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A:\Nanuk airshot 2.jpg (local) - Microsoft Internet Explorer Page 1 of 1 V.COv DOO°-O APR 1 2 2011 8/22/00 9:22:21 AM � A : \Na a Q36o jpg (local) - Microsoft I Internet Explorer � Page 10 / \� \\ � < 8/22/00 9:25:06 A Re: Nanuk (Nanuq) 2,--issue closed ) ') Subject: Re: Nanuk (Nanuq) 2--issue closed From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 16 Nov 200409:38:43 -0900 To: Rob Mintz <robert_mintz@law.state.ak.us> CC: dan - seamount@admin.state.ak.us, jack - hartz@admin.state.ak.us, john - norman@admin.state.ak. us, steve - davies@admin.state.ak.us dOO- a~O Rob, Following your last note, I contacted Paul Mazzolini regarding the confidentiality request as noted in their transmittal letter. transmittal letter and not edited the confidentiality statement. He has sent a revised letter. Thanks for the help. Tom He indicated that they had used their standard Rob Mintz wrote: Tom, if! understand the situation correctly, the newly submitted information is information that was required to be submitted within 30 days from the completion, suspension, or abandonment of the well, and the confidentiality period for all such information has expired. If that is the case, then clearly you are correct and the newly filed information cannot be held confidential. If it could, then that would be an incentive for operators to be late in their required filings. »> Thomas Maunder <tom maunder(ai.admin.state.ak.us> 11/15/2004 11:00:20 AM »> Rob, Here is a message trail regarding a request to CPAI to fill in a "hole" in the information submitted for this well. A customer had been examining the electronic version of this well file and returned with some questions. After researching the file, it was apparent that there was about a 3 week period of the testing operations that were not covered in the material submitted. I requested that CPAI provide the missing information according to 20 AAC 25.071 (b)(8)(A) and (B). CPAI recently submitted the requested information, however in their transmittal letter they requested that the submitted information be held confidential due to the exploratory nature of the well. I don't believe that we can honor their request. The well was P&Aed 5/7/00 which would have established a release date of 6/7/02. On 5/30/02 the information was given extended confidentiality until 11/22/02 which was 30 days following the next scheduled lease sale. The well information was released as scheduled and has been in the public domain for nearly 2 years now. Could we get your "read" on this. I would propose to prepare a response letter to CP AI acknowledging receipt of the information, but notitying them that their request for confidentiality is not honorable since the remainder of the well information has already been released and no further request regarding the confidentiality of any of the well information was received prior to 11/22/02. Thanks Rob. Tom -------- Original Message -------- Subject:Re: Nanuk (Nanuq) 2--PTD 200-030 Date:Wed, 03 Nov 2004 08:57:37 -0900 From:Thomas Maunder <tom maundert.â1admin.state.ak.us> Organization:State of Alaska To:Mazzolini, Paul <PauLMazzolíni@~conœophiJlips.com> References:<FB8E6.EC6316A4A4EA003114121588ACC6D21:1F(li).ancexmb I.conoco.net> Thanks Mazz. I haven't checked the other files. I will have a look, but as I noted in my original message there appears to be a "hole" in the information for Nanuq #2. I will get back to you. Tom Maunder, PE AOGCC Mazzolini, Paul wrote: >Tom, I got your email and started looking at the well file to see what info has been sent. Our well file shows that we sent all required ir: > >We can make another copy of the info if it can not be found. > >Let me know. > > >Regards, > >Mazz > >- - - --Original Message- ---- >From: Thomas Maunder [mailto:tom maunder@admin.state.ak.üs] >Sent: TUesday, Novembei'--Ö'2';-"-2'ÖÕ4-ä-;sõ"-ÄM--"""-------"----"""""'------'.- >To: Mazzolini, Paul >Cc: Steve Davies >Subject: Re: Nanuk (Nanuq) 2--PTD 200-030 > > >Paul, >Just checking on this message if you received it. I did not send the >original wi th a return receipt. >Tom > >Thomas Maunder wrote: > > > »Þaul. »Due to a recent customer request, a review of the subject well file »was conducted. That review has determined that the information filed »with the Commission is incomplete with regard to the testing »activities that were conducted on this well. Nanuq 2 was tested in 2 »intervals over nearly a 3 week period and the information submitted »:Eor these operations is comprised of a 1 page stimulation report on ».Äpril 16 and some flow rate information provided on the bottom of the »completion report (Form 407) . »20 AAC 25.071 (b) (8) (A) and (B) requires the operator to submit (within »30 days unless a longer time is approved) more complete information »with regard to well testing. ConocoPhillips should provide such »information as soon as practical. In this particular well, the SCANNEC> NOV 2 3 2004 10f2 11/16/20049:39 AM Re: Nanuk (Nanuq) 2--issue closed ) ) »operations time period in question begins with the rig release on »April 11, 2000 and continues through the beginning of plug and abandon »activities on May 3, 2000. »Your timely attention to this matter will be appreciated. Please call »or message with any questions. »Tom Maunder, PE »AOGCC » » 2 of2 11/16/2004 9:39 AM ) ) Paul Mazzolini Exploration Drilling Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 November 15, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 NOV 1 2004 Subject: Nanuk #2 (Permit # 200-030) Addition to Completion Report Dear Commissioner: ConocoPhillips Alaska, Inc. as operator of the Nanuk #2 exploration well, submits the enclosed reports per your request. The Completion Report (10-407) has also been revised. The attachments include the RFT test results, test operations log, gas flow rate report, graphs, oil flow rate report and gas and oil sample reports. Sincerely, ?~ f1~'- ' - P. Mazzolini Exploration Drilling Team Leader CPAI Drilling PM/skad ) ConocóP'hiiii ps November 10, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ) Paul Mazzolini Exploration Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 9951 0-0360 Phone: 907-263-4603 Subject: Nanuk #2 (Permit # 200-030) Addition to C pletion Report Dear Commissioner: ConocoPhillips Alaska, Inc. as operator of th anuk #2 exploration well, submits the enclosed reports per your request. The ompletion Report (10-407) has also been revised. The attachments include th RFT test results, test operations log, gas flow rate report, graphs, oil flow rate rep rt and gas and oil sample reports. AOGCC is requested to keep confid tial the enclosed information due to the exploratory nature of this well. If have any questions regarding this matter, please contact me at 263-4603 ^ .~ 'I LßJ~ <Ç ,\ \ J A^& ^ "J':::>" 'fJJ 'fl \ Sincerely, P. Mazzolini Exploration Drilling CP AI Drilling PM/skad .--... ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 22. Type Electric or Other Logs Run Neutron/Density/4_phase Resistivity/GR, PEX/CMR, DSI, FMI, RFT, USIT/GRlCCL, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 2219' Surface 9105' 1. Status of well Suspended D Abandoned 0 Service 0 anD GasD 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 465' FNL, 864' FEL, Sec. 25, T11 N, R4E, UM (ASP: 377335, 5954678) At Top Producing Interval . 1172' FNL, 3718' FEL, SEC 25, T11 N, R4E, UM (ASP: 374470,5954017) AtT otal Depth 1172' FNL, 3718' FEL, SEC 25, T11N, R4E, UM (ASP: 374470, 5954017) 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKB 28 & Pad 11' ADL 354209 ALK 4700 . 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. March 24, 2000 April 1, 2000 5/7/2000 Abandoned 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 9112' MD /8241' TVD 9024' MD /8154' TVD YES 0 No 0 CASING SIZE 16" 9.625" HOLE SIZE 20" WT. PER Fr. 62.5# 53.5# 29# GRADE B L-80 L-80 12.25" 8.5" 7" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 7048'-7108' MD 6178'-6238' TVD 5 spf 7948'-7962' MD 7077'-7091' TVD 6 spf Classification of Service Well 7. Permit Number 200-030 1 300-118 8. API Number 50-103-20332-00 9. Unit or Lease Name Colville River Unit 10. Well Number Nanuk #2 11. Field and Pool Exploration 15. Water Depth, if oftria.:' (ï~,. ~ t\C~, ' !~ NI A feet MSL i::: ":",.# c: d V C U 20. DePt~:ere SSSV set feet MDN 0 "Ì T~~~lM :~mafrost Al~$k~ & Commission CEMENTING RECORD 200 cu ft. AMOUNT PULLED 397 sx AS III LW, 350 sx Class G 198 sx Class G Lead, 245 sx Class G Tail 3.5. cement plug @ 6707' MD set bridge plug @ 334' RKB TUBING RECORD DEPTH SET (MD) 6906' PACKER SET (MD) 6791' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7048'-7108',7948'-7962' FRAC: 293550# of 16/20 behind pipe with 12 ppa on formation. Left 2450# prop in wellbore bridge plug: 12.75 bbls AS I cement Plug #1: 113 bbls Class G 26. 27. Date First Production April 19, 2000 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Abandoned Production for OIL-BBL GAS-MCF 533 306 OIL-BBL GAS-MCF 740 NI A CORE DATA 4/19-24/2000 133 hrs Flow Tubing Casing Pressure press. 350 Psi 655 28. Test Period> Calculated 24-Hour Rate> WATER.BBL 869 WATER.BBL CHOKE SIZE 48/64 OIL GRAVITY - API (corr) 390 GAS-OIL RATIO 575 SCF/STB Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. 935 To be sent under separate cover Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. ') GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME RFT Tests: see attachment for details refer to attachment Wellbore P&A'd 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Geologic Tops, Time and mud weight chart, memo of abnormal pressure, as-built 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ?~0~ Paul Mazzolini Title Exploration DrillinQ Team Leader Date / (I/o ! ~()O4 Prepared by Sharon Allsup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate Rnonen. Form 10-407 ) Nanuk 2 RFT MW = 9.7 ppg Mud Grad. & MW 0.511 . 99.035 . 9.839 Hydrostatic Depth SSTVD Before After Formation Mobility 4800.02 4063.08 2158.58 2157.97 1873.5 10.7 7047.96 6137.22 3247.87 3246.1 2739.51 2.2 7064.99 6154.25 3253.11 3252.86 Bad test, Pressure Falling off 7063.88 6153.13 3251.36 3251.09 2742.21 1 7064.02 6153.27 3250.88 3250.69 2739.69 4.81 7074.96 6164.21 3256.55 3256.11 2741.26 5.52 7096.02 6185.26 3267.28 3266.95 2751.52 3.43 7121.03 6210.26 3280.1 3279.64 2774.86 2.03 71 21.48 6210.7 3279.84 3279.39 2773.39 1.67 7141.48 6230.7 3289.81 3289.84 2766.95 1.78 7142 6231.2 3290.3 3289.7 Tite 7143 6232.22 3290.55 3290.38 2767.52 3.94 71 65.02 6254.23 3302.07 3301.65 2781.41 1.88 7200.1 6289.3 3320.8 3319.6 Tite 7200.5 6289.7 3320.2 3320.1 Tite 7634.9 6764.3 3546 3545.4 Tite 7645 6774.4 3550.8 3549 Tite 7658 6787.4 3357.4 3357.6 Tite 7964.01 7053.06 3714.86 3714.44 3298.14 408.86 7961 7050.05 3711.09 3711.1 3236.26 20.8 7966.5 7054.5 3714.4 3714 Tite 7967.94 7056.99 3714.79 3714.6 3238.75 30.5 8303 7392.3 3885.9 3885.2 Tite 8309.21 7398.25 3888.56 3888.01 3337 2.04 8319.6 7408.6 3892.2 3892.6 Tite 8321 7410 3893.6 3893.1 Tite Samples 8309.2 Open 2 3/4 gal. For 1 hr 27 min, close @ 945 psig, get stuck. Formation pressure = 3337 (Alpine) 620 psig @ surface. Recover 300 cc bottle of gas at pressure. Dump 2.6 ft3 gas and 8250 cc liquids, approx 750 cc oil. 7964 Open 2 3/4 gal. For 1 minute, close @ 3226 psig. Mobility 367 md/cp. Formation pressure = (Kuparuk) (Surface pressure registered 1350 psig?? Gauge suspect.) Dump 5.9 cU.ft gas, 10000 cc liquid & foam (2200 cc oil & foam.) Filtrate very emulsified. 3239 (K-2) 4802 Open 1 gal. For 39 minutes, close @ 445 psig. Mobility 8 md/cp. 330 psig @ surface. Recover 300 cc bottle, though valves and fittings very oily. Dumped 0.1 cU.ft gas, 2500 cc oil, no water. Had to poke around to find any permeability. Formation pressure = 1873 ) Nanuk #2 RFf Tests ) RFf Tests: K-2 4802 Open 1 gal. For 39 minutes, close @ 445 psig. Mobility 8 md/cp. 330 psig @ surface. Recover 300 cc bottle, though valves and fittings very oily. Dumped 0.1 cu. ft gas, 2500 cc oil, no water. Had to poke around to find any permeability. Formation pressure = 1873. API gravity = 27.3 Kuparuk 7964 Open 2 % gal for 1 minute, close @ 3226 psig. Mobility 367 md/cp. (Surface pressure registered 1350 psig ?? Gauge suspect). Dump 5.9 cu.ft gas, 10000 cc liquid & foam (2200 cc oil & foam.) Filtrate very emulsified. Formation pressure = 3239. API gravity = 37.3 Alpine 8309.2 Open 2 % gal. For 1 hr 27 min, close @ 945 psig, get stuck. 