.0 2915.0 2919.0 2921.0 2926.0 2928.0 2933.0 2934.5 2939.0 2941.0 2940.5 2942.0 2944.0 2945.0 2949.0 2952.0 2961.5 2964.5 2969.0 2973.0 2972.0 2977.0 2973.5 2978.5 2975.5 2979.0 2980.0 2982.0 2989.5 2991.0 2992.5 2995.0 3001.5 3004.5 3018.0 3020.5 3021.0 3022.0 3060.5 3061.0 3064.0 3065.5 3065.5 3066.5 3066.5 3067.0 3068.5 3068.5 3072.5 3073.0 3076.5 3076.5 3081.5 3082.5 3084.0 3084.0 3098.5 3100.0 3102.5 3105.0 3108.0 3108.5 ) ) 3110.0 3112.0 3111.5 3113.0 3114.0 3115.0 3116.0 3119.5 3118.0 3121.0 3119.0 3122.0 3122.5 3124.5 3127.5 3128.0 3129.0 3129.5 3141.0 3141.5 3148.5 3149.5 3151.0 3151.0 3173.0 3172.5 3179.0 3182.5 3188.5 3190.0 3226.5 3226.0 3237.0 3239.0 3247.0 3249.5 3309.5 3309.5 3316.5 3318.5 3407.0 3407.5 3408.5 3408.0 3410.0 3410.5 3451.0 3452.0 3494.0 3496.0 3497.0 3498.5 3499.0 3500.0 3522.0 3523.5 3523.5 3527.5 3525.5 3528.0 3529.0 3531.0 3533.0 3533.5 3546.0 3549.0 3555.5 3557.0 3563.0 3564.5 3570.5 3574.5 3583.0 3587.0 3606.5 3607.5 3608.5 3610.0 3610.5 3610.5 3614.5 3613.0 3707.5 3708.0 3709.0 3709.0 3711.0 3711.5 3740.0 3741.0 3742.0 3743.0 3744.0 3745.0 3792.5 3794.0 3794.5 3796.0 3796.5 3799.0 3820.5 3822.0 3822.0 3823.5 3826.5 3828.5 3846.0 3847.5 3848.5 3850.0 3856.0 3859.5 3860.5 3864.0 3867.0 3867.5 3872.0 3872.5 3978.5 3979.0 3979.5 3981.0 ) ) 3983.0 3984.0 3986.5 3988.5 3988.5 3990.0 3994.0 3995.5 4000.5 4001.5 4002.0 4003.5 4012.0 4014.0 4017.5 4018.5 4042.5 4042.5 4044.5 4045.0 4046.5 4047.0 4048.5 4048.5 4058.0 4057.0 4059.5 4060.5 4062.5 4064.0 4065.0 4066.5 4085.5 4086.5 4094.5 4096.0 4100.0 4101.0 4102.5 4103.5 4108.5 4109.0 4110.0 4110.5 4112.0 4113.0 4114.0 4115.5 4116.5 4118.5 4118.0 4119.0 4149.0 4149.5 4152.0 4153.0 4154.5 4155.0 4157.0 4157.5 4178.5 4179.5 4229.0 4229.0 4235.0 4235.5 4300.5 4301.0 4302.5 4303.0 4305.5 4304.0 4319.0 4319.5 4321.0 4321.5 4625.0 4626.5 4628.0 4628.0 4630.5 4630.5 4787.5 4787.5 4789.0 4789.0 4791.0 4790.5 4876.5 4877.0 4881.0 4882.0 4883.5 4884.0 4887.0 4887.5 4889.0 4889.0 4896.0 4897.0 4898.0 4897.5 4900.0 4899.5 4905.0 4905.5 4907.0 4907.5 4909.5 4911.0 4914.0 4913.5 4916.5 4915.0 4918.0 4917.5 4920.5 4920.0 4940.5 4941.5 4945.5 4947.0 4947.5 4957.0 4962.5 4966.0 4969.0 4972.0 4980.5 4982.0 5035.0 5038.0 5044.0 5046.5 5048.0 5049.5 5051.5 5053.0 5122.0 5127.0 5130.0 5132.0 5141.5 5252.0 5255.5 5256.5 5262.0 5265.5 5270.0 5274.0 5276.0 5303.0 5305.0 5307.0 5309.0 5321.0 5395.0 5432.5 5490.0 5496.0 5507.5 5525.5 5526.5 5531.0 5538.5 5539.5 5555.5 5560.5 5562.5 5578.5 5579.5 5582.0 5648.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: ') 4948.5 4958.5 4964.0 4967.0 4970.5 4973.5 4981.0 4983.0 5037.0 5038.5 5045.5 5047.5 5049.5 5052.0 5053.0 5053.5 5122.0 5125.0 5130.5 5133.0 5142.5 5250.5 5254.5 5257.0 5261.0 5264.5 5270.0 5273.5 5274.5 5304.5 5306.0 5308.0 5308.5 5321.5 5394.0 5431.0 5490.0 5495.0 5507.0 5524.0 5525.5 5529.5 5536.5 5538.0 5554.5 5559.5 5561.0 5578.5 5580.5 5583.0 5649.5 BIT RUN NO 2 3 4 MERGED MAIN PASS. MERGE TOP 2526.0 4792.0 4950.0 ) MERGE BASE 4792.0 4950.0 5650.0 ) ) $ # 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 .1IN Max frames per record............ . Undefined Absent value... ................. ..-999.25 Depth Units.... ...... ............. Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 2471.5 5648.5 4060 6355 2471.5 5648.5 ROP 12.927 580.443 182.107 6252 2523 5648.5 GR 27.5612 190.181 105.895 6251 2471.5 5596.5 RPX 1.7925 31.1431 3.47619 1739 4737 5606 RPS 1.8022 32.1993 3.50446 1739 4737 5606 RPM 0.3191 2000 3.4841 6187 2513 5606 RPD 0.3698 2000 4.68818 6187 2513 5606 FET 0.0656 38.4541 0.738788 6187 2513 5606 First Reading For Entire File. ....... ..2471.5 Last Reading For Entire File... ...... ..5648.5 File Trailer Service name.... ........ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation... ....98/04/01 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.... ...98/04/01 Maximum Physical Record..65535 ) File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM ROP $ 2 ') header data for each bit run in separate files. 2 .5000 START DEPTH 2475.0 2515.0 2515.0 2515.0 2526.0 STOP DEPTH 4739.5 4749.0 4749.0 4749.0 4791.5 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 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): 12-FEB-98 5.07 5.46 MEMORY 4792.0 2526.0. 