620 psig @ surface. Recover 300 cc bottle of gas at pressure. Dump 2.6 ft3 gas and 8250 cc liquids, appro x 750 cc oil. Formation pressure = 3337. API gravity = 40.2 Nanuq #2 Testing Results Fracturing Treatment Design . Completed Well with 3-1/2" Tubing, Perforated Top 50' of Nanuq . Objective was to Place a Large Fracture in the Nanuq . Treatment Not Designed for an Aggressive Tip Screen-Out . Estimated Less Than 500 PSI Net Pressure Build .~ ajb 8/00 Nanuq #2 Testing Results Com:) etion Sc 1ematic -¡ ~ , t r } I~ . ~,',.,',,:,,'.,',.":.,',.' ".:..,"-,-,:,:,,',. .,..,,1.,.,1 : 9--5/811 36 ppf J--5S BTC ~ . i-¡ ':: Surface Casing : ; n : : :: f-t ,': : GLM's 1 & 2 . t '~' :ii : f,':,:',::.,' ,'."".,;," j : t .¡ i IT ~ 7" X 3-1/2" Perm. Packer '-" Nanuq IntelVal Kuparuk Interval ¡~~ 711 26 ppf L-80 BTC Mod Production Casing ajb 8/00 Nanuq #2 TestinQ Results Open Hole Log Section NANUK 2 Nanuk Interw1 ~-~ Alaska . PHllllPSJ Exploration {Ðt ;,":;-:_fJ'~~~'1 !f/~i:!-~~i~'~- Nanuk Interval 50-103-20332-00 '-"'. hI] :+- C'DrtI PHI R:.:T 1!1!1 On rtI. PEm.. . o C:~ R.~;TIM :+ '" '" n 0.1 8'1\' \fl'ol RlliH~" PHI ... II OH.C¡},L 1 ;TE"::::::~M:I~:?,~<~i:":':';: 6n f\::T n n 1 &" - - iÑ - - IZ . . ~.. D Dep'" ------,~~ T u t.!¡ -'"..----. . ~..- --"- , ...' ¡j,B 'rJ',rI," r.¡ 0.1 f") Ii .O~ VBM .' .~., . ..~... "...' -,.-,_. !I.1 Resistivity logs 100 :!iI!: ~ c( '11.111 == RDb~'.PERM ....= ~H.AH¡;;-;''''~:1ØJ :> ; M 0 * 1DD ~ Z' '. "'Òií";M¥""~ . 6~ Mcdt'J PERM 0 H..o. " FIID "'it-!' - ',,=, --."" , ,'" ; ~- - - - - " '- ¡~"- ~~-,~;-~:... -f 'iIC;.'~ ~ j~~,~a::~~:~:, ~~~-' .t.' ,-=--- ..~ '¥ . . hvulon ~. '- -~~~~i---.. .¿-~-- Proll. T' . ----.-.---.--.... -!E~: 1.1[0 p. r"T .~;~ ()8! !_1T '¡' .}~ ~ n t3.IÌ,f{ Ifin' ~-rl~!- Jtj:.?~:~~:~:~~-;:.~: , '.-1 ,'" ::¡-~: : : :':,:':: .,.. J- ~~--= f~*¡i[lt¡::~mm- ..mt -I--~--- .!.\'~~.....,... ~- f~:'~! :- ~~~mljI~ ~-æ'-- ~.;.":"",,;, -:--:-,", ".~ æ"" .... t 'r~~= ~s~¡¡n~u~ L_r:--- ;::::.;.f-#.m:::: : : ¡= t-tc- ~~;;¡~j~~ om .3m ~!--t-vr-- ~~-""--~~-'-:~~~:;:l , . ~/ ajb 8/00 Nanuq #2 Testing Results /:-~ Alaska PHilliPS ~¡ Exploration ~ 1 :"",::',.:.~.;c",:,.: " Open Hole Log Section - Kuparuk Interval NANUK 2 60-103-20332-00 Kuparok Interval 60 BW I 'lfN D Robf':' PHI .. fDT PHI 111111 'lfM PI1 nõ ... :w: c - -< HJ!JJ = ~ ~~;H;iJR::~~ Wi!! oe: 1 0 "MM 70ft ROT -".RV. PERU ON.AN F!lD -~ .~. -~:~-2:0 ,) o 10m '1 ~ - - - - - - - - 2iin - ~ ß~v~i~;.---~' -e--~-----:- Æ~. .---..'.,.,. :-:-'-~-::-;'j;! t'~. '*- ~~.- , ~,..... -) :'- " -~~~.::-" -'--- - -- -~-a- ' ---.- COM ,~. ¡; T 1M 0 H.C.lU 1 g - ~.7~~.' - -~ ~... ~'- ,VIR :.:;;~.:;.""~ ~D D.~~~ 0.6 . ...c:r-~.-. .' - '0. IJ C<A!~ h1)' r i-------ill)" [ .¡ P FT.?J 0 f~! ! rr y ~ 'Õ ~~ -. :~i: I~~~~;7~~;~~ U_-_...:- ~,' ~, ~'~:'. ',- .',';"" ...~. , ": - ","t;~ '_"'~f:..~'L':::'--~:"':.t:-.~;~. :: ~ :} ...-:-.__.;-;o-.',-:-;...._~~._.,~::--- ~-~ 1!!I!!IJ 1D!iD ~ ~' ajb 8/00 Nanuq #2 TestinÇJ Results & - Î Alaska /PHILLIPS) Exploration ~' y.-.. -~}7~1 ~. !~-~Ç.' ..:t..1'~~. :" Fracturing Treatment Execution . Pumped Breakdown and Data Frac Which Indicate Minor Perforation Friction and NWB Pressure Losses, Slightly Higher Than Expected Permeability from the Leak-Off Co-Efficient ~' . Left Pad Size at 800 Bbls and Added FLA's to Control Spurt Loss . Pumped Main Treatment at 30 BPM with Treating Pressure of 3,200 PSI During the Pad . Possible TSO Response in Middle of Sand Stages Which Turned Out to be Increasing Tubing Friction ajb 8/00 Nanuq #2 Testing Results ~'-- ~ ~ Alaska . PHilLIPS ~~' Exploration ~. Fracturing Treatment Execution :cont.: . Had Difficulties with Gel Quality Due to Low Water Tank Temperature ~' . Built Only 250 PSI of Net Pressure During Treatment . Flushed Treatment to Completion and Placed 296,000 lbs Proppant in the Formation with 12 PPG Concentration at the Perforations ~ ajb 8/00 0 0 tV 0 ~. VJ (j 0 ~ ::s 0 ....-- "'0 ~ "'0 p:¡ u (JQ ...... '-' 0\ (þ I 0 ""-- 0.. cr' (j (!) "'0 V 0 S ::s '-' ....-- o?O "'0 0 "'0 (JQ '-' 0 0 ........ tV 0 _. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . V'I . . . . . 0 .'.. .... ......... ........ ..: ..... .... ........ ...:.... .... ......... ... -:-.. ........ ....... . ._~;M'i,l_~~..~-.-_",.""'-; I .~ ~... . . . . . . . . . . . . . . . : : : : : tV . . . . . 0 .........~.........................................~....... ...........-......................................... 0 ! J! ¡'M~U. ! ¡ 4j : ..... .,.."'................... ........ ............ . '_liìil..ÌI."~_I'~~_' "",..,.....""¡Vi&,'....,"".r"'" . ä. 1 0 ;C- ...11. ..~.iWI."" 0 \h: . -~ ..'~ V:- -. : : : ' '. \...,: : : : - . /I ~ .... ... ~... ... .... ..~. ;....~:.-.,.;, ~..,.,.t..~, A___- 4. ;~un- - _Wi.- A .A\.\À. .i... Ii ..~.;." 11." .1~'iI.'.1.iiìi!~ II. .~~:~~~~~. ~.. :., g 0 :.: : : : 0 . . . . . . . . . . . ... . . . V'I .....................:....................~....................:..................... "0 . . . . . . . . 0 . . . . . . . . . . . . . . . . . . . . I ...~ ". H u \' L ~ .. -. ~ ,- t-, \ ~"" o. - ~ ; . . . . . . . . . . . . . . . . . . . . . . . . -...J . . . . . 0 ....:....................:....................~....................~....................:...................8. C) : : : : : 0 . . . . . . . . . . . . . . . ~ ~ ~ ~ ~ Z# ){nUUN 00/8 qçu VJ V'I ....... 0 '~~ Wii. '-~dl1~IH~. 98 ZL (U!w) ~UI!..L 8Ç -j~ OJ Ea 6Z tV ,.. o.£' VJ V D~ + ::I:: '< 0.. ""I 0 ....-- "'0 VJ _. vr'-' I -- ~ 0\ ~.H ,., g 0 w~ ....-- "'0 VJ '-' SllnS8tJ 5u!Jnl~eJ.::I UO!1U1Oldx3 U~SUIV SllnS8}:J ÖU!lS8..L "G# bnUBN Nanuq #2 TestinÇ) Results - ~ - Initial Nanuq Flow Test . Performed a Coiled Tubing Clean-Out 24 Hours Post-Frac, Recovered Heavy Unbroken Frac Gel ~' . Opened Well to Production at 1 AM on April 19th . Started N2 Lift and Had Difficulty Maintaining Flow, Unloading More Unbroken Frac Gel . Called Out CT to N2 Lift Well from Bottom, Finally Cleared Out Unbroken Gel .~' . Initial Rate 1,700 BFPD at 60% WC, 800 GaR, 39° API Oil ajb 8/00 Nanuq #2 Testing Results ~.., ". t~. '.'\ ( ~ ~~w ~«IJ . .-, Initial Nanuq Flow Test :Cont.: . Reinterpreted Oil/W ater Contact on Logs and Core Flourescence Photos . Continued to Flow w/CT and N2 Until Midnight April 21 . Well Continued to Flow Unlifted at 1,400 BFPD, 60% WC, 800 GOR . Flowed Well Until 3 PM April 24 . GOR Increased to 1,300 SCF/STB by the End of the Flow Period .~ . Obtained Separator PVT Oil and Gas Samples ajb 8/00 Nanuq #2 Testing Results 3500.00 3000.00 - 2500.00 ... 'C C. .c cD - 1! 'C 2000.00- 'S g 'C c: ~ 1500.00- .!! ca ~ 'õ 1000.00 - 500.00 - 0.00 0 Shut-in for Nanuq zone PBU , . r. .:~:.~ ~~., ':~.: ~ ïDJ at1 Nanuq #2 Well Test Oil, Water and Total Liquid Rate Total Liquid, BLPD Water, BWPD Oil, BOPD -GaR NanuQ Zone onlv 6 mD (10O ft total sand), 150 ft fracture half-length, (294,000 Ibs @ 12 ppg) 390 API ~ ~~ ~~,' !i~~ L l.t.r 1- " -~....:~ . t"Jit,{~~1I'~ Nitroaen 11ft WHP = 350 psig I 50 100 150 Elapsed time, hrs ~~~ Alaska PHILLlPS~~f: Exploration Combined Flow Nanuq(500 BO & 1000 BW ) Kuparuk (1250 BO) 400 API -- ...--- )It Kuparuk zone: 9 ft net pay , appx. 100 mD f; , :: '~, ,.. , .. '~ ,¡WHP=450~L 200 250 300 Produced 6000 BO and 6300 BW to Kuparuk ajb 8/00 Nanuq #2 TestinQ Results ~-~ Alaska PHILLIPS I ~}~- Exploration. I I ' Nanuq-Only PBU Test . Rate 1,400 BFPD Avg., 1,800 PSI Flowing PBH . Permeability 5.5 mD A vg (550 mD-Ft) . Skin -5 . Partial Boundary 530' (800' Investigation) .~ ajb 8/00 Nanuq #2 TestinQ Results Alaska Exploration 41»HILUPS'it .., It::!I''fõl-i-lltõ.mil.lll~:l ¡IIj.i~~I r.lml~:Ir£..rollll!jl'.&''.J.tõl':J.~~:" _~~I..1"1.I1..~.(..~r;l(11i1 . .. ,,"....,. ., :;.1~Jxl Ji1~:iF1l:~:r:i::,] ~.,;t.(~;~'h~'1j:~;E<S:'~~"'.,~.''ki!.k ~ l!t ~,ltl. ~;i';~;~¡;;'~~"¡~¡:j¡~'I<j.:~ ~I.~ '. ~.:.t ~...."A~,_1rjl_~.h.)(.\;4~L.:t.S~,<,.l",,~~U,: .J~lp t, A~_"t_J.I;.. I ,. t. .. r.. ...J ., 1~.:.1 ,fL..., J. l:.A.,. ':. b,;.::.:,'.i~.~"::;"" .w~}\'':::;~~'){~~r:~1~¡Y?::>:3f:1~F~':~'(\?~:;~'; ~';~'~':::r:~.s:';~~~:'"~~~:'¡,:;;;;::~,,~;;-'.!'~''' ';-:~;'(}1::¿¡::~::þ'(:';:"7!.>:.:i"<~< "~"". '~'-"" ',' " . '. . Automatic Type Curve Match ---J 10.0000 -::- I . " I I . . I I I , If. I I I, . . I I. I t I '. ~ I I I I ------, , I I I -------- , . I I I I I '!.l I , I I ,/:;" I , 1. 0000 ~- - - - - - - - - - - - - - - - - + - - - - - - - - - - - - - - - - -1- - - - - - - - - - - - - - - - - - ~ - - - - A - - - - - - - - - - - ~ - - - - - - - - -tr - ~ - ~- - - - -g:¿- - - - - -~~~~-=-=: I I I 4-L~ ^ /'t&...A. ------ I I , ~~"-'- ~-~--- I I f I I I , I , !.l I I : : 0 ^!.ll:;__~--f:r~~ l:J.. : : : 0 4:5';"'-, , I ",,- -------!.l l:J.. I I : : ~-ri .--l.>~-"-- l:J.. : : : 0.1000 ;:-----------------¡------------______l ~~i~-~~~--¡--- -------------1-------------!.l----¡~---------------¡ : . -~~.r-----' ð. 4 ; : : I -------~. I I I I . I ...-- I . 1 , I I -.,r_/ I l:J..' I I I - : ....~ -_/-/: : : : l:J.. : t -k--~'-~ I I I . . 0.0100 -::----- -- - --- --- - -- 6~..r'::": - -- -- - --- ---- ~-- - - - -- - -- - ---- - - -~--- ---' ! -..: - l:J.. 0 I : : Fbd.œ C.ùuctivity Fraetu1J : : : : PenMaltiJity þlldl '" 5.517 0.6002 : : : : Fradu'e COJlÒctMty "I - 45.05 121 : : - CÙC1Ilaål4lPn..- : Fraet8re Ila]f:.Lenctlt (81 '" 159.2 22A7 : : - - CÙl:u1aål4lD8ñvailn : Wellbore Stlrar;e (Wt1s,psQ - 0.89 (Fbei) : 0.0010 -=-------------------:----------- ~ =:-:=:. -----:----~--. Easi,NoF1øw (81 '" 533.5 339.7 .--: .. I Ratius oflltwsd¡ation (81 - 779JJ I : ; : 1ÞraiIeJt 05lO2lOO 00:01 :18 : I I I . , I , I . . I I I I I I I I , It. I I Iff I I I t I I I , I I I , , , ,I I I I , , I I ,I I' I I , , , II I I I I I , 1,1 I I I I I I III 'I I I I I "~ 0.010 0.100 1.000 10.000 100.000 1000.000 l:J.. 4) > .¡ > .C 4) 0 1 s: 0 0.0001 0.001 to/CD :Å~~.'::';''-_.:)~''':.'-': ~J .I'..,~. ~. :..-?, ':~~:.:~~~:~,:_-.J ',,"J~>;-":.~:., .-.~;> :.: ',: ' :.: , ;t'~o.oò06832 . ¡X'~ö.œ1~":h~,~3:66 ;-1'(' . ajb 8/00 Nanuq #2 Testing Results ~ - .~ Alaska 4 . PHilLIPS ~t EXPloration~' Dual Zone Flow Test . Underbalance Perforated the Entire 15' C Sand Interval at 1 AM on April 29 . Opened the Well to Production and Saw an Immediate Production Rate Increase - Initial Rate was 1,700 BOPD & 900 BWPD at 450 PSI Wellhead Pressure . Opened Choke from 48/64's to 128/64's and Rate Increased to Nearly 3,500 BLPD '-" . API Gravity Increased to 41 0 ajb 8/00 Nanuq #2 TestinQ Results Alaska ''PHIÛ.IPS) 1 . r¡T¡I , Exp oratIon ~. Dual Zone Flow Test #cont.' " J . Performed Production Logging Profile - Kuparuk 75% of Flow and Nanuq 25% of Flow . Flowed Well for 40 Hours and Shut-In . Total Production for Both Tests was 6,000 BO and 6,300 BW ~. ajb 8/00 ~~) ) Nanuk 2 RFT MW = 9.7 ppg Mud Grad. & MW 0.511 99.035 9.839 Hydrostatic Depth SSTVD Before After Formation Mobility 4800.02 4063.08 2158.58 2157.97 1873.5 10.7 7047.96 6137.22 3247.87 3246.1 2739.51 2.2 7064.99 6154.25 3253.11 3252.86 Bad test, Pressure Falling off 7063.88 6153.13 3251.36 3251.09 2742.21 1 7064.02 6153.27 3250.88 3250.69 2739.69 4.81 7074.96 6164.21 3256.55 3256.11 2741.26 5.52 7096.02 6185.26 3267.28 3266.95 2751.52 3.43 7121.03 6210.26 3280~ 1 3279.64 2774.86 2.03 7121.48 6210.7 3279.84 3279.39 2773.39 1.67 7141.48 6230.7 3289.81 3289.84 2766.95 1.78 7142 6231 .2 3290.3 3289.7 Tite 7143 6232.22 3290.55 3290.38 2767.52 3.94 7165.02 6254.23 3302.07 3301.65 2781.41 1.88 7200.1 6289.3 3320.8 3319.6 Tite 7200.5 6289.7 3320.2 3320.1 Tite 7634.9 6764.3 3546 3545.4 Tite 7645 6774.4 3550.8 3549 Tite 7658 6787.4 3357.4 3357.6 Tite 7964.01 7053.06 3714.86 3714.44 3298.14 408.86 7961 7050.05 3711.09 3711.1 3236.26 20.8 7966.5 7054.5 3714.4 3714 Tite 7967.94 7056.99 3714.79 3714.6 3238.75 30.5 8303 7392.3 3885.9 3885.2 Tite 8309.21 7398.25 3888.56 3888.01 3337 2.04 8319.6 7408.6 3892.2 3892.6 Tite 8321 7410 3893.6 3893.1 Tite Samples 8309.2 Open 2 3/4 gal. For 1 hr 27 min, close @ 945 psig, get stuck. Formation pressure = 3337 (Alpine) 620 psig @ surface. Recover 300 cc bottle of gas at pressure. Dump 2.6 ft3 gas and 8250 cc liquids, approx 750 cc oil. 7964 Open 2 3/4 gal. For 1 minute, close @ 3226 psig. Mobility 367 md/cp. Formation pressure = (Kuparuk) (Surface pressure registered 1350 psig?? Gauge suspect.) Dump 5.9 cU.ft gas, 10000 cc liquid & foam (2200 cc oil & foam.) Filtrate very emulsified. 3239 (K-2) 4802 Open 1 gal. For 39 minutes, close @ 445 psig. Mobility 8 md/cp. 330 psig @ surface. Recover 300 cc bottle, though valves and fittings very oily. Dumped 0.1 cU.ft gas, 2500 cc oil, no water. Had to poke around to find any permeability. Formation pressure = 1873 -~ ~ r.~'!-.!-J~~,~~~~~b!~£; ) TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Tim Ryherd State. of Alaska-DNRjDivision of Oil & Gas 550 W. ¡th Avenue, Suite 800 Anchorage, Alaska 99501 RE: Nanuq 2 DA TE: 02/15/2001 Transmitted herewith is the following: Nanuq 2501032033200 CD ROA-1 Digital data: - Core Labs Slabbed core UV and natural light core photos 3.5" disk _Sidewall and rotary core description and core chip descriptions Paper files _Nanuq 2 detailed core description graphic plot- by Dave Bannan 12/2000 _Summary: RFT 1 and 2 for Nanuq 2 by Dave Bannan _Core analysis results-Rotary sidewall core analysis with 3.5" disk of digital 7/26/2000 _Conventional Core Analysis, Core Labs, June 5, 2000 _Epoch Well Services Final Well report- includes _1) color formation log - 108'-9112' ; TVD 2"=100' _2) color formation log - 108-9112'; MD 2"-100' _3) Drilling dynamics log - 108'- MD 2"=100' data tables- Core Labs Log Prints _Schlumberger Repeat Formation Tester (run 1) 4/3/2000 _Schlumberger Repeat Formation Tester (run 2) 4/5/2000 please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) cc: Dave Bannan, Renee Hannon Approved for transmittal by: D. Bannan Receipt: Return receipt to: Date: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases ~ PHILLIPS Alaska, Inc.) m:1 A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke¡ AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Bob Crandall AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: Nanuq 2 DA TE: 02/20/2001 Transmitted herewith is the following: Nanuq 2 501032033200 CD ROA1 Digital data: - Core Labs Slabbed core UV and natural light core photos 3.5" disk _Sidewall and rotary core description and core chip descriptions Paper files _Nanuq 2 detailed core description graphic plot- by Dave Bannan 12/2000 _Summary: RFr 1 and 2 for Nanuq 2 by Dave Bannan _Core analysis results-Rotary sidewall core analysis with 3.5" disk of digital 7/26/2000 _Conventional Core Analysis¡ Core Labs¡ June 5, 2000 _Epoch Well Services Final Well report- includes _1) color formation log - 108'-9112' ; TVD 2"=100' _2) color formation log - 108-9112'; MD 2"-100' _3) Drilling dynamics log - 108'- MD 2"=100' data tables- Core Labs please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) cc: Dave Bannan, Renee Hannon Approved for transmittal by: D. Bannan Receipt: Return receipt to: Date: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases COMPANY: WELL: LEASE: FIELD: TlCKET#: DATE /TIME' 4/9/00 11 :00 4/9/00 15:30 4/9/00 19:45 4/9/00 20:00 4/9/00 21 :00 4/10/00 7:00 4/10/00 7:30 4/10/00 9:45 4/10/00 13:00 4/10/00 14:30 4/10/00 17:00 4/10/0018:30 4/10/00 19:00 4/11/007:00 4/11/007:30 4/11/0010:00 4/11/00 10:30 4/11/0012:00 4/11/00 14:30 4/11/0018:30 4/11/00 19:30 4/12/006:00 4/12/007:00 4/12/008:00 4/12/007:00 4/12/008:30 4/12/009:30 4/12/00 10:00 4/12/0010:30 4/12/00 14:00 4/12/00 15:00 4/12/0018:00 4/12/00 19:45 4/13/005:30 4/13/00 6:00 4/13/007:00 4/13/00 8:00 4/13/0010:15 4/13/00 11 :45 4/13/0013:00 4/13/0014:15 4/13/0016:00 4/13/0018:50 4/13/00 19:00 4/13/00 20:00 4/14/007:00 4/14/008:00 4/14/008:00 4/14/008:00 4/14/00 9:15 4114/009:30 4/14/0010:15 4/14/0010:30 4/14/00 11 :20 4/14/00 12:00 4/14/00 13:45 4/14/00 14:30 4/14/0014:30 4/14/00 14:50 4/14/0015:30 4/14/0016:00 4114/0016:15 4/14/00 17:30 4/14/00 18:30 4/14/0019:00 4/15/007:00 4115/00 7 :30 4/15/007:45 4115/008:30 ARCO Alaska, Inc #2 Nanuk Exploration 551359 STE CREW ON SITE Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard All Sparks crew Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard All Sparks crew Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard All Sparks crew Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard All Sparks crew Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard Sparks CfWi ) ".'.'.:.:.:.:.:.~«*:~~ ~ ~~~e'/l:'-U--_...U- - ARC a ~> HALLIBURTON OPERATIONS PERFORMED Travel to Slope Arrive on Slope Arrive on B3 pad Inventoried all STE equipment Shut Down for night Safety and job planning meeting Depart for location Arrive at Nanuk talked with co. rep. About rig departure and rig up Arrive at Sparks and discussed rig up and rig move. Travel back to 3 B pad to prepare STE equipment for Nanuk job. Repair high level and low level floats Repaired vertical Sep. controller. Shut down for night Safety and job planning meeting Depart for location Arrive at Clover Sparks crew move gear in Arrive on Sparks location, start rig up on tanks Move tank manifold in tank burm start running Kelly hose to tank Heater, lab, and pipe racks arrive on location Depart from location Shut down for night Safety and job planning meeting Sparks crew travel to location and secured the tanks Sparks crew travel to Nanuk location to help on rig up Nordic camp rig down and planning for move to Nanuk Leave for location Sparks crew on Nanuk location Arrive on location, Sparks crew on location also to help for the day. Waiting on snow removal and cleaning of pad. Trucks arrive with burming material and 2 HES tank and 2 tanko. Start building tank burms Start building Sep. burm . Trucks leave for 3B pad to get more equipment Shut down for the night. Safety and job planning meeting with the truck drivers Trucks depart for 3 B pad to load trucks Safety and job planning meeting Start setting tanks Start setting tanko tanks Trucks on location start unloading equipment Start spotting Sep. and doghouse Rigging up flow and suction hoses Spot Heater and Vertical Sep. In burm Finished rigging up tank farm Finished burming up Sep. burm , clean up location Shut down for the night. Safety and job planning meeting CAT departs for 3B pad to get genset (All HES equipment off pad) Start running relief line for transfer pump to tanko tank Start running pipe from heater to Sep. and all fluid out lines Spotted the sand filters and flanged SSV to the well head Built pipe burms from well head to Sep. burm Fueled diesel fired Heater Start manifolding sand filters Start running 1502 pipe from well head to sand filters Built genset burm and spot genset Start burm for relief tank Start psi test on tank hoses. Start rigging up from sand filter to chock manifold Finish building relief tank burm Start laying out 1502 pipe to the well head Finish rigging up to chock manifold start rigging up to heater Stood heater stack and test fired heater Finish running pipe to tanks Finish running pipe to heater, start picking up all tools and pipe. Shut down for the night Safety and job planning meeting Continue psi testing on tank rig up Start rigging up solids flow line from sand filter Built fluid transfer Burma for vac trucks Page 1 r~~T~ijfJj4?:;-.~:~;:.T::)~:~'çm;w :~..$Ú:~:.:/:..'/)::/\:' .:~?: ::::')::.~:~:'/::::{::::~::<~:::~:::::::\{.:.r::~':,(:::, :'::¡':':?~~'~~AA11ØN.~t~~Q.~M~~:f:~~~)~~tIt?}~)))~.~::~~~~:~(((.)~:)::::~:}:~~~:/~:t~:~:~~t~::r 4/15/00 9:45 Norm, David. Todd. Ken Finish running pipe for sand filter solids line 4/15/0010:00 Start building stairs to get in and out oftank and Sep. burms 4/15/0010:20 Start running safety system 4/15/0010:45 Preparing the Sep. and all flow lines for air psi test 4/15/00 11 :30 Start house cleaning on location 4/15/00 13:00 Air test completed on tanks inlet. 4/15/00 14:50 Air test completed on all tank piping 4/15/0015:20 Start repairing 2" valve on vert. Sep. 4/15/0016:00 Sparks crew off location 4/15/0016:20 Spotted SCAN lab between tank and Sep. burm 4/15/0017:40 Rigged up Scan transducer. 4/15/0018:30 Rebuilt and replaced 2" valve on vert. Sep. 4/15/0019:00 Welder on location to fix genset's door 4/15/0020:00 Shut down for night 4/16/00 7:00 AM Doug, Tony, Mark, Adam, Mike Safety and job planning meeting 4/16/007:30 Kevin, Billy, Chad, Richard Start heat tracing and Insulating all tanko tanks 4/16/007:30 Tommy Continue rigging up safety system 4/16/009:50 Finish air psi test on all pipe and front manifold of sand equipment. 4/16/0010:00 Attend safety meeting with Schl. On well frac procedures 4/16/0012:00 Air psi test on Sand filters, both blow down valves leak. Stutz (co. Rep.) will have them replace with new valves. Continue insulation of tank hoses. Start rigging up flare stack. Finish insulating tank hoes Start rigging up to well head Finish rigging up to well head Shut down for night. Safety and job planning meeting Start replacing valves on the sand filter Start building bunns for sand blow down tank Finish rigging up valve on sand filter, valves still leak. Finish with safety system. Waiting on Schl. To move sand Harper were we can rig up relief tank. Regressed valves on sand filters and they held pressure. Run pipe to sand tank. Crane on location start standing flarestack. Psi tested pipe running to sand filter. Pulled adj. Chock out of chock manifold and zero indicator Flare stack stood and test fired. Start running relief line and gas line. And building burms for pipe. Psi test flare line to 100 psi with air, then to 1000 psi with n2. Finish running relief line and psi test. Test all of the safety system to the ssv. Finish chaining relief and sand blow down lines to the tank. Pre-pressure test safety meeting and planning. Load lines with hot diesel and pump 5 bbl into each tank Lines full - and 5 bbl in each tank Pressure test lines to tank #4 Psi to 0 250 psi 200 - 250 psi Lines to tanks to 500 psi Pressure lines 500 to 1000 psi Bleed off pressure and repair leak Pressure lines to tank fann 0 to 1000 psi Bleed off pressure Pressure hose to tank #3 to 1000 psi Bleed off pressure Pressure hose to tank #2 to 1000 psi Bleed off pressure Pressure tankco to #3 tank to 1000 psi Bleed off pressure Pressure lines to tank #3 to 1000 psi Bleed off pressure Pressure test tank manifold to 1000 psi Bleed off pressure Fill separator Start pressure test of separator to 200 psi 200 to 500 psi 500 to 1000 Bleed off psi COMPANY: WELL: LEASE: FIELD: TlCKET#: ARCO Alaska, Inc #2 Nanuk Exploration 551359 4/16/0012:30 4/16/0013:45 4/16/0016:30 4/16/0018:30 4/16/00 19:45 4/16/00 20:00 4/17/00 7:00 4/17/007:30 4/17/008:30 4/17/00 10:00 4/17/00 10:45 4/17/00 11 :00 4/17/00 13:00 4/17/00 13:50 4/17/00 14:30 4/17/00 15:30 Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard Tommy, David 4/17/00 16:40 4/17/00 17:00 4/17/00 19:00 4/17/00 20:30 4/17/00 21 :00 4/17/0022:00 4/17/00 22:35 4/18/000:00 4/18/000:24 4118/000:30 4/18/000:32 4/18/000:33 4118/000:50 4/18/000:53 4/18/00 1 :00 4118/00 1 :07 4118/00 1:10 4/18/00 1 :13 4/18/001:14 4/18/000:16 4/18/00 1 :22 4/18/00 1 :24 4/18/00 1 :27 4118/00 1 :28 4/18/00 1 :30 4118100 1 :32 4118/002:00 4118/00 2:15 4118/002:18 4118/002:21 4/18/002:23 ) ) ORALLiBURTON ARca ~> Page 2 COMPANY: WELL: LEASE: FIELD: TlCKET#: :.-~--.oÂr~7~ - 4/18/00 2:30 4/18/00 2:30 4/18/002:45 4/18100 2:48 4/18100 2:49 4/18100 2:55 4/18100 2:59 4/18100 3:02 4/181003:10 4/181003:15 4/181003:26 4/18/003:30 4/181003:36 4/181003:40 4/18100 3:46 4/18100 4:01 4/18100 4:10 4/181004:15 4/18/004:19 4/18/00 4:20 4/181004:30 4/18100 5:00 4/18100 7 :00 ARCO Alaska, Inc #2 Nanuk Exploration 551359 . .....~J'E çFŒW ~ ~.rr~ Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard Tommy, David, Tim ) .'.'.'.'.'.'~';';;o.";..-x-.....-....--..--_...... ARca ~> HALLIBURTON . v' ..... .. . ..... .. ..... . ~~~Jl9N$ P¡:;~O~M~Þ . .. ..... . .... --............... --.....-- ..... 