4792.0 .0 .0 TOOL NUMBER P0942CGR6 P0942CGR6 8.500 8.5 LSND 9.30 42.0 9.0 1450 12.4 2.200 1.830 1.400 2.800 111.0 ) ') # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction......... ...... ..Down Optical log depth units.. ........ . Feet Data Reference Point.... ........ ..Undefined Frame Spacing.. .... ....... ...... ..60 .1IN Max frames per record. .......... ..Undefined Absent value...... ... ...... ...... .-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 RPM MWD 2 OHMM 4 1 68 8 3 RPD MWD 2 OHMM 4 1 68 12 4 ROP MWD 2 FT/H 4 1 68 16 5 FET MWD 2 HOUR 4 1 68 20 6 First Last Name Min Max Mean Nsam Reading Reading DEPT 2475 4791.5 3633.25 4634 2475 4791.5 GR 27.5612 190.181 107.937 4530 2475 4739.5 RPM 0.3191 2000 4.00284 4469 2515 4749 RPD 0.3698 2000 5.39771 4469 2515 4749 ROP 24.2762 592.643 202.983 4532 2526 4791.5 FET 0.238 2.1913 0.469864 4469 2515 4749 First Reading For Entire File.. ...... ..2475 Last Reading For Entire File.... ..... ..4791.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...98/04/01 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...... .98/04/01 ') Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX FET RPD RPM ROP $ 3 ) header data for each bit run in separate files. 3 .5000 START DEPTH 4732.0 4737.0 4737.0 4745.0 4745.0 4745.0 4790.0 STOP DEPTH 4930.0 4939.5 4939.5 4939.5 4939.5 4939.5 4950.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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 13-FEB-98 5.07 5.46 MEMORY 4950.0 4792.0 4950.0 .0 .0 TOOL NUMBER P0946CGR6 P0946CGR6 8.500 8.5 LSND 9.30 42.0 9.0 1450 12.4 2.300 2.020 1.200 2.700 107.0 ) ) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units... ....... .Feet Data Reference Point....... ...... . Undefined Frame Spacing.................... .60 .1IN Max frames per record.... ........ .Undefined Absent value..................... .-999.25 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1· 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 FET MWD 3 HOUR 4 1 68 24 7 ROP MWD 3 FT/H 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 4732 4950 4841 437 4732 4950 GR 78.0362 144.383 109.425 397 4732 4930 RPX 1.7886 5.4601 2.47028 406 4737 4939.5 RPS 1.8099 5.6327 2.5001 406 4737 4939.5 RPM 1.8346 5.3835 2.45486 390 4745 4939.5 RPD 1.8736 5.5127 2.51949 390 4745 4939.5 FET 0.0656 10.5516 2.67663 390 4745 4939.5 ROP 12.927 309.668 93.1035 321 4790 4950 First Reading For Entire File........ ..4732 Last Reading For Entire File.......... .4950 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .98/04/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 ) Physical EOF File Header Service name....... ..... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .98/04/01 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 4 ) header data for each bit run in separate files. 4 .5000 START DEPTH 4884.0 4935.0 4935.0 4935.0 4935.0 4935.0 4950.0 # 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 VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 5597.5 5607.0 5607.0 5607.0 5607.0 5607.0 5649.5 15-FEB-98 5.07 5.46 MEMORY 5650.0 4950.0 5650.0 1.0 1.1 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 TOOL NUMBER P0946CGR6 P0946CGR6 # 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): 8.500 8.5 LSND 9.50 50.0 9.5 1100 5.2 ) ') RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2.100 1.630 1.300 2.600 117.0 # 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 .1IN Max frames per record... ....... ...Undefined Absent value............... ...... .-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam Reading Reading DEPT 4884 5649.5 5266.75 1532 4884 5649.5 GR 47.7929 145.598 98.6497 1428 4884 5597.5 RPX 1.7341 31.1431 3.79713 1345 4935 5607 RPS 1.7463 32.1993 3.82698 1345 4935 5607 RPM 1.7839 32.623 3.68352 1345 4935 5607 RPD 1.8803 27.5704 3.69692 1345 4935 5607 ROP 31.8389 379.336 133.502 1400 4950 5649.5 FET 0.3625 39.8469 1.44603 1345 4935 5607 First Reading For Entire File..... ... ..4884 Last Reading For Entire File.......... .5649.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 ) ') Date of Generation...... .98/04/01 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name... ..... ... ..LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 9 8 / 04/ 01 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 Da t e. . . . . . . . . . . . . . . . . . . . . 98 / 04/ 01 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