100 psi trip on low level alarm sep pressure Start filling second vessel Psi second vessel to 200 psi 200 to 400 psi 400 to 1000 psi (High pressure alarm tripped) Bleed off pressure Start pressure test of heater Pressure 0 to 1450 psi Pressure bleeding off Tripped safety valve Pressure to 1500 then 2000 psi Bleed off pressure Start pressure testing choke manifold (Test 2 back valves and middle valve) Pressure manifold to 2000 psi (Tripped Safety - working properly) Bleed off pressure Pressure test front valve of manifold to 2000 psi Bleed off pressure Start test of downstream valve of sand filter to 2000 psi Bleed off pressure Start test of upstream sand finer to 2000 psi Bleed off- isolate sand filters to determine leak Valves on sand filter are not holding - pressure leaked to inlet of separator blowing gasket. Finish pressure testing Start insulate and heat trace lines Continue to insulate and heat trace lines Insulation of lines complete, walk through with Tony, & Steve Pre Job safety meeting - All HES personnel, ARCO reps, Schlumberger (nitrogen), APC, Lil Red Hot Oil 4/19/000:00 Final walk through by well test supervisors Tony, Steve, Mark, & Mike 4/19/000:51 Lil Red Hot oil rigging up to sand filter #2 (Baker screen) will perform line integrity test 4/19/001:12 Surface safety valve open 4/19/001:12 Open wing valve to closed in choke manifold for initial build up pressure 4/19/00 1 :12 Initial wellhe~~.p!.:!~~~!_~ 37~_.e~~m__m--__m.....--. .._~--a.."~~~~Øit~ii~ti~~~~~~~~~~ 4/19/001:22 Increase choke to 32/64 from 20/64 (adjustable) 4/19/001:32 Increase choke to 48164 from 32/64 (adjustable) 4/19/002:23 Start pumping nitrogen down annulus to kick well off (minimum rate) 4/19/002:30 BSW 95% water & 5% diesel 4/19/00 3:00 BSW 50 % water & 50% diesel 4/19/003:30 BSW 1% Water 4/19/004:00 BSW .25% Water 4/19/004:30 BSW 10% Water 4/19/005:00 BSW 45% Water 4/19/005:17 Flare pilot was lit and tested good 4/19/00 5:30 BSW 2.5% Water 4/19/005:40 Switch to Tank #2 transfer Tank #3 to vac truck 4/19/006:15 Doug, Tony, Mark, Adam, Mike Stop pumping Nitrogen 4/19/006:30 Kevin, Billy, Chad, Richard Start back pumping Nitrogen 400scflmin N2 4/19/006:45 Tommy, David, Tim Stop pumping Nitrogen 4/19/00 7:00 Start back pumping Nitrogen 400sctlmln N2 4/19/007:15 Stop pumping Nitrogen 4/19/007:30 Start back pumping Nitrogen 400sctlmin N2 (Starting 30 min cycles) 4/19/00 8:00 Stop pumping Nitrogen 4/19/00 8:30 Start back pumping Nitrogen 400sctlmin N2 (Starting 30 min cycles) Fluid 8.6 ppg Stop pumping Nitrogen Start back pumping Nitrogen 400sctlmln N2 (Starting 30 min cycles) Stop pumping Nitrogen Start back pumping Nitrogen 400sctlmin N2 Stop pumping Nitrogen Start back pumping Nitrogen 400sctlmin N2 Stop pumping Nitrogen Shut well in to rig up CTU . Rig up Lil Red to pump diesel for freeze protection Flowing into tank two, Pump diesel thru CTU to clean, RIH pumping N2 Open up to well, ready to run CT inhole. 4/1810018:00 4/18/0023:15 4/18/0023:30 4/19/00 9:00 4/19/00 9:30 4/19/0010:00 4/19/00 11 :03 4/19/0012:06 4/19/0012:35 4/19/0013:40 4/19/0014:00 4/19/0015:19 4/19/0015:30 Page 3 COMPANY: WELL: LEASE: FIELD: TICKET#: nn:.DA1:(t fIME':n-: - 4/19/0015:40 4/19/0016:45 4/19/0017:20 4/19100 17:25 4/19/0017:30 4/19100 17:40 4/19/00 17:50 4/19/0018:00 4/19/0018:00 4/19/0018:30 4/19/0019:00 4/19/0019:30 4/19/0019:30 4/19/0019:30 4/19/00 19:30 4/19/00 19:45 4/19/00 21 :00 4/19/00 21 :00 4/19/00 21 :30 4/19100 21 :30 4/19/0022:00 4/19/0022:00 4/19/0022:30 4/19/0022:30 4/19100 22:30 4/19/0023:00 4/19/0023:00 4/19/00 23:30 4/19/0023:30 4/19/00 23:30 4120/00 0:00 4/20/000:00 4/20/00 0:30 4120/00 0:30 4/20/00 0:30 4120/00 1:00 4120/00 1 :00 4/20/00 1 :30 4120/00 1 :30 4/20/00 1 :30 4/20/00 2:00 4120100 2:00 4/20/00 2:30 4120/002:30 4120/002:30 4120/00 3 :00 4120/00 3:00 4120/00 3:00 4120/00 3:00 4120/003:29 4/20/003:30 41201003:30 4/20/003:30 4120/003:30 4120/004:00 4120/00 4:00 4/20/00 4:00 4120/00 4:30 4120/00 4:30 4/20/005:00 4/20/005:00 4/20100 5:00 4120/005:00 4120/00 5:30 4/20/00 5:30 4120/005:30 4120/00 5:45 41201006:00 4120/006:30 4/20/007:25 ARCO Alaska, Inc #2 Nanuk Exploration 551359 . .::SiE. ÇREW QN SITE' Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard Tommy, David. Tim ',' .'.'.'...';";.;.;<'".,~" 5."""".""-"- ARCO <> HALLIBURTON . w . ..... . . .... un. ... n .. '" ~E~Tl9N.$ ~ffl=OR~J;Q. .. . m''''''m......... 'm........... m ... On' . CT RIH while circulating N2 500scflmin N2 Switch to 2 nd Sand Filter (without baker screen) Flush Baker sand filter with hot oil Switched to Baker Sand Filter Increase N2 rate thru CT to 1000 scf/min Switch to 2 nd Sand Filter (without baker screen) Flush Baker sand filter with hot oil Switched to Baker Sand Filter Switch to 2 nd Sand Filter (without baker screen), 50% pressure drop across Baker Sand Filter Flush Baker sand filter with hot oil BSW 80% Water 20% Diesel BSW 100% Water wIT race oil BSW 78% Water 22% oil BSW 88% Water 12% oil Flowing Into tank three, Completed transfer of fluid in tank #2 to Tank #5 Continue to cire. Nitrogen @ 500 SCFIMIN Loaded tank #2 with 250 bbl of diesel to be used CTU circulating purposes Switch to tank #4 from tank #3 BSW 76% Water 24% Oil Switch from Tank 4 to Tank 2 BSW 70% Water 30% Oil BSW 75% Water 25% Oil Switch from Tank 2 to Tank 4 BSW 80% Water 20% Diesel Switch from Tank 4 to Tank 2 Continue to clrc. Nitrogen @ 500 SCFIMIN BSW 73% Water 27% Oil Switch from Tank 2 to Tank 4 BSW 70% Water 30% Oil Switch from Tank 4 to Tank 2 Continue to circ. Nitrogen @ 375 SCFIMIN (min rate) BSW 70% Water 30% Oil Switch from Tank 2 to Tank 4 BSW 70% Water 30% Oil Switch from Tank 4 to Tank 2 Continue to circ. Nitrogen @ 375 SCFIMIN (min rate) BSW 70% Water 30% Oil Switch from Tank 2 to Tank 4 BSW 70% Water 30% Oil Switch from Tank 4 to Tank 2 Continue to circ. Nitrogen @ 375 SCFIMIN (min rate) BSW 70% Water 30% Oil Switch from Tank 2 to Tank 4 BSW 70% Water 30% Oil Switch from Tank 4 to Tank 2 Continue to circ. Nitrogen @ 375 SCFIMIN (min rate) BSW 70% Water 30% Oil Switch from Tank 2 to Tank 3 Transferring Tank 4 to Tank 5 Corr. Oil Gravity 37.4 @ 60 Chlorides 24,000 ppm BSW 70% Water 30% Oil Continue to circ. Nitrogen @ 375 SCFIMIN (min rate) Tank 5 full start transfer to vac truck and switch to tank 6 for transfer of tank 2 Transfer of tank 4 complete - start transfer of Tank 2 to tank 6 BSW 63% Water 37% Oil Estimate 31.67 bbl for period 03:30 to 04:00 Estimated rate = 562 bblloil per day and 957 bbllh20 per day Switch from tank 3 to tank 4 Continue to cire. Nitrogen @ 375 SCFIMIN (min rate) Switch from Tank 4 to Tank 2 Start transfer of #3 to Tank #6 BSW 63% Water 37% Oil Corr. Oil Gravity 39.2 @ 60 BSW 63% Water 37% Oil Switch from Tank 2 to Tank 4 Continue to circ. Nitrogen @ 375 SCFIMIN (min rate) Transfer of tank 2 to tank 6 complete Switch from Tank 4 to Tank 2 Switch from Tank 2 to Tank 4 Increase N2 rate to 500 SCFIMIN Page 4 COMPANY: WELL: LEASE: FIELD: TlCKET#: ARCO Alaska, Inc #2 Nanuk Exploration 551359 ) » . ,','. '.'.~.':":"~;'XWio. ,;,~..---.......... ARca <> HALLIBURTON :~¡~j~j~j~j¡j¡WAt$~t¡n.tj¡¡~¡¡¡¡¡¡fj¡¡¡j¡~¡~¡j¡j¡j$m¡~J¥W~¡~'f$.f:Œ~¡¡t¡¡~;¡¡¡~t¡¡¡;¡~¡~¡¡¡¡¡;¡~¡~¡;¡¡¡;¡j¡;¡~¡¡¡~¡j¡¡~;¡¡~¡~¡;~~¡;¡¡¡¡¡¡~¡¡~~¡¡j¡¡~;¡~¡jm¡j¡jm¡¡¡j¡¡¡;¡¡¡j¡j¡;¡j¡j¡j¡~¡ffj~¡tm~~'jm~UM!OO:1'ø.~Mi~¡¡¡j¡j¡;¡~¡;¡j¡j~j¡j¡j~j¡j¡j~j¡;¡¡~¡¡;¡j~~¡¡¡¡¡¡¡~¡;¡j¡¡¡¡¡¡¡j~;¡j¡j~;¡j¡;¡j¡¡~~¡~j¡j~j¡j¡¡¡j¡~;¡j¡j¡j¡~¡j¡j¡¡¡¡¡j~¡¡~ 4/20/00 9:36 Oil gravity 35.1 @ 60 4/20/00 9:39 Decrease N2 rate to 350 SCFlMin 4/20/0010:53 Transfer fluid from Tanko #5 to Vac Truck 264.9 bbl 4/20/0011:38 Oil gravity 35.0 @ 60,20000 ppm Chloride, 60% SS&W 4/20/00 12:00 SS& W 57% Transfer fluid from Tanko #6 to Vac Truck 24.36 bbl SS& W 61 % SS&W 60% SS&W 68%,22000 ppm Chloride SS&W 68% SS&W 68% Oil transfer pump developed leak, spill was contained, pump is out of service and parts are ordered to repair pump. Pump # A 1210 22000 ppm Chloride SS& W 67% SS& W 60% SS&W 65% SS& W 70%, 23000 ppm Chloride SS&W 63% SSW 70% Water 30% Oil Flowing into Tank 3, cont. to circ hole nitrogen - coil tubing still In hole Transfer of Tank 4 to Tank 7 complete SSW 61% Water Flow into Tank 3 SSW 62% SSW 64% Flow Into Tank 3 SSW 63% Water 37% Oil Chlorides 18,000 ppm Flow into Tank 3 Volume In Tank 1 Is 175 bbl SSW 60% Water Chlorides 15,000 ppm SSW 60% Water SSW 64% SSW 65% SSW 63% Water 37% Oil SSW 60% Water SSW 60% Water Start transfer of tank 6 to vac truck SSW 60% Water. Closed Tank N# 4 ending strap 11 feet 5 inches. Open Flow to Tank N# 3 End of vac truck operation Transferred 262bbl. Tanko N# 6 ending strap 3 feet. Tank N# 3 ending strap 1 foot 8 inches. SSW 52% SSW 58% Finished transfer of Tank 4 to Tank 6 Continue to flow into tank 3 Fuel truck on location, Fill all equipment SSW 62% SSW 60% SSW 60% Switch from tank 3 to tank 4 - Start Transfer of Tank 3 to tank #5 Start Transfer of Tank 7 to vac truck SSW 62% SSW 62% SSW 60% Completed transfer of Tank 7 to vac truck Completed transfer of Tank 3 to Tank 5 SSW 58% SSW 60% Clorldes 14000ppm Oil Gravity is 36 API @ 60 Start transfer of tank 6 to vac truck SSW 60% SSW 62% SSW 60% SSW 65%, 15000 ppm chloride, 38.8 @ 60F SS&W 65% SS&W 63% SS&W 65% 4/20/00 12:30 4/20/0013:00 4/20/0013:30 4/20/00 14:00 4/20/0014:30 4/20/00 15:00 4/20/0015:30 4/20/0016:00 4/20/00 16:30 4/20/00 17:00 4/20/0017:30 4/20/0018:00 4/20/0018:00 4/20/00 18:30 4/20/0018:30 4/20/00 19:00 4/20/00 19:00 4/20/00 19:30 4/20/0019:30 4/20/00 20:00 4/20/00 20:00 4/20/00 20:00 4/20/00 20:00 4/20/00 20:30 4/20/0020:30 4/20/0021:00 4/20/00 21 :30 4/20/0022:00 4/20/00 22:30 4/20/00 23:00 4/20/00 23:30 4/20/00 23:30 4/21/00 0:00 4/21/00 0:22 4/21/000:30 4/21/000:30 4/21/00 1 :00 4/21/001:19 4/21/00 1 :30 4/21/00 1 :30 4/21/00 2:00 4/21/002:30 4/21/003:00 4/21/00 3:00 4/21/00 3:00 4/21100 3:00 4/21100 3:30 4/21100 4:00 4/211004:20 4/21100 4:20 4/21100 4:30 4/21100 5:00 4/21100 5:00 4/21100 5:00 4/21/00 5:15 4/21/00 5:30 4/21/00 6:00 4/21/00 6:30 4/211007:00 4/21/007:30 4/21/00 8:00 4/21/00 8:30 Doug, Tony, Mark, Adem, Mike Kevin, Billy, Chad, Richard Tommy, David, Tim Page 5 COMPANY: WELL: LEASE: FIELD: TICKET#: ARCO Alaska, Inc #2 Nanuk Exploration 551359 ") f%fRALCïBURTON ARca ~> .))::[:PA~Ptf~)(}}::}(?~~J?~Vf~.~.n:~;:::~:::;::;.:T:::\?:./:()/:::::::'\:{~~')::)?::::~::::::I~::)trL{::r:.:':::IJ:æ~fiA)1Þ.N~f~Øf9~M~~}}{{::~~/Itft:}{:)~/::~r::::~::t.I?I\{.){/\~\t: 4/21/009:00 BS&W 65% N2 down, lost prime 4/21/009:30 BS&W 62%, N2 back on line 350 scf/mln 4/21/0010:00 BS&W 55%,Started to flow thru seperator 4/21/0010:30 BS&W 45% 4/21/0010:42 Bypass Seperator 4/21/0011 :00 BS&W 47%, Oil Gravity 35.3 @ 60F 4/21/00 11 :30 BS& W 55%, Started to flow thru seperator 4/21/0012:00 BS&W 55% 4/21/0012:30 BS&W 60%,14000 ppm chloride 4/21/0012:43 Nitrogen went down, lost prime 4/21/0012:45 Nitrogen back up 350 scf/min 4/21/0013:00 BS&W 80%, 38.3 @60F 4/21/0013:30 BS&W 78%, H2S 0,1000 ppm CO2 4/21/00 14:00 BS&W 78% 4/21/00 14:30 BS&W 70%, 23000 ppm Chloride 4/21/0015:00 BS&W 65% 4/21/00 15:30 BS&W 70% 4/21/0016:00 BS&W 65% 4/21/0016:30 Switch SCAN to 3 phase 4/21/0018:00 BSW 75% Flowing thru separator 4/21/0018:00 1% BSW on 011 leg 4/21/0018:30 Taking Oil samples at separator 4/21/0018:30 BSW 70% 4/21/0019:00 BSW 68% 4/21/0019:30 BSW 70% 4/21/0019:30 Gas Gravity .846 4/21/00 20:00 Switch from tank 4 to tank 3 4/21/00 20:00 Start transfer of tank 5 to vac truck 4/21/0020:30 4/21/00 21 :00 4/21/0021 :00 4/21/0021:11 4/21/00 21 :11 4/21/00 21 :22 4/21/00 21 :30 4/21/0022:00 4/21/0022:13 4/21/0022:30 4/21/0022:30 4/21/0023:00 4/21/00 23:00 4/21/00 23:30 4/21/00 23:30 4/21/00 23:30 4/21/00 23:50 4/22/000:00 4/22/000:30 4/22/000:46 4/22/00 1 :00 4/22/00 1 :30 4/22100 1:44 4/22/00 2:00 4/22/00 2:00 4/22/00 2:08 4/221002:10 4/22/00 2:27 4/22/002:30 4/22/00 2:30 4/22/003:00 4/22/003:00 4/22/00 3:00 4/22/003:11 4/22/003:30 4/22/00 3:30 4/22/00 4:30 4/22/004:45 4/22/00 5:00 4/22/00 6:00 4/22/007:00 4/22/00 7:30 Doug, Tony, Mark, Adam, Mike Kevin, Billy. Chad, Richard BSW Well Head 70% BSW 011 leg 10% Transfer of Tank 5 to Vac Truck complete Start transfer tank 4 to tank 5 Gas Gravity .852 BSW Well Head 70% BSW Well Head 69% Transfer of tank 7 to Vac Truck BSW Well Head 65% BSW Oil leg 2% BSW WellHead 62% BSW Oil leg 2% Opened Tank 4 and Close Tank 3 BSW Well Head 64% BSW 011 leg 2% Stopped Pumping Nitrogen BSW 64% BSW 62% Switch to 2 phase in separator Gas Gravity .806 BSW 62% Gas Gravity 0.777 BSW Well Head 63% Heater choke decreased from 128th to 64/64th Transfer Tank 7 to Vac Truck Gas Gravity 0.783 CO2 0.2% Gas Gravity 0.778 BSW Well Head 50% BSW Well Head 55% Closed Tank 4 and Opened Tank 3 Gas Gravity 0.780 Tank 4 Transfer to Tank 7 BSW Well Head 63% Chlorides 11,000 ppm BSW Well Head 62% Gas Gravity 0.772 BSW Well Head 64% Gas Gravity 0.770 Oil Gravity 40.2 @ 60 BS&W 60%,11000 ppm Chloride BS&W 60% Page 6 COMPANY: WELL: LEASE: FIELD: TICKET#: ARCO Alaska, Inc #2 Nanuk Exploration 551359 (t FiAlLïBURTON ARca <> '----:i)-Ãi{i_U-~-~~~.-.-~1¥~ç~w~õirsijl--.-.-.-.-.-.VV----------VV~- U~~ ~~-- ~, ,.- - ..---.-----.-~.~.RA-n~$.-PERf9RMË~'~-.-.~~--.-.. - ..~.-.----.~~ ~.~.-.-..-.. .--.--w:.~~.: .~.. 4/22/008:00 Tc;,mmy, David Tim BW&W 62°0 4/22/008:30 Oil Gravity 39.8@60F, BS&W 60% - 4/22/009:00 BS&W 58%, SG Gas 0.774 4/22/009:30 11000 ppm Chloride, BS&W 65%,2800 ppm CO2, 0% H2S 4/22/009:30 API Oil Gravity 43.4@ 107F 39.5@60F 4/22/0010:00 60% BS&W 4/22/0010:30 60% BS&W 4/22/00 11 :00 65% BS& W 4/22/00 11 :30 60% BS& W 4/22/0012:00 62% BS&W, Gas SG 0.778 4/22/0012:30 62% BS&W 4/22/0013:00 11000 ppm Chloride, 2000 ppm CO2, 0 H2S, API42.8@95 = 39.7@60F, Gas SG 0.779 4/22/0013:30 65% BS&W 4/22/0014:00 62% BS&W 4/22/0014:30 65% BS&W 4/22/0015:00 62% BS&W 4/22/0015:30 58% BS&W 4/22/0016:00 60% BS&W 4/22/0016:30 60% BS&W, Gas SG 0.785,11,000 ppm Chloride, 4/22/0017:00 60% BS&W, 2000 ppm CO2, 0 H2S, API Oil Gravity 40@80 = 38.3@60 4/22/0017:30 62% BS&W 4/22/00 18:00 58% BS&W 4/22/0018:30 65% BS&W 4/22/00 19:23 Gas SG 0.718 4/22/00 19:30 Switch from Tank 3 to Tank 4 4/22/0019:30 63% BS&W 4/22/0020:00 62.5% BS&W 3000ppm CO2, 0 H2S 4/22/0020:30 62% BS&W 4/22/0021:00 62% BS&W, 10,000 ppm Chloride 4/22/00 21 :00 Corrected Oil Gravity 39.5 @ 60 4/22/00 21 :30 64% BS&W 4/22/00 21 :30 Gas SG 0.780 4/22/0022:00 63% BS&W 4/22/0022:30 63% BS&W 4/22/0022:30 Gas SG 0.718 4/23/00 0:00 64% BS& W 2000 ppm CO2, 0 H2S 4/23/000:30 64% BS&W, 11,000 ppm Chloride 4/23/00 1 :00 63% BS& W, API Oil Gravity 40 @ 68 = 39.4 @ 60 2000 ppm CO2, 0% H2S 4/23/00 1 :30 64% BS&W 4/23/00 2:00 61 % BS& W 4/23/00 2:30 62% BS& W 4/23/002:30 63% BS&W 4/23/00 3:00 63% BS&W 4/23/003:30 63% BS&W 4/23/004:00 63% BS&W 4/23/004:30 64% BS&W, 12,000 ppm Chloride 4/23/005:00 64% BS&W, API Oil Gravity 39.6 @ 58 = 39.8 @ 60,12,000 ppm Chloride, 2500 CO2, H2S 0% 4/23/00 5:30 64% BS&W 4/23/00 6:00 63% BS&W 4/23/006:30 59%BS&W 4/23/007:00 Doug. Tony, Mark, Adam, Mike 60% BS&W 4/23/007:30 Kevin, Billy, Chad, Rlçhard 55% BS&W 4/23/008:00 Tommy, David, Tim 58% BS&W 4/23/00 8:30 4/23/009:00 4/2310013:30 4/23/0014:00 4/23/00 14:30 4/23/0015:00 4/23/0015:30 Gas specific garvity 0.718,2500 ppm CO2, 60% BS&W, 0% H2S, API Oil Gravity 39.4@64 = 39.1@60 57% BS&W 58% BS&W 61 % BS& W 60% BS&W 59% BS&W 65% BS&W 59% BS&W, 10000 ppm Chloride, CO@2 2000 ppm, H2S 0% 62% BS&W, Gas SG 0.78,11000 ppm Chloride, API Oil Gravity 36.6@62 = 36.4@60 63% BS&W 61% BS&W 60% BS&W 57% BS&W 60% BS&W 4/23/009:30 4/23/00 10:00 4/23/00 10:30 4/23/00 11 :00 4/23/00 11 :30 4/23/00 12:00 4/23/0012:30 4/23/00 13:00 Page 7 COMPANY: WELL: LEASE: FIELD: TICKET#: ARCO Alaska, Inc #2 Nanuk Exploration 551359 ~r_-..-PÄ1EifJM(~----------r-~fè CÆw-õN~sn:f- 4/23/0016:00 4/23/0016:30 4/23/0017:00 4/23/00 17:30 4123/0018:00 4/23/00 18:30 4/23/00 19:00 4/23/0019:30 4/23/00 20:00 4/23/00 20:30 4/23/00 21 :00 4/23/00 21 :30 4/23/00 22:00 4/23/00 22:30 4/23/00 23:00 4/23/00 23:30 4/23/000:00 4/24/000:30 4/24/00 1 :00 4/24/00 1 :30 4/24/00 2:00 4/24/00 2:30 4/24/00 3:00 4/24/003:30 4/24/00 4:00 4/24/00 4:30 4/24/005:00 4/24/005:00 4/24/00 5:30 4/24/00 6:00 4/24/006:30 4/24/007:00 4/24/00 7:30 4/24/00 8:00 4/24/00 8:30 4/24/00 9:00 4/24/00 9:30 4/24/0010:00 4/24/0010:30 4/24/0011:00 4/24/0011:30 4/24/00 12:00 4/24/00 12:30 4/24/0013:00 4/24/0013:30 4/24/0014:00 4/24/0014:30 4/24/0015:00 4/24/00 15:30 4/25/00 20:10 4/25/00 22:00 4/26/000:00 Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard Tommy, David, Tim Doug, Tony, Mark, Adam, Mike Kevin, Billy, Chad, Richard Tommy, David, Tim . .........~..~.~.;.~.;..~.............-.......--- ARC a ~> HALLIBURTON --"" -.....,-----,- ------~"---V.._------'_.- - - - W.- ~v~-- Y~()PEijiTii;)Nš-P:ERfoRMép~r.~~..-.--.---. '.~.-.- .-.-"~~.~ -- --'V -----------,,,,,__4 . ---.0.... --. ...... 60~0 BS&W 60°0 BS&W 60°0 BS&W, 2800 ppm CO2, 0°0 H2S, Gas SG 0.786 API 011 Gravity 37.6'" 83 =35.7~60 62°0 BS&W 59°0 BS&W 62% BS&W 63% BS&W 64% BS&W 66% BS&W 67% BS&W 66% BS&W, Chlorides 9000 ppm, .782 Gas SG, API Oil Gravity 39.6 @ 68F = 39.0 @ 60F 63% BS&W 65% BS&W 65% BS&W 62% BS&W, .780 Gas SG 65% BS&W 64% BS&W 64% BS&W 63% BS&W, Chlorides 10500 ppm, .782 Gas SG API Oil Gravity 38.2@66 = 37.7 @ 60F 64% BS&W 63% BS%W 61% BS&W 64% BS&W 65% BS&W .780 Gas SG 64% BS&W 64% BS&W 65% BS&W, Chlorides 10000 ppm, Oil Gravity 38.6@64 = 38.3 @60, Gas SG.772 2500 ppm CO2, 0% H2S 64% BS&W 65% BS&W 63% BS&W 60% BS&W 65% BS&W 66% BS&W 65% BS&W 63% BS&W, 2500 ppm CO2, 0% H2S, Gas SG 0.786,10000 ppm Chloride API Oil Gravity 36.4@55 = 36.8@60 64% BS&W 65% BS&W 65% BS&W 66% BS&W 68% BS&W 65% BS&W, 2800 ppm CO2, 0% H2S, Gas SG 0.786,10000 ppm Chloride 62% BS&W 65% BS&W, Gas SG 0.786,0.28% CO2, 0% H2S API Oil Gravity 63% BS&W 63 DS&W, Bleed Casing pressure down thru flow lin from 650 psi to 450 psi, Gas rates will increase due to N2 flowing thru seperator 63% BS&W 63% BS&W, Close Needle valve on Casing, Pressure 450 psi, Blow down seperator Flush lines with diesel Finished flushing lines with diesel Blow Nitrogen thru lines from well head to tank farm Finished blowing down lines with nitrogen Arrange equipment, clear snow from baskets, bundle unused plywood to prepare for rigdown Page 8 COMPANY: WELL: LEASE: FIELD: TICKET#: ARCO Alaska, Inc #2 Nanuk Exploration 551359 -) .-~~ QÃT~i~~. -~ .. $TE qttw ON sn:E.. I . .'...'.'.'.';';.o;..~.;..w¡, .;.............._--...... HALLIBURTON - . - ." - . - - -- Page 9 ) ARCO ~> OP~8ÃTlON$ PE~OA~~Q m - m.. ---.. . -. -. .-.". -- COMPANY: WELL: LEASE: FIELD: TICKET#: ARCO Alaska, Inc #2 Nanuk Exploration 551359 _mmÕA-Œ-r- nufm.- ~.--.-- - nS jifc~W-orfsii£.n, ') ..............~..;.~.~....~....¡ ""................ HALLIBURTON Page 1 0 ) ARca ~~ OP.ERAll~~ ~~.oflM~P........... .".. ..-_0 ---- - - ... ---.. --- ~~ COMPANY: ARCO Alaska. Inc SURFACE TESTING REPORT c:ìHALLlBURTON FIELD: Wildcat GAS FLOW RATE ~~ Lease: Nanuk CALCULATIONS Well It 2 ARCa Alaska, Inc. HI.STAGE METER RUN SIZE: i.ID: LQ;.STAGE METER RUN SIZE: DATE/TIME HI-STAGESEPARATOR CONDITIONS HI-STAGE TIME STATIC DIFF GAST ORIFICE GAS GR H2S CO2 GASRATE GAS CUMM m/dlyr hr:mn (mln) (pal,,) (" we) (da" F) Qnch..) (elral) (ppm) (maclld) (ma~ 4/21/0012.00 30 131.89 50.06 89.42 1.25 0.65 0.000 0674892 0.0301989 =~ ~lgF9Qi2 3q 30 9552 23.03 9248 125 065 0000 03991368 0.0385142 -- -~, ~~ !.QQ--,!~'Q9 30 13653 19.85 959 125 0967 0.000 I 0 5278763 0.0495116 ---- -~:'~ 'PQ _~30 30 187.31 2939 9733 1 25 0967 0.000 0 5508957 0.0609886 4/21100 1400 30 158.& 41.06 9718 125 0.967 0.000 0.5963856 0.0734133 .---"- 4/21100 14:30 30 119.51 49.05 9612 125 0.967 0.000 0573831 0.0853681 - - _4/21 ,~OQ-) _5 00 30 12352 4962 9607 125 0967 0000 0.5937209 0.0977373 --- ~'.?1JOO '.?_~Q 30 122.59 5333 9562 125 0.967 0000 0.6052562 0.110347, - ___.Æ?_1 IQ.Q_!Ê~O 30 1139 5667 9469 125 0967 0.000 0 59&0534 0122806 _____~2_'!00 16}_0 30 107.4 5804 9467 125 0.967 0000 05757916 0 134802 ---~~ IQQJ ZS¡Q 30 1391 40.6 9435 125 0967 0.000 055769023 0146421, ---- 4121'09 1L_~ 30 13917 4036 9376 1.25 0967 0000 05599251 0 1 58086 - -- ~gl:~ !~-QQ 30 142.8 4126 9282 1 25 0967 0000 05577234 0 169705 - - .412_~ IQ~U ~~9 30 14058 3991 9233 125 0967 0000 051'.78458 0.181535 . -- -- - 4 ~? ! /_Q.Q_'_~. q_9 30 13~. 4 4106 92.75 125 09>37 0000 0 55&4394 0193169' ~- ----~~?!!QO _'!'~~Q 30 13536 4223 92 &2 125 09>37 0000 0 5764006 0205178 --- __~_1 /00 ?O.OO 30 121 18 5162 92 C 125 0967 0.000 0 5920297 0.217511 -- -----~~-1}00 _20 30 30 11881 5202 93.93 125 0846 0000 06217274 0 230464 4121/0021 00 30 11 7 602 5193 9381 125 0846 0000 06234897 0 N3454 -- ---- - ----- .-- - -- - - _4g~_,'QO_2_!.}.Q 30 119 E.7 5337 9369 125 0852 0000 0637?492 0 25674.4 ____4~:?1 100 _2200 30 12ò 87 56.59 9435 125 0 8~2 0000 0 òè5389 0 2701306 - ----- ~I? 1..'90 ?_~ }-Q 30 12555 5642 9484 125 0852 0000 064130553 0 2840>36 -- -- - _4 '2_1 ~'QO _~9_0 30 1155 5244 9422 125 0852 0000 0632078 0 297234 , - --- - _~2_1 /0_0 ?_~:~ 30 12B 62 5B 49 9379 125 0852 0.000 0673192B 0311259 -- -- - ~i2..~OQ 9_q() 30 '1381'. 5295 9276 125 0852 0000 04532855 0 320;-02 ~ - -~~-~QQ.Q-~Q 30 808 34 3B 9216 125 0822 0000 0 41f.;¡1 0 329385' 4122100 1 00 30 1361B 136:' 9255 1.25 0806 0.000 0 3:-380:'2 0336756. ---- -----...-- 99B 9157 125 0806 0.000 0 58~.2046 0 348948 4'22'00 1 30 30 13392 --- - --------- -- - 8094 9368 125 0777 0000 0 3588504 0 356424 . - -- - ~~~/QQ- ~-Q9 30 13462 ----- ~-,2?~QQ ?_39 JO 1:,9~, 1349 9484 125 078J 0.000 0.4102382t. 0365057 - .. __~_22100__~ 0Q 30 153 3~, 1259 9397 125 0783 0 OCtO 04063742 0 373523 - 4,'2..?':QQ_~_3.Q 30 1427f, 17 16 9307 125 078 0.000 03603421 038103;- - - - --~ :2~~Q9_,,-q9 30 14303 1746 929 125 0.764 0.000 Oo211Õ3:<36 0 3897(4)' - 4-,'2?qsJ- 4._3() 30 1024 9 1755 9304 125 0764 0000 04168252 0 398388 , 4:22.:00 590 30 14ij 53 175:' -}351 125 (1772 0000 0 4 1 6~. 1 7f. 0 .107065 4~22"09 ~ .39 30 14762 1778 939:' 125 0772 0001) 04)97'8:' 0 41622f. - 4. ~?-'.9.o- 6__°') 30 9338 2854 908ò 125 077 OOOC' 0439(1447 0425373 -. ---_",,:!'~'QQ6_32 :<0 12461 2383 9322 125 077 0000 04483264 0404514 4 2}'~)9 ~ 09 30 12504 2371 941 125 077 0000 0447917 0 413846 ' - -- -- _~~2~~'00 7.. 3,} jO 12301 2'355 9434 125 077 0000 0 484~.1).1<. 0423941. ~,22'PQ ~_og 30 12504 2389 9486 125 0784 0000 04792321 0433925 --~-~?'Q9J3_;!Q 30 1::'617 23 €-5 9544 12:- 0784 0 000 04809654 0443902';) .~ - -. -- ~.]_2!9.Q.~.Qg 30 12586 2339 9535 125 0784 0000 048171~ 9 04511002 4:22,009.30 30 126 , 3 2383 9537 125 0774 0000 04873606 0 464 1 55 - -~~ ii~!~_:it~ 30 12551 2361 9523 125 0774 0000 0.4B7212 0474305 30 12691 2393 9512 125 0774 0.000 04874:.07 0484461 11'22:001100 30 126 79 2361 9509 125 0774 0000 0 4892495 0494653 - --_~i.2:?¿QQï} 30 30 12722 2355 9537 1.25 0774 0000 04912422 0 504888 4::??'QQ )-~ 90 30 12808 2369 9583 125 0778 0000 0 4909961 0515117 4.22/00 I 2 30 30 12854 2406 9571 125 0778 0000 -'.:~ 0.4B95306 0525315 --=~~.'-2j¿Q~ iXQ.Q 30 1213 83 2338 94.B 1.25 0.778 0.000 0200 04900164 0.535:.24 - ~'?~QO 1l~.Q 30 12827 2383 9394 125 0779 0000 0200 04894003 054572 . --___~l~2~QO_.! '!...~ì 30 128 OJ 23.22 9348 125 0779 0000 0200 04905673 0 55594 - --- -~:'?2../QQ.~~ 30 128..13 2:i.14 9314 1 2:. 0.179 0.000 0200 04897297 0566137 - _n _4 ~?£'QQ~~QQ 3(1 12897 236 9304 125 0.779 0.000 0200 04¡122027 0576:192 - 4 22,'00 15 30 30 1)1) 45 235 9332 125 0779 0.000 0200 04991893 0586791 ! - ~_~4.2?~'91ïj_"f..QQ 30 1202 38 2612 93.42 1.25 0779 0000 0200 05049212 0597311 _4,:?2.:QQ_.12.1Q )0 12582 2584 9377 1 2: 0779 0 000 0200 0 50694 '3 0.60;'872 . ~ '?2..'99 _1_~ 0_(1 30 12562 2:.85 9405 1 2:, 0779 0000 0200 050022437 0618377 02 '2~'Q.0 ) !_3Q 3(1 126402 25.63 9386 125 0785 0000 0200 0 5056344 0628911 .1 ~2 OÚ 1800 '30 12578 2:,11 9375 , 25 0785 0000 0200 \) 4993043 0638043 .."f "'-" Page 1 ~~ COMPANY: ARCO Alaska. Ine SURFACE TESTING REPORT 0 HALLIBURTON FIELD: Wildcat GAS FLOW RATE ~",. Lease: Nanuk CALCULATIONS Well # 2 ARCa Alaska, Inc. HI.STAGE METER RUN SIZE: i.Zi1:. LO-ST AGE METER RUN SIZE: DATElrIME 1i'.S I AGE SEPARATORCONDn .0...5 TIME srATIC D!FF QAST ORIFICE' QAS QR H2S CO2 mIdl)or hr "'" (mln) (P8'1I) .(" we) (d811 F) :(';,cht.) (8,...1) (þpm) (%) {m8rl/ct ~l::IOO 1830 30 I :.~. ~,EI :»4 i'1ì °31B 1.25 07B5 0.000 0 ~no 0 JO:'3B49 _~~2100 19 (10 30 I:'F.~' 2505 '1J êS 1.25 07B5 0.000 0 ::'(10 0 ~,O 1 70Ç',7 ---__~;>2!22...!J ~I 30 127 ~ì ..J ~8 9) )f, 1.25 (1 778 0.000 0200 (ì ~O~tlj 75 '-- J'~2!OO ~O (in 30 I~':' Q:' :'~. 3 I 0) I~. 1.25 (1 778 0.000 (1 )('10 0 ~.nr.7QI1 - M:,:~rlQ ~ ~ 30 I :.ç, 1)(. ::~ J i 9310 1.25 0778 0.000 (i 100 (I ~.i1~~~01 -_u_~/~'::IOO 21_0,9 30 I~~ ~9 ~~I 9~-J 937J 1.25 0778 0.000 03('10 (1 ~.1 :.4:'<i9 4!=:2'OO o£.JI ..,(\ 30 1 :".. ~.:~ ~:. I' 91:'9 1.25 0:'8 0.000 (I )110 0 ~.1 ('2'.'~7 _.~2.?!l1n :'J~ on 30 ,:,03f, 2~...9 9J (II 1.25 078 0.000 Ú 300 (i ~(lE':'f.:! 1 --_4~~/QOj'2 '4(1 30 1:'9 ~9 :?~ <.q 04;'1 1.25 0 i8 0.000 (I -'00 0 ~.f10~.J 12 -. 4122100 :':~ 00 30 14[. ~ ~2 :'4 9~,~) 1.25 0778 0.000 0300 0 ~.(('7J07 --~/:'~'/n(J :'3.l!.1 30 14::1 3E1 220g 9~.::S 1.25 (1:78 0.000 (1 JOO 0 J']97<.:~1 - 4/~~~~ (I( 30 14)fl1 ~fA 9~)7 1.25 () 77'8 0.000 0 :'00 (1 <.i)~.O I 09 ----.- _Jli)IOO II ~(I 30 14~' '.9 :J~' [.7 ~5 .1 1,25 0778 0.000 (I ~'f)0 0 ~.i1'¡ 7J;'4 ---__J~~~/~!..~~ 30 IJ4 ~o ~~:! t-.4 95 ",~~ 1.25 (1778 0.000 02no 0 :->(.40'.37 .--- ~~1/(¡{1 I.. ;'fl 30 14) F:J7 2:' f,1 94 tl4 1.25 0776 0.000 0 ~OO 0 ~,r('4 ~.48 I --- 41:>1!0{1 :' (1'1 30 14':\:'7 2;,' J4 944:' 1.25 0776 0.000 (1200 0 ~.O:('449 ,-"i ._~~:;!!OO ~' ~~I 30 IJ:' 76 2:: :'5 94 2~.¡ 1.25 0 i76 0.000 '1 :'00 n ~.{j:'7J~~4 --~yoo 3 (~O 30 14J J7 ¿~. 5 94 :.) 1.25 0776 0.000 0 ~Oo (1 ~(1;'4JI31 - 4!¿o3/00 ) :.0 30 14... 0;1 22[.4 ~J b 1.25 0778 0.000 0 ~'OO 0 5DЀ.5a7 -- ~~?':\I(IO 4 00 30 14[. ~.:. 2292 9487 1.25 0778 0.000 (¡ ~(l0 rJ ~14J.479 _4!¿o)!0(, 430 30 14716 :a 96 949 1.25 0778 0.000 0 ~'OO 0 "'4C1'66 4123100~. 0(1 30 14[. 3 ;'312 9~: 1.25 0778 0.000 (. :'<.0 0 ~,'4E<~4 412:lïoo ~ 3Ô 30 14739 :»352 9~.d7 1.25 0778 0.000 f) ~'~.O 0 ~1r.1~'16 -- 4/¡')/(J() 6 00 30 14f.96 23)5 9~ ~~. 1.25 0778 0.000 0 :-~.O 0 ~, 7:'Q(l4 ._4/23/00 630 30 147 If. 2J )2 C¡<. fCl 1.25 0778 0.000 0 ~'~.O (¡ 51 f,7 ..'37 J/;>:'/OO :' 00 30 IJ731 2341 9~ 7) 1.25 0 Ti8 0.000 0 :'''0 0 ~173122 4/23/(10 7 1(¡ 30 141) B~. 2:.:1 9~. f,9 1.25 0778 0.000 (¡ 2~0 (I <, 1f41 a8 ---- 4/23/('10 B no 30 l47a2 "~1 r. 9~~) 1.25 ('1778 0.000 0 ~'~.O 0 ~.1C11F157 4/23/()(I a :10 30 14751 £I:' 14 9599 1.25 0778 0.000 0 ~~.O 0 5:> I ~.Fil1 --- ~~!_OO 9 OQ 30 14£< 9~. ...3 J4 9~ f.I 1.25 0778 0.000 0 ¿'~,O (J ~.¡. ¿~,rj~~7 412':\/00 0 :.('1 30 14~. 14 ~,) 72 9~. R 1.25 0 778 0.000 [. :'50 0 ~~. :'4 ~,;:¡9 --:1'2)/(¡(1 10 O(! 30 '~.O 47 :'>:1 71) 9J 9 1.25 0778 0.000 0 2~.0 (I ~¿o4(JÍ189 J/2:!/00 10 :'0 30 IJ92f, 2313 94 49 1.25 0 i78 0.000 0 2~0 (1 :.:;<42J96 - J!2)!00 I 1 00 30 1491 2Hi 9~ ~7 1.25 0778 0.000 (1 ;>~.O (I ~.25(1Q2.1 - JI2)/QO 11 :19 30 ' ~(J £<fj 2:" ;"7 ~~J .12 1.25 0778 0.000 (I :.~.O (I ~1:,..;]77 4!2)/(¡0 12 0(1 30 1 ~(J 62 2J 14 95 £1 1.25 ('1778 0.000 0 :'~.O (1 ~.?~.5~O3 J/.:':\!ÕOI2 :'0 30 149 J2 :»)<; 94 ~7 1.25 0718 0.000 0200 ('I ~..€,5)' 8 J/~3/0(J I:, 00 30 1 ~.'1 ~,1 ~3 71 ~~. 1.25 078 0.000 0 ~'( O 0 ~.~'cl(I~.24 4i~1/00 1))0 30 ,~:. If' ~J 72. 95 f.7 1.25 078 0.000 0 ~'OO Ú ~,~'f\t.4(J9 -----¡f2:l100 ! 4 CIO 30 1~1 71 :-3 £1J I:J~. ~5 1.25 078 0.000 0200 0 5..009<>2 4!:' .1!00 14 "0 30 'f,rl b;' ..I '9 93 :-J 1.25 078 0.000 0 :-00 (I ~.I 7~.M8 -- .í:Q5iorl 1 ~ rJO 30 ' 6(' 44 .., 'j ~~I 87 1.25 078 0.000 0200 0 ~ ;yJ29 -J/2:1/00 I ~ :.(1 30 IJ609 :'8 :.1) 96 :'S 1.25 CI78 0.000 O..CIO 0 ~,~ I 7773 4i..3iOO If, QO 30 I 3t1 5~. ~'B 97 95 ~~ 1.25 078 0.000 (1 :'00 0 5325OJ8 J/~':1/00 1& :10 30 1~E. 2~J :1296 9~ 49 1.25 078 0.000 0200 0 ~6.:'9;'>O9 412:1100 1 7 (1(! 30 '2b 01 3539 95Y~ 1.25 078 0.000 0280 0 5£f49;>69 J/;>3/00 173('1 30 1~5 12 31 Jl 9~ :'_1 1.25 0 7~6 0.000 0 2i10 0 ~545896 -----:if 2 3/00 Iëi(i(ï 30 12J 61 333 94~) 1.25 07136 0.000 0280 0 ~5707 4123/00 1 FI 30 30 I~'f, 67 31 ~4 9~.~.J 1.25 (1 786 0.000 0280 0 ~,r.4~:'.9 4/2~0() 1 9 00 30 11~, 07 4013 9~ 49 1.25 0786 0.000 0:'>80 0 60f.6964 4123#)(1 19 3n 30 III :'f, 41):,g 9~ 61 1.25 () 786 0.000 0280 0 5Q26)58 ---~J.1IO(J 20 (10 30 lOB 57 44 )<; I]~ f.4 1.25 0786 0.000 0280 0 6069904 4/23/00 2(1 30 30 10681 4647 9~ E>4 1.25 07£16 0.000 02BO 06171159 4/:>3!00 21 on 30 10724 422 95 B7 1.25 0786 0.000 0280 0 £043226 _~.JIOO 21 :.(1 30 10787 42 (15 95 9~ 1.25 0782 0.000 02fl0 0 [.1494(16 J/¡')/(10 i<' Oll 30 '07 17 JO BI 96 ~£1 1.25 0782 0.000 02BO 061)2:.'4.4 4/."3/00 ~'2 30 30 113 If. JI1\9 9656 1.25 0782 0.000 0 ~tlO 0 &1452~5 41:')!00 23 00 30 11;:'"77 41 ~.5 9677 1.25 07B2 0.000 0280 061614&2 ----¡¡-:?:!IOO :'3 30 30 1142' 4237 C¡7 1.25 0782 0.000 0280 0 f,091 722 ---- J/:'41('1('1 0 (1(1 30 1 If. 8" )y 4i'j 969J 1.25 0782 0.000 0280 06'02:'14 --4!:F.ÙOCi ( :ij 30 110 (14 JI02 9f. ;'B 1.25 (1 7£12 0.000 0 ~'80 0 t.099fl:'6 Page 2 ~~ COMPANY: ARCO Alaska. Ine SURFACE TESTING REPORT 0 HALLIBURTON FIELD: Wildcat GAS FLOW RATE ~",. Lease: Nanuk CALCULATIONS Well # 2 ARCa Alaska, Inc. HI.STAGE METER RUN SIZE: LID: Lo-ST AGE METER RUN SIZE: DATEfTlME HI-STAGE SEPARATO.R CONDITIONS HI-STAGE TIME STATIC DIFF GAS.T ORIFICE GAS GR H2S CO2 GASRATE GAS CUMM mIdl'Jr hr:mn (rilln) (p8Ig) (" we) (deg F ) (Inehê8) (811'81) (ppm) (%) (m8of/él) (m8of) 4/24/00 1 :00 30 119.39 36.23 96.7 1.25 0.782 0.000 0.280 0.595447 1.3322 -----;;¡ï24/00 1 :30 30 119.12 35.54 96.53 1.25 0.782 0.000 0.280 0.6023865 1.34481 4/24/00 2:00 30 119.08 34.68 96.22 1.25 0.782 0.000 0.280 0.585005 1.35743 4/24/00 2:30 30 120.64 39.04 96.04 1.25 0.782 0.000 0.280 0.6077433 1.37007 ---4/24/00 3:00 30 118.5 39.69 95.95 1.25 0.782 0.000 0.280 0.6042503 1.38272 4/24/00 3:30 30 118.19 37.85 96.03 1.25 0.78 0.000 0.280 0.6138723 1.39544 4/24/00 4:00 30 117.8 40.93 96.15 1.25 0.78 0.000 0.280 0.6095794 1.40819 ---- 4/24/004:30 30 118.19 43.64 94.95 1.25 0.78 0.000 0.280 0.6101226 1.42095 ---~4/oo 5:00 30 117.41 39.62 95.66 1.25 0.772 0.000 0.250 0.6132171 1.43371 4/24/00 5:30 30 119.63 37.16 95.85 1.25 0.772 0.000 0.250 0.5863527 1.44655 --- 4/24/006:00 30 117.91 40.33 96.08 1.25 0.772 0.000 0.250 0.621072 1.45941 - 4/24/00 6:30 30 118.26 44 96.48 1.25 0.772 0.000 0.250 0.6208935 1.47699 ------- 4/24/007:00 30 118.77 39.23 96.36 1.25 0.772 0.000 0.250 0.6203537 1.48992 -- 4/24/00 7:3Ó 30 119.47 41.16 96.24 1.25 0.772 0.000 0.250 0.6199671 1.50283 ----~ï¿¡iõO 8:00 30 118.19 39.39 95.79 1.25 0.772 0.000 0.250 0.6210087 1.51577 ~ =-]'/24100 8:30 30 119.2 40.63 96.03 1.25 0.772 0.000 0.250 0.6226359 1.52874 __~4/00 9:00 30 119.51 39.42 95.93 1.25 0.786 0.000 0.250 0.622843 1.54172 4/24/00 9:30 30 118.34 40.55 96.29 1.25 0.786 0.000 0.250 0.6236784 1.55471 ---- 4/24/00 10:00 30 118.03 43.16 96.81 1.25 0.786 0.000 0.250 0.626158 1.56776 ------'4/24/00 '10:30 30 115.97 44.74 97.3 1.25 0.786 0.000 0.250 0.6286607 1.58085 ------¡Î24ïoo11':00 30 116.12 43.31 97.61 1.25 0.786 0.000 0.250 0.6299871 1.59398 ----4/24/00-11 :30 - 30 114.84 43.57 97.33 1.25 0.786 0.000 0.250 0.6209631 1.60691 .-- 4/24/00 12:00 30 118.38 38.84 96.98 1.25 0.786 0.000 0.280 0.6281828 1.62011 ---4/24/00 12:30 30 119.31 41.43 96.76 1.25 0.786 0.000 0.280 0.6274928 1.63318 .~.~-- 4ï24ìOQ..13:0_0 30 119.47 42.96 97.01 1.25 0.786 0.000 0.280 0.6295838 1.64629 ----- 4/24/00 13:30 30 118.54 42.75 97.77 1.25 0.786 0.000 0.280 0.6268509 1.65935 4/24/00 14:00 30 118.11 43.69 97.57 1.25 0.786 0.000 0.280 0.699109 1.67392 '---4/24io014:30 30 125.12 75.36 96.86 1.25 0.786 0.000 0.280 0.8127809 1.69085 ------¡f24/00 15:0Õ 30 335.32 3.46 98.13 1.25 0.786 0.000 0.280 0.2663115 1.6964 Page 3 --.-J Client Lccati on Service Co. Start D et e .Are 0 LiI"Id Halliburton Energy SetVices 27-ppr-ü0 Country Well Ticket #. U.s.A Nanuk #2 551359 Field Engineer Exploration Chad Nicosi a :~ 1 (f. fih ! 00 000 , ~.,;~.: ({):": " ~' ~4.000 ?t;'¡:: ¡;!)~-: ,. '" ,~:¡ H(1*": :: I"~~:: P<:.k:, C t"O~:s Sir.e 64tro r;'!l( r-q::,: ""!~a ,00(1 . . , .0' ( II:.J .. ; :. ; :: i ; ... " . ,¡ ¡!,: : . ~: : II i ,~¡ ~. 1 i .j: : ~.",wW~~~_~"'_"""''''1_¡p.,--"",-~~~y~~~QQI:_.J , . ~ .~. . , , ,¡. , ~ '.' .~,~ ¡, ~ :~ :: . . h I~ ~t . ~ R. ~ ;r~ ¡ ,!L ~ ~ 1'I~j ¡IH¡,..L,. ~~: iY~'~¡~~: : '~j ~il ~,{~,,~~.~ I ¡:. ~ ~ ¡ : ~ ~~f rr. ~ ~ ~~ ' J= I :~~ ! . f' =( ~ '.:: I ~ f~ f w:' .lh...,I ~_:~:~ lJ ~, : '¡ 42 000 . ~ I I I I . 19-.Apr-D0 20..ft.p--00 21..ft.pr-00 22-ftpr-OO 23..ft.p--00 24..ft.pr-OO 01 :00:00 03:48:00 06:36:00 09:24:00 12:12:00 15:00:00 ",-"J Time Client Location Service Co. Start Dàe Þrco Lend Halliburton EnErgy Services 27-Þpr-DO Country Well Ticket # U.S.A Nanuk #2 551359 Field Engineer Exploration Chad Nicosia ,¡:::) :'s) s 5.(11..1(1 ¡ ¡ ~ \ ¡ ¡ ,', ~:) ;)..\:,~ n.......".."..., "''''''''''''''''''''''r-' , ¡ ,'. .................................... '" ',."............n....................-....,.... "'."""" '...'.. '............. .......................................... .~ j:8:8) ! ".-... ! ¡ ".." J)., . I ¡ ~~. ~ . . .' jjj . . '''I'''((~',' : ~\' ;~:. . . ~,~~ ' . . . . .' . .. .." . ' .." ,",on, . . . , ,."." . . ~It . . .' . .: ~ . ".' . , 1 ¡ff'I"'''' ,. . . . . 3001) .' \ ,'s '~, ~ . I' ""¡-¡;~!,, I j~ , : ".. ¡ . ~.. .,.,.< '1",' . , . \ Mr.I')'"F"""'" ,I .'. J ....~, . .i! ' ! 2000 "~.1}~<1!"1 Î. .' :1 .........."""""""""",' :l'"'' . r~'W11!;=-'''''' .,'"'.N. . I! -: > , ........., ......, """....",.." "" - ' : fKfll "1 ~ -T . r'-' --" ._...~.....,~.J ".. 21-Þpr -DO 12:00:00 22-A¡:r -00 03:00:00 22-Apr-00 18:00:00 23-Þpr -DO 0800:00 24-A¡:r -00 00:00:00 fJJ.JIj¡j........ ....... 24-Apr-00 15:00:00 Time Client Lc:cati on Service Co. Start Dåe ,Arco Lmd Halliburton Energy Services 27-,Apr.oO Country Well Ticket #- U.S.A Nanuk #2 551359 Field Engineer Exploration Chad Nicosi a ~ r - - -i..::~~I- .~;-<.~._~ < ~ ~ ~ ~ ~ ~ I < ,:> ))(1 ~.................. .... .~.: ......... ... ;:. . ....... ................ ..................-............ .. ........... ........ .... .. . ... . ....... "" ...."" .." ... ......... ."'"'''' ........ .... ............ ... ........ .....; ¡".. 0130 1,,,,,1 !~ a' ~ ~ t¡' ¡ ji~'¡w~¡~~'<' l.~,~~'fr.rnnn "",,1":-.-, 1~1 ~ .. i ,l' I il ~u ~ ..~~~~"Jl.aJ" I~A ~~ ~, "'~'.~:..:'~~ ~,',: .,h,I......, I.'!::, ! r ' 1 '1 . r' i¡JI'~ ' : ,'If flow' ~ I : '4+,~,': . .. '1 1 , ...................................""... ",,,...",,,.. '"'' " t f EDr~JO¡!I,.V ~" il:i. ~. ~ ¡ ; '11' i . .. ..... ...... - .. .... ........... ..... .. .. '''''''''''''' ......., .~" .coo ~I. àWh!~' :: II '.I '.I:'.I',lt ~J : ..~ i ~i ~!11 : ~ / ~ :.;; YtJ.~ if.'Œ 01'10 :.:(( ('DO 21 -,ßpr.oO 12:00:00 22-Ap--OO 03:00:00 22-Apr-00 18:00:00 23-,Apr .00 09; 00: 00 24-Ap--OO 00:00:00 ,( (ot) 24-Apr-OO 15: 00:00 Time Client Location Service Co. Start D Ii e ftlco Lend Halliburton Energy SelVices 27-,Ilpr-OO Country Well Ticket # U.S.A N anuk #2 551359 Field Engineer Exploration Chad Nicosi a .~ . ... . . . ....... ¡Ii[¡~~, ;g~¥,i;;r ' ! ¡ dl~! ~L"~' ~._I\_~ Lou.. ~~ ~ -j~,,~, ....illJ JuIJh 1,",fm"'rFIv\'''' , . .... , '::,.' ~ . '1J~~~"'1'.~' .~ '~~ I.., .- . ~ .,0' : ~ ; ¡ ... ..........................' ¡ : > : : - i i ¡ i: ,~ : j ~'~~~W' '~si'1;":;. ¡; !, ¡ ì.~~~i~!~)tm~¡¡:~(W~¡ ';':. :=-:-.;;.; ';.;;:;;:;;.';'. ';('1 ' : :: 1 : r~ ~~_n'''''''';'''t--''»WWV'''-1....,_..Ym'.~nn_Nw~", ~ ¡:'iWäl1iUY ! ¡ : l~1¡!T1 ¡i. ¡! i ! . 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" ". - -. - - . - - - '~, 4n) mo , i ~: ~ I ! ,¡ I " : .. :!~, 'J~ ~,r :: ': < ; §I d.1 . ;:~ 1~'~:II;~':t . < r' ¡¡ 1! i I n', '¡,Il¡ f " . . , ; I II ~ ~ ! ~ ' ~ ~ ) J,I'; ~ 21-,Apr .JJO 12:00:00 Client Locati on Service Co. Start D et e ftrco LfOd Halliburton Energy Services 27 -ftpr.{)O ;1 i ;, :" ¡ ~ ~ > ~. 22-A :f -00 03:00:00 Country Well Ticket # 22-Apr-00 18:00:00 U.S.A Nanuk #2 551359 Time Field Engineer 23-,åpr .JJO 09:00:00 24-Ap' -00 00:00:00 Exploration Chad Nicosi a : 1O)J 1100 . .; 2{(I, XKI ;Y In 24-Apr-00 15:00:00 GHALlIBURTON ~~ ~~ ARCO Alaska, Inc. WHP/Oil Rate COMPANY: FIELD: Lease: Well#: 1--- Well Head Pressure (psig) - Oil Rate (bbl/day) I ,,-. 2000 1800 1600 1400 1200 '6; 'w .e: 1000 D.. :J: :: 800 ,- 600 400 200 0 4/18/00 0:00 ,. -. ø . " 4 , to .. . ARCO Alaska,lnc Wildcat Nanuk 2 . ,', ~I ' " .. I" j 7: V ~' ~.~ . . '~P> ,:'; ,,'.' ,,~~ . ",Jt'. ,p-... ;.1., ", , . ," ..,~, 1 " ,~:, . , , ' 4/19/00 0:00 4/20/00 0:00 4/21/000:00 Time ~ 4/22/000:00 4/23/00 0:00 J 4/24/00 0:00 1600 - 1400 - 1200 - 1000 ~ - 800 :g .a e. Q) -600 ~ Õ - 400 - 200 06 - 0 -200 4/25/00 0:00 ~~ ~~ 0 HALLIBURTON ~ 0.9 0.8 ,--- >: 0.7 as " t 0.6 U) E 0.5 E "-" CI) 0.4 ... as a: 0.3 U) ~ 0.2 0.1 0 4/21/00 0:00 COMPANY: FIELD: Lease: Well#: ARca Alaska, Inc. Gas Rate Vs. Water Rate I-+- Gas Rate (MMscf/day) - Water Rate (bbl/day) I " ARCO Alaska,lnc Wildcat Nanuk 2 - -~ ~~ ~,~'"V^~'.L~~ . , 4/21/00 12:00 4/22/00 0:00 4/22/00 12:00 4/23/00 0:00 Time 4/23/00 12:00 4/24/00 0:00 4 ~ 4/24/00 12:00 1800 1600 1400 1200 1000 800 600 400 200 0 4/25/00 0:00 0 HALLIBURTON ~~ ~~ COMPANY: FIELD: ARCO Alaska, Inc. Lease: Weill: ARCO Alaska,lnc Wildcat Nanuk 2 BS&W VS. Oil Rate ~ -+-BS&W -Oil Rate (bbl/day) I . 1600 - 1400 .- 1 0.9 0.8 . ~~ . " ~ ~:: ~ ~~.: ,J.~~VtJ\ 3: 0.5 p. f1 . ~ " .- It .. ~ ~:: ., .rr.~,~~'~~"..~.~~. ".y.' ,~:'~ ::',~' ~'.~~: ~ - 400 S 0.2 ¡ , ~ '. 0.1 .' . 0 I .. .0 ,. . I 0 4/18/000:00 4/19/00 0:00 4/20/00 0:00 4/21/00 0:00 4/22/00 0:00 4/23/00 0:00 4/24/00 0:00 4/25/00 0:00 Time . . . - 1200 >:: as "C -- 1 000 ::::: .c .c 800 ....... CD ..... as - 600 a: - 200 0 HALLIBURTON ~~ ~~ COMPANY: FIELD: ARCO Alaska, Inc. Lease: Well#: ARCO Alaska,lnc Wildcat Nanuk 2 Choke Size Vs. WHP 1- Choke Size - WHP I 60 50 CD 40 .!::! en ~ 30 0 .c 0 20 ~ 10 700 - 600 ..~.. , .. .. .. ... -- 500 II . ~- , - ~, " - A. J ....... m - 400 ëñ c. --- a. - 300 :I: 3: - 200 . If - \ -- , ~~".,,; , ~' l"{\ '" .r"1\.. ~, "rt' ."'" ~~j , 1 -, U it ' - I 4 t . . .. I -, - - - j-, J- ~. r-t,') ',," 0 I ,~, " 0 4/18/000:00 4/19/000:00 4/20/000:00 4/21/000:00 4/22/000:00 4/23/000:00 4/24/000:00 4/25/000:00 Time - 100 0 HALLIBURTON ~~ ~~ COMPANY: FIELD: Lease: Well#: ARca Alaska, Inc. WHP Vs. Gas Rate 1.-.- WHP - Gas Rate I 450 400 ARCO Alaska,lnc Wildcat Nanuk 2 ., - ^ ~ ."......,¡Â". ~I&,~-"N'~~,~ ,--I".¡..~,~I fl. . 9' lJ \~ ..-. 350 0) ëñ .e: 300 a. :r: == 250 ~.. . ~ . . I 4 ,~...n..........v....._....,..1 ~.l....-.J"" ..................".......... ,.....,.. ......... ......... ,- .. ryn " 200 150 4/21/00 0:00 4/21/00 12:00 4/22/00 0:00 4/22/00 12:00 4/23/00 0:00 Time 4/23/00 12:00 4/24/00 0:00 4/24/00 12:00 2.5 ..-... -2 ~ ;E ..... (J - 1.5 ~ :E --- -1 .! as a: en - 0.5 ~ 0 4/25/00 0:00 r":' l'.I~ f I I"" P'i .. Ii' r,t ~:~ ~~ o?'l'; tJrJ \ r:~':' n: ,~~. r"~ (Ii.:. ....;' tI,:'~j 1.11:4 .i".it :II' ~,1:- .;.. " :...'f ~"V ~'.rlf Þi,7 '?iJ'i ...~ f.S II H~ ~r: l r:i '.":11,1., I. ~ ~ ~t t. ~ ;.~I' ~i t41:' :"l ..I I' ":t..: .: '.11' ~( .. ,~(' rl,l ~ ì": oj I I~',I": ':II' .: ~,~ ?I ':'IiI~ ..M' ;i.~ ':In" r;~ ~r',1 II ~ r: I,'~ 1:11 ? 'J..": I.II~ ;..i I.' I ~ i.." .IJ~ i..~ ..,:'! 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I..:: '."'.u I.": :p~ f'nj,,U,',j 1.1[11; 1:'( I. '.'1.' ~ 1 't 1,":1. '.".'I:I't 'J'W "':'1] (",II' II'"IPI ~N (u: j 1:..:- I: I ,. ':":' ~ 1:11:' ': I 'I' '.11: .;. 1.'(' ,; 1 ,. '.":10;.1.'1.',:,1'1' '.of r '.":' ..; ~ 't '.".'1 ':":"':,1'1 ')1, l lll:, ': I 't ,.'<.(',.',.'..1'1 .,.I U: ~IC:I r&.l'.u, :r. flJl,jw,'I::i ¡.Ii'I: '.n: ~ (II.' ': I" I:") ,~ (11.1': I 't UW III Ji\,o¡:,IW 5>1 I::f'lf W 31::1 3WIJ/31 'If a 1.1:I0d31:1 ÐNJl.S31 3::>V:ll:lnS S3::>IAI:I3S AÐI:J3N3 N01I:JnSI11VH HALLIBURTON ENERGY SERVICES SURFACE TESTING REPORT DATE/TIME REMAFlKS mlcL'Y r "r mn '" i'"' ,'u", ~ ,',,", .\ ¡(II:"", ~ )':. . , ~C. .:.C. ,.:,,'. '" ~ I' (.,", ~ ~I" ,= II :o:...I'ilI:Wr,:J' N': :I~ ,", .;:rt ITW', " ~ ,', ,"u", I~I "11'1 '" :.,,", (." h' :u', .1 ~'I:II'I(' t I .:..:. ~ .:.,(. (II'" 1 I ~(I ." ,,:,', I'II~ I~ (..:. .2.:..,',,"..". ':..' }I'I ,,:..,", (":. I ~ ( ,¡:. " .::. I' I"" 1:4 ,~I'I '" ¿'"I ,...:. I J ':":1 .s. ~ ,', '"11,1 1.1 ~rl .t :,", ,'..", ,~ (.,', .1 :. ':. .:,1". I ~ ~'.I .I. ~I'II''':I I'; .:,,', ...:.. ,', ,'..:, ,~ ~U.' .I" ;.,", (,,:. ''''' f,," .1 :..,,", ""~I ,'" :l,", .1 ¿,", ,',(" I~ ,'M", '" ;:,", ':,.:' '1;4 ..'(1 "",", ,'..", I,:' ,:..', t ':'(1 I":' I ~ ,~I'I J :. ,', ':":' ':'~:I ,,"..:. '" ~"II'" :.:. :11', ,,:..", ':'1) i:' ':'(1 t ,,", ,:.(1 :!' J(I .1 : ,', f'(1 ¿;¡" (M" "" ~II (..:. II ,:..:. ",.:.,,", (II:' ~~ .:11'. ",:",'~ (.n ~;\ ),", "'Z,.:,11 f) "11" t.:. , (II:' (I J,', 4. ~ , ~I"I I,:h:, '" ~' 1 (II~' 1 ,:I.'. '" ~ , .:11:, ~ ('II' ,,~' 1 .:1(1 ¡. ..11. ,.:' ,"'':' :~ (11:' '" ~'I (11'1 J J... "';!' ~h'l :I (,,) '" ~ , ,:11"' .I ~.'. ,,:' (1(1 50'"' '" " (II:' ~ .~-:I '\'';' ')(1 f)o (.(. " ~, 'I~" ,?, ~t:' '" ¡' I I"'~I ~ 1,,(. '" ~ I ('~I . ~I" "'~ , (1(1 f' (11"1 4. i , '1:.(' (4 JI) . , ~ 1")(' ç. (.(. I~'" I.:.~I ~'''''np ~ ~ 1 (II,"' ,:.. F' ,,"',I ::,."ar:rr,] N': )~(I ':.o"!f md'". "''::'1 1"1(1 I~I (";, :,I,.:.,.,'!'] I:' II:... lj",nJ ~PIl!"I :a': I . ,:.' 1 '11(1 10 y. ,,=, I'll) II t:'M"1 E'I) r: 1I:1j, -::~'='IB':' .¡, ':'1')'"1 I I ,~'"I ~~"........................, í HALLIBURTON WELLHEAD CONDITIONS WHP WHT CßG CHOICE (p'llg) (-::11'9 F I Ipslg, (&4Ih'J) I~ ~ I;":, ~If. I~ "'¿'~ ~-r; 1~ 2')1 , I f.U I~ ... ':0 ."1 1~ I~~ ? ~:: "'':~ ,- ~ ¿.. .~ ~. ) ~ . ~(I ~ ,:.. 1~ ¿ I r:- ¿ ~.4 i.~. . ),:,'::! 1f! ~'~ ';.t,:' ~..I ~I~ .)':Ir:- .1'=' ¿)I;I I:I~ ,~ ¿;.. :-) 1 :.: ~~ )..J'~ ~ ',:'~ '" )1". ~J 1f.1 ¿'1'1~.. :., ~) .. . )(1 ,';" ~~ ""~J ~S U .11 oS~ 1f! ..')) -:~;: ~~n ':")1',:'''' 1P. ",..", ..... r:a~1 ~'2 "',:-2 "'I 1~ .:. :'~ ~I ~~. ':' ~ -:'~:\II . p. i.')';' .I'" ~~, ..~ ~ ),.' ~ 18 2u: ~'" ~. ~ ~ 7~2 I'~ oiP. IÇo,:t ~, '.IS < ~ .,:u ~p. 1~ .I'"";' ~ ~I~ i.~ . :'':' "'~, . ~ ':~". oJ:" ~~. ~ ) '" 1~ "'~ . ~ ¿'J-: ~J~ 8.~ ~ I ~ :'~ .s I . ~ ) ~oS ~ I ~~ [I~ . ':1'::::' 18 ~~ ~ s ~.S ,~. '" :'2~.J 18 ~:,,", ,:..~ a.~ (" ~ :'~ i ~ 1":- ~~:.. ~S .¡ "':': 4~ 1~ i.~.? ~,'¡ ~~ ~~, ':1.01" I.c1 ~.,I 'p ".,,:, .1 ~ ~:' 1~ ¿.~.. ~ I r;1 P.7 ~: ., ~ ;..:' 1~ .: ~~, ~. ~- ~- -, ;' ~ 18 ¿";" I .u ~'" '='''' ""~ S! 1P :':'~~ ."..s P.' ~ 1 ., ::- '9"'? 1~ 2"':': S~ ~., ':)" 7' ~ ~I;' 4~ ~~ ~ (,~ ~., t~ .,::- ~¡, oil.l .:~~, ~ I ~- 5~ ,:, ~ ~~ .11.\ ~'!~. .I ~., ~~ '" I~" ~.: 1~ , :-::. 1~ '='~ ~J ~ ..~ ~~ 1P. ~ ,:.:. .) ~7 (I~" ~.~ ;;:.1 1~ ~,~..¡ r...~ ~. ':1~' ..;¡.:"~ ',:',J .\1.1 ¡~ ,:. "~ ~~ , ~,.;..:a~ 1~ i..J ~"1 ~~ J. ~ . ~I.I¿ 011.\ ,2:¿ ~J ~.' ~.;. H .¡.q .:~ ~ 7) f\~ l'o¡. ~..'.:' ~I 4';' ~'5:' ~ ~~n ~"",:'~, ~ .:'!"'3 ~~ F~.I a:."';':J .!~ ¿~ ~ ,¿ ~? .t ,:. ~. ~ ~I;" . ~ i.:~,' '" ~ ~7 ? I fo';",:' '-:' .!~ '':'(1 ~{.. f3! ':"4 .;..;~('I';' . ~ )1.17 ~',,:. %';'~' 1f.I:" ~! .18 :.If' ',;..t.:' ~., ~ s ~H .~ 1P ';'''~I:I 'U ~"'';:~ If.f" ~,.. .If. 2.~ ~ ~:"? ~,I? I~ .\1.1 I~{...s. f . .11.1 If.!~ (II 48 1" ~If;, ~':a ~"',:' Fi.~1 ,:101 Jl4 i.! (I .1,:' ð!. ~. If!'; .1;1 5~ ':'.~ t ~;" I ~.f~ ,:.., 1b ~7""~ ~.., '=' '!l-:: ~~ "Po I~~ 14 .~.:'~ ,=~I ~ 1~ ~J(I.U: ~I)" ;.t ~ ~'" 4P ~~ ~",. ARCO Alaska, Inc. TOTAL GAS GAS RATE I 13.5 ClIMM (I1'Imsc1/-:I) [ ,(mms.:I) COR, VOL ¡SIb) , , " " . ... . . .. , ' I -. ,;; -.., , , ..- .. . . : ,:", :' , ",' :' :':' "'~ :', '.', ""~':" ,,:':. , ' ,: ,,: ':,~ ;.. . 0: ." , .. . .' ,,,. ,. ,,-" I . '" '" Page 2 T01 AL OIL OILRA TE OIL CUM'" (slb/d) (billS) :~~I"I "I~ 11=,"'. ~.) ~(II"I '(I ,,~S .1:' 1) ~ (I:' ~ ~~ ~~I If!1(1 II:. .,",J ~~ ~. ¿ I) . I r;1 Ij~, ~.(,:, ,'(1 '" ¿ ,:. ~J ~.~ I~' ., J I ].J ""u: I"I~ ..~ ':1 (II ,.. ~~ 1J .~ j :~~ ".J~;..~ -:..':..c ~I"'J 1(1 . ~.., 4!. . ~¡ "" ..~,:.. ¿~, ~ ~ JI ~ II~ '!4:- ~,~ (..:. ~.:' If~ ~(I' ."1 ~~, I' ~;..~ '2 f\4 S 4.1 s.).:: II ~~ ~,~ oUJ ':.. ~I':.s .,.., . :'~ ,~. ~f:'I:'~. ~') -c, '3p'.~ ';.." 11:'."1 .,"1 ~';"';" ':''' :.':.,:. ~I"I ':0;.""1"'" :U:I.I'"W '~¿ '" " ¡~~ I:"; ',:':-:1 II J.:a '!":' "....s,: ;.r:o .I;!:I I ~ ~~ ',:'~ ~;..'!' I~ :'.. , I: .I~ I:. ~:. ~r;1~~, .;...: I) ""II~I 1 ¿ ~ ~.,),,: ,:'1 1('1;:' )~ ~ ~'!', I~ '1"': s ~~ ~.~ I¿ ""1)'; :'~ I ':."1 ~¡, ,(.~~.. ."1 J~ '"1 ~ ~ ,,",~ ';" ~I" ~'"IJ ,:'2 1(1.:a, '~I"I """IJ 1.1, II:' ~~"¡ ~,,, ~" r :,,", "(''''-:-J f'"I~ I¡ '1";""":" I '':':. ~..: '1J3 h ~:.~ ~~ II!>I S~ '!'Jf,'1 ,~ "~.S "2 ,:""1. ~J:t "~J e.:: ~..I(I I:t "';'. U ~.~ ''': I':(I'~ I~ ~~I:' ;..,: I~"::~ ¿. ~ )~' ,. '': .t ~ ~"I )I: ~ .:.- I:'!o I I~" ~.~.;t I,:: I:,,) u ~:..? ,¡ I:': .,~. ':'13 oS.~ '(1 ''¿'~~ "'1 ~""4 1(' I":' ~~ ;"(. ~I'I" ".," ~i' ,- 1:11',:' ,:":' 1:t~(1 I~ q!~}J J.;'J I:.~' ':'.1' ~,. EI~(' , ~I I)~ ~I .I I COMPANY: FIELD: LEASE: WELL#: Sales Order: API a,O.R (@ ~O,) C~~~,'SJb). : ...? : ".'''''. ~ :, ',': ~ ::::::; ~ ,.. .:...: ' , , . . ... .. '? . ,",i . '.' :',~ , ',: ': ;':',.:t " , , .. ".. ': ~.. ~..... ,~ " , ' .. " , " .. '. ~ .: .. .. ..:. , .. .):-::<:,J 1 :. ' "" : :" ~"""~ t;;";1iJ : : 0:-:.' ':-: : :-- .:- ... ' ' . .. ~ ',:, ~ ,~~':,~~': ~:':"~'.i . .... ..' ,. ? . "<"::~": ;<l¡;~r:! :~"" "~~~:;;: 'i~:2i:d , ":,, ,",:, .. ,.,.. ,. I ."J L"I ARCO Alaska, Inc Wildcat Nanuk 2 551359 r.-',..? , ? . '1 . . 'J TOTAL WATER TOTAL FLUID ChlorldN H2O RATE CUNNI (9BLSI (ppml (bw'd) (bb"l '~I:I~ ':' l~(.':~. II tl"' ~ 3 ~J~r '4 ,'=' ,~, ~ l~,)h:, '~I,"II:' '~,. ,:'1Ç1 ~;. It;..:' (I ¿ ~I'.rll:1 ""II"I~ i.I'1 ':-J:'I I~ 1.,:," ~. ':;:~I~(,(I 11~I"':i: I.:"',:.! , ~ I"'~ ~ . ,fj.",,",,-::, I~''''~ ) I ":I),i 1;1~' , .~~ ~I ':E":":.:I Q.~,!, ~? 1('~1~. I~ I': (I .?~(II:'" ~~'4 ,7 ",ï'o.' ~." , r;1 ~ ~ ';' 2~~":1I) P',¿'4 I:.! 'I~~') ~. ,~~ . .", 2")1""11) .;.,.:' '1:1 I "I~' -:. , ;..n.'1 .:'(..:11:":1 '1"'1 .I ~ "~. (,:- ';' ~ '" ~I ':":'(11''') ';':IF IÇI "1~1 ~'" , ,:'f?4 5 '¿:¿(II:(I IJ';,~~'" II;S",: ¿"~('I 2 Z2('I,".) 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J I"IE' t' "'~~ ~I '~(1(""" ~J ~ :.. II; ~h,l ~'~ ~~ I:. ~ I~ '11"..:1 ~:.,: I ~ I'!'-~';" ~ ~ ..:~;'f.t I) '~"" :") II!' ~":. :' 1 , '" ~'.I If''; .2~~" ~, I~ 11'"11;\ £0..14 r.) I ':II J~ 1(1 ?;.DI) I ~II)(.) fo':") ".> , 1~ ~ II"' :!f:..18 .) 15')'.:' 12~ ~ I~I~ 1 '" ~J 2' :"JII. 14(.(.) ç.PJf'."'I 1(.. 11;"4 ¿ I J()H 4 14'",11".) er;4 ,~ IB)¿ ¿' :u:'~ø: !I '4('~'" , ))ÇI t 7 'e~~1 'Z ~,~~.. 'l 1.11:1(..1 '¡?JI3 if:- 'I.I~~ ',2 ~I51.! I:I(II:~' F¡7~ '4 I'~(I" ~ I .'. ~~ S '~I'I('" If..;...... 22 I~"¡'J. \;..r; ..'2'C:-" ~ '~I"II)(I ,~u)'3 2('1 I~".s~ f.., ,:t~.t'=' I '~"'II).) ~p.~ 1[1 '\>£2 )¡. ~2"'e I I ~'o:"-.) ';").;, IÇo "P' ~', 1,)11.1 '~(II'IIJ 1(IJ('l' .')':'" ~f :\HI~ I ,~,,,'..~ ':'1 J ~ ';0 ¿"~J' ,:'" 1,~'~ 4 1 ~.(Irl '" .~'I:,I '4 ~La..'8 ~~I ':I.3ç.,~ , '~I:":"'. )''1 .:O~ ':".t~ (1.1 ,:I'¡¿' :' '!- '~."I"II' .¿I) '1 .?""~1 I:IJ : : . ',: .",~ , ,:' '1 HALLIBURTON ENERGY SERVICES SURFACE TESTING REPORT DATE/TIME ~EMARKS t "'\ rrJdIy r 11r:mn 4121/00 12:00 FloWIng thru seperator 4121/00 12:30 4121/00 13:00 4121/00 13:30 4121/00 14:00 4121/00 14:30 4121/00 15:00 4121/00 15:30 4121/00 16:00 4121/00 16:30 4121/00 17:00 4121/00 17:30 4121/00 18:00 4121/00 18:30 4121/00 19:00 4121/00 19:30 4121/00 20:00 4121/00 20:30 4121/00 21:00 4121/0021:30 4121/00 22:00 4121/0022:30 4121/00 23:00 4121/00 23:30 4122/00 0:00 Stopped pumping N2 4122/00 0:30 4122/00 1 :00 4122/00 1 :30 4122/00 2:00 Heater choke ecreased from 128 to 64 4122/00 2:30 4122/00 3:00 4122/00 3:30 4122/00 4:00 4122/00 4:30 4122/00 5:00 4122/00 5:30 4122/00 6:00 4122/00 6:30 4122/00 7:00 4122/00 7:30 4122/00 8:00 4122/00 8:30 4122/00 9:00 4122/00 9:30 4122/00 10:00 4122100 10:30 4122/00 11:00 4122/00 11:30 4122/00 12:00 4122/00 12:30 4122/00 13:00 4122/00 13:30 4122/00 14:00 4122/00 14:30 4122/00 15:00 4122/00 15:30 ~ i OHAiIiBURTON WELLHEAD CONDmONS WHP WHT CSG' CHOKE (Pllg) (deg F) (pslg) (84th.) 271.59 85.43 655.27 48 183.31 82.82 654.06 48 250.58 83.6 654.43 48 289.13 84.76 654.8 48 286.43 84.95 656.67 48 255.59 85.63 655.27 48 258.1 85.96 655.46 48 256.75 86.17 655.75 48 249.04 86.28 656.12 48 236.12 85.7 656.23 48 244.6 85.32 656.01 48 249.04 85.09 656.19 48 238.63 85.04 656.12 48 241.71 85.06 655.97 48 234.97 84.9 656.08 48 241.13 84.82 656.01 48 237.09 84.84 656.16 48 228.03 84.79 656.3 48 236.89 84.98 656.27 48 225.33 84.85 656.27 48 246.34 85.29 656.63 48 240.36 85.35 656.3 48 234.77 85.02 657.04 48 242.1 85.43 656.78 48 202 84.97 656.45 48 161.53 82.22 654.61 48 182.54 73.08 653.03 48 201.43 81.2 653.62 48 191.21 75.54 651.93 48 305.13 81.73 653 48 297.61 81.86 653.44 48 298.96 82.68 653.51 48 302.62 82.82 653.77 48 306.48 83.21 654.17 48 305.51 83.04 653.99 48 304.93 83.09 652.37 48 302.81 83.35 654.06 48 305.9 84.03 654.28 48 300.31 84.08 654.69 48 308.21 84.28 654.94 48 307.83 84.38 654.83 48 307.83 84.21 655.13 48 309.75 84.55 655.05 48 313.61 85.35 654.98 48 325.17 86.38 655.09 48 328.26 86.47 655.16 48 332.31 86.54 655.27 48 332.11 86.39 655.53 48 333.65 86.45 655.57 48 332.69 86.32 655.53 48 335.58 86.68 655.64 48 334.62 86.33 655.57 48 333.46 86.54 653.88 48 334.81 86.58 665.64 48 335.39 86.76 655.24 48 335.77 86.8 655.75 48 . TqT AL GAS GAS RATE CiA'S CUMM. (mmsoffcl) (mmsct) 0.674892 0.0301989 0.3991368 0.0385142 0.5278763 0.0495116 0.5508957 0.0609886 0.5963856 0.0734133 0.573831 0.0853681 0.5937209 0.0977373 0.6052562 0.110347 0.5980534 0.122806 0.5757916 0.134802 0.5576943 0.146421 0.5599251 0.158086 0.5577234 0.169705 0.5678458 0.181535 0.5584394 0.193169 0.5764006 0.205178 0.5920297 0.217511 0.6217274 0.230464 0.6234897 0.243454 0.6379492 0.256744 0.665389 0.270606 0.6460553 0.284066 0.632078 0.297234 0.6731928 0.311259 0.4532855 0.320702 0.416771 0.329385 0.3538072 0.336756 0.5852046 0.348948 0.3588504 0.356424 0.4143826 0.365057 0.4063742 0.373523 0.3603421 0.38103 0.4163336 0.389704 0.4168252 0.398388 0.4165176 0.407065 0.4397187 0.416226 0.4390447 0.425373 0.4483264 0.404514 0.447917 0.413846 0.4845645 0.423941 0.4792321 0.433925 0.4809654 0.443945 0.4817139 0.454002 0.4873606 0.464155 0.487212 0.474305 0.4874507 0.484461 0.4892495 0.494653 0.4912422 0.504888 0.4909961 0.515117 0.4895306 0.525315 0.4900164 0.535524 0.4894003 0.54572 0.4905673 0.55594 0.4897297 0.566137 0.4922027 0.576392 0.4991893 0.586791 ~~ ~~. ARca Alaska, Inc. COR. VOL ~tb) Page 3 TOT AL OIL OILRATE OIL CUMM. (stbfcl) (bbls) 864.17 1383.41 320.06 1390.08 112.02 1392.42 475.30 1402.32 334.47 1409.29 480.10 1419.29 588.12 1431.54 456.09 1441.04 588.12 1453.30 408.08 1461.80 400.08 1470.13 486.50 1480.27 190.04 1488.19 408.08 1496.69 486.50 1506.82 456.09 1516.32 460.89 1525.93 504.10 1536.43 432.09 1545.43 528.11 1556.43 396.88 1564.70 504.10 1575.20 760.15 1591.04 288.06 1597.04 547.31 1608.44 395.28 1616.68 532.91 1627.78 456.09 1637.28 355.27 1644.68 760.15 1660.52 540.11 1671.77 444.09 1681.02 473.69 1690.89 547.31 1702.30 518.50 1713.10 516.90 1723.87 571.31 1735.77 576.12 1747.77 672.13 1761.77 364.87 1769.38 562.51 1781.09 544.11 1792.43 604.92 1805.03 504.10 1815.53 512.10 1826.20 528.11 1837.21 518.10 1848.00 560.11 1859.67 516.90 1870.44 547.31 1881.84 547.31 1893.24 532.1064 1904.327165 462.0924 1913.95409 504.1008 1924.45619 486.49728 1934.59155 621.72432 1947.54414 COMPANY: FIELD: LEASE: WELL#: Sales Order: API (0 60 °) 38.3 38.3 a.O.R. {nmsoUetb} 34720.1 858.095 2122.38 4411.81 4732.9 2166.58 1241.85 1258.98 1237.43 1039.13 2266.8 1454.18 1548.82 1582.26 1524.62 1559.1 1513.71 1401.33 12~3 1558.61 1900.76 2155.97 2256.5 1814.31 1510.82 2535.78 1334.17 1390.64 857.496 837.361 589.2 576.248 807.982 804.409 790.728 833.047 832.52 750.211 741.73 807.014 885.793 889.352 891.428 905.26 902.82 863.962 864.594 747.202 869.199 870.676 868.178 910.712 915.109 989.448 996.025 1009.13 36 40.2 39.8 43.4 39.7 TOTAL FLlRD (BBLS) 3466.6 3483.1 3494.8 3539.8 3571.5 3604.8 3639.8 3671.5 3706.5 3734.8 3768.2 3799.9 3831.5 3859.9 3891.5 3923.2 3953.2 3988.2 4018.2 4054.9 4081.6 4111.6 4163.3 4169.9 4201.6 4223.3 4253.3 4278.3 4298.3 4330.0 4355.0 4380.0 4406.6 4436.7 4466.7 4495.0 4523.3 4553.3 4588.4 4608.4 4640.0 4668.4 4698.4 4728.4 4755.1 4782.6 4813.4 4842.6 4870.9 4900.9 4930.9 4960.1 4987.6 5017.6 5044.3 5075.1 ARCO Alaska, Inc Wildcat Nanuk 2 551359 ~. . ChlorldM (ppm) 15000 15000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 14000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 11000 T~T AI.., ~ATER H2O RA TE (bwfd) 1066.21 480.10 448.09 1685.14 1186.84 1120.22 1092.22 1064.21 1092.22 952.19 1200.24 1033.81 670.11 952.19 1033.81 1064.21 979.40 1178.24 1008.20 1232.25 883.38 936.19 1240.26 612.10 972.99 644.93 907.38 744.16 604.92 760.16 880.13 756.16 806.56 892.98 921.78 843.37 788.96 864.17 1008.20 596.32 957.79 816.16 835.37 936.19 768.15 792.16 962.19 840.17 843.37 892.98 892.98 868.17 858.17 936.19 793.76 868.57 CUMM. (~Is) 2083.06 2093.05 2102.38 2137.49 2162.20 2185.53 2208.29 2230.46 2253.21 2273.05 2298.06 2319.59 2343.35 2363.19 2384.72 2406.89 2427.30 2451.80 2472.81 2498.48 2516.88 2536.39 2562.23 2572.89 2593.16 2606.60 2625.50 2641.01 2653.61 2669.45 2683.20 2696.95 2716.76 2734.36 2753.56 2771. 13 2787.57 2805.67 2826.58 2838.98 2858.93 2875.94 2893.34 2912.85 2928.85 2945.35 2965.40 2982.90 3000.47 3019.07 3037.68 3055.77 3073.64 309a, 15 3109.68 3127.57 0 HALLIBURTON ...,~ COMP ANY: ARCO Alaska, Inc HALLIBURTON ENERGY SERVICES FIELD: Wildcat SURFACE TESTING REPORT ~.~ LEASE: Nanuk WELL': 2 ARca Alaska, Inc. Sales Order: 551359 DATE/TIME REMARKS WELLHEAD CO.NDmONS TOT AL GAS TOTAL OIL TOT AL WATER WHP .WHT CSG CHOKE GAS RATE GAS CUMM. COR. VOL OIL RATE OIL CUMM. API .. G.O.R. TOTAL FLUID Chlorides H2O RATE: ' .. CUMM. mIdlyr hr:mn (pllg) (deg F) (pslg) (84ths) (mmsc1fcl) (mmscf) (stb) (stbfcl) (bbls) (@ 60 ') (lm18CJt'etb) (BBLS) (ppm (bw/d) (bb18J 4122100 16:00 333.27 86.84 655.97 48 0.5049212 0.597311 528.1056 1958.54634 1025.88 5102.6 11000 792.18 3144.07 4/22/00 16:30 337.12 86.92 655.94 48 0.506943 0.607872 592.1184 1970.88214 1017.17 5133.5 11000 888.18 3162.58 4/22/00 17:00 337.32 86.94 655.97 48 0.5042437 0.618377 496.0992 1981.21754 38.3 1014.84 5159.3 11000 744.15 3178.08 4/22/00 17:30 337.51 86.89 656.01 48 0.5056344 0.628911 532.1064 1992.30309 1017.39 5188.5 11000 888.17 3196.17 4/22/00 18:00 338.67 86.81 655.71 48 0.4993043 0.638043 571.31424 2004.20547 927.422 5216.8 11000 788.96 3212.81 4/22/00 18:30 338.47 86.86 655.97 48 0.4973849 0.648448 420.084 2012.95722 913.604 5241.8 11000 780.16 3228.86 4/22/00 19:00 339.44 86.88 656.01 48 0.5017067 0.658892 532.1064 2024.04277 837.317 5273.5 11000 988.20 3249.45 ~~ 4/22/00 19:30 340.02 86.91 656.12 48 0.5028375 0.669349 473.69472 2033.91141 995.211 5300.2 11000 806.56 3266.25 4/22/00 20:00 338.47 86.94 656.27 48 0.5067911 0.679853 540.108 2045.16366 945.877 5330.2 11000 900.18 3285.00 4/22/00 20:30 339.63 86.94 656.12 48 0.5088201 0.690427 518.90336 2055.93248 950.644 5358.5 11000 843.37 3302.57 4/22/00 21:00 339.63 86.94 658.16 48 0.5134259 0.701038 547.30944 2067.33476 39.5 980.57 5388.5 10000 892.98 3321.18 4/22/00 21:30 338.47 87.19 658.12 48 0.5102997 0.71164 518.50368 2078.13692 958.663 5418.5 10000 921.78 3340.38 4/22/00 22:00 340.79 87.41 656.71 48 0.5082621 0.722247 532.90656 2089.23914 1003.71 5448.5 10000 907.38 3359.28 4/22/00 22:30 339.82 87.1 656.16 48 0.5095412 0.732852 503.30054 2099.72457 976.204 5476.9 10000 856.97 3377.14 4/22/00 23:00 341.75 87.13 656.08 48 0.5027407 0.743482 473.69472 2109.59321 1011.9 5503.5 10000 806.68 3393.94 4/22/00 23:30 342.14 86.76 656.08 48 0.4997521 0.753839 518.50368 2120.39537 982.314 5533.5 10000 921.78 3413.15 4/23100 0:00 341.56 86.69 655.83 48 0.5050109 0.764261 460.89216 2129.99729 1020.36 5560.2 10000 819.36 3430.22 4/23100 0:30 344.06 86.68 655.83 48 0.5047474 0.77477 489.69792 2140.19933 1005.57 5588.6 11000 870.57 3448.35 4/23100 1:00 341.56 86.88 655.68 48 0.5040937 0.785302 503.30064 2150.68476 39.4 1014.19 5616.9 11000 856.97 3466.21 4/23100 1:30 342.14 86.28 655.57 48 0.5034548 0.795833 432.0864 2159.68656 982.46 5641.9 11000 768.15 3482.21 4/23100 2:00 341.75 86.52 655.79 48 0.5032449 0.806366 530.50608 2170.73877 1009.04 5670.2 11000 829.77 3499.50 4/23100 2:30 341.36 86.57 655.64 48 0.5027424 0.816884 547.30944 2182.14105 928.621 5700.2 11000 892.98 3518.10 4/23100 3:00 344.06 86.88 656.8 48 0.5074481 0.827428 473.69472 2192.00969 953.486 5726.9 11000 806.56 3534.90 4/23/00 3:30 348.38 86.63 655.49 48 0.5086507 0.838007 444.0888 2201.28154 981.868 5761.9 11000 756.15 3550.66 4/23/00 4:00 348.3 86.53 655.46 48 0.5143479 0.848655 503.30064 2211.74697 1001.43 5780.3 11000 856.97 3568.51 4/23100 4:30 347.34 86.36 655.71 48 0.5149166 0.85936 403.28064 2220.14865 1018.26 5803.6 12000 716.94 3583.45 4/23fOO 5:00 345.03 86.3 655.57 48 0.514864 0.870054 489.69792 2230.35069 39.8 1042.77 5831.9 12000 870.57 3601.58 4/23100 5:30 347.15 86.38 656.08 48 0.5161216 0.880769 460.89216 2239.95261 1026.2 5858.6 12000 819.36 3616.65 4/23100 8:00 344.06 88.44 655.83 48 0.5172904 0.891505 503.30064 2250.43804 1048.96 5886.9 12000 856.97 3836.51 4/23100 8:30 341.94 86.52 655.75 48 0.5167237 0.903666 606.92136 2263.082235 1009.6 5917.8 12000 873.37 3654.70 4/23100 7:00 341.94 86.65 655.94 48 0.5173122 0.914444 560.112 2274.751235 1008.95 5947.0 12000 840.17 3672.21 4/23100 7:30 342.14 86.73 655.94 48 0.518188 0.925239 594.1188 2287.12871 1014.21 5974.5 12000 728.15 3687.33 4/23100 8:00 342.14 86.92 656.01 48 0.5191857 0.936056 588.1176 2299.38116 1015.79 6003.6 12000 812.16 3704.25 4/23100 8:30 345.03 86.96 655.75 48 0.5215611 0.946922 544.1088 2310.71676 1018.94 8032.0 12000 818.18 3721.26 7 4/23100 9:00 343.68 87.21 655.75 48 0.5225027 0.957807 496.0992 2321.05216 39.8 1022.6 6057.8 12000 744.15 3736.76 1 4/23100 9:30 345.99 86.94 655.68 48 0.5234599 0.968712 636.52728 2334.313145 39.1 1022.98 6088.7 11000 843.77 3754.34 4/23100 10:00 348.11 86.81 655.86 48 0.5240089 0.979643 520.90416 2345.165315 1021.68 6114.5 11000 719.34 3769.32 4/23100 10:30 347.15 86.85 655.79 48 0.5242496 0.990565 530.50608 2356.217525 1023.95 6142.8 11000 829.77 3786.61 4/23fOO 11:00 346.18 86.99 657.77 48 0.5250921 1.0015 576.1152 2368.219925 972.759 6172.8 11000 884.17 3804.62 4/23100 11:30 345.8 87.2 655.97 48 0.5267377 1.01248 524.90496 2379.155445 929.961 6199.5 11000 756.35 3820.35 4/23100 12:00 345.8 87.02 655.86 48 0.5255603 1.02343 476.0952 2389.074095 928.454 6227.8 11000 884.18 3838.77 4/23100 12:30 342.71 87.4 655.97 48 0.5265318 1.0344 541.30824 2400.35135 39.1 1090.75 6255.4 11000 778.96 3855.00 4/23100 13:00 349.65 87.56 655.75 48 0.5290524 1.04542 50 1.70032 2410.80344 36.4 1095.8 6282.9 11000 818.56 3872.05 4/23100 13:30 349.85 87.59 655.71 48 0.5288409 1.05642 488.49768 2420.980475 1099.52 6310.4 11000 831.77 3889.38 4/23100 14:00 351.39 87.48 655.71 48 0.5200952 1.06726 592.91856 2433.332945 1080.23 6342.0 11000 927.39 3908.70 4/23100 14:30 351.58 87.44 655.42 48 0.5175848 1.07804 496.0992 2443.668345 1086.78 6367.9 11000 744.15 3924.21 4/23100 15:00 356.21 87.39 656.19 48 0.5479429 1.08946 602.1204 2456.21252 1157.59 6397.0 11000 798.16 394D.83 4/23100 15:30 348.88 87.58 656.49 48 0.5617773 1.10095 544.1088 2467.54812 935.621 6425.4 11000 818.16 3957.84 4/23100 16:00 351.39 88.01 656.3 48 0.5925048 1.1133 512.1024 2478.21692 1051.88 6452.1 11000 768.15 3973.84 4/23100 16:30 348.69 88.04 656.45 48 0.5629209 1.12503 608.1216 2490.88612 36.4 998.898 6483.7 11000 912.18 3992.84 4/23/00 17:00 352.74 88.01 655.6 48 0.5689269 1.13647 560.112 2502.55512 35.7 1003.89 6512.9 11000 840.17 4010.35 4/23100 17:30 352.74 88.11 657 48 0.5645896 1.14823 501.70032 2513.00721 997.098 6540.4 11000 818.56 4027.40 4/23100 18:00 352.18 88.23 657.04 48 0.55707 1.1566 524.90496 2523.94273 1043.15 6567.1 11000 755.35 4043.14 4/23100 18:30 350.81 88.38 657.96 48 0.584229 1.16864 868.93376 2537.87885 f066.3 8603.8 11000 1091.42 4Dß5,I)ð 4/23100 19:00 349.07 88.48 658.03 48 0.6000964 1.18093 355.27104 2545.28033 1104.87 8623.8 11000 604.92 4078.48 4/23100 19:30 348.11 88.72 657.48 48 0.5926358 1.19335 489.69792 2555.48237 1122.89 6652.1 11000 870.57 4096.62 Page 4 ~lLlBUìUON ~~ COMPANY: ARCO Alaska, Inc HALLIBURTON ENERGY SERVICES FIELD: Wildcat SURFACE TESTING REPORT ~",. LEASE: Nanuk WELL#: 2 ARCO Alaska, Inc. Sales Order: 551359 OATEITlME REMARKS WELLHEAD CONDmONS TOT AL GAS TOT AL OIL . .' T9TAl, WATE!A WHp. WHT CSG CHOKE GAS RATE GAS CUMM. COR. VOL OI~RATE OIL CUMM. API G.O.R. TOTAL FLUID Chlorides H2O RATE CUMM. mJdlyr ht:mn (pslg) (deg F (pslg) (84ths) (mmsoflcl) (mlMcl) (stb) ($IbId) (bbllSt (@ 60 o (nmsCJf/~) (eBLS) (ppm) (bWld) (bbls) 4/23/00 20:00 352.54 88.81 657.26 48 0.6069904 1.20588 489.69792 2565.68441 1185.89 6682.1 11000 950.59 4116.42 4/23/00 20:30 350.23 88.75 656.96 48 0.6171159 1.21858 554.51088 2577.23672 1250.08 6717.1 11000 1125.83 4139.87 4/23/00 21:00 350.81 88.72 657.11 48 0.6043226 1.23127 420.084 2585.98847 39 1283.24 6742.1 9000 780.16 4156.13 4/23/00 21:30 350.42 88.71 656.49 48 0.6149406 1.24404 562.51248 2597.70748 1204.63 6773.8 9000 957.79 4176.08 4/23/00 22:00 349.07 88.65 657.26 48 0.6132244 1.2567 448.0896 2607.04268 1171.27 6800.5 9000 832.17 4193.42 4/23/00 22:30 342.71 88.57 656.74 48 0.6145255 1.26925 504.1008 2617.54478 1257.02 6830.5 9000 936.19 4212.92 4/23/00 23:00 350.81 88.56 656.6 48 0.6161462 1.28184 486.49728 2627.68014 1245.6 6857.1 9000 793.76 4229.46 4/23/00 23:30 354.86 88.42 656.56 48 0.6091722 1.29447 560.112 2639.34914 39 1131.54 6890.5 9000 1040.21 4251.13 4/24/00 0:00 350.23 88.33 656.41 48 0.6102214 1.30703 460.89216 2648.95106 1146.62 6917.2 9000 819.36 4268.20 4/24/00 0:30 349.65 88.29 656.27 48 0.6099828 1.31961 547.30944 2660.35334 39 1204.54 6948.8 9000 972.99 4288.47 4/24/00 1:00 349.46 88.25 656.41 48 0.595447 1.3322 473.69472 2670.22198 37.7 1165.24 6975.5 10500 806.56 4305.27 4/24/00 1:30 346.38 88.13 656.27 48 0.6023865 1.34481 489.69792 2680.42402 1156.39 7003.8 10500 870.57 4323.41 4/24/00 2:00 350.81 88.26 656.16 48 0.585005 1.35743 503.30064 2690.90945 1142.78 7032.2 10500 856.97 4341.26 4/24/00 2:30 353.32 88.04 657.37 48 0.6077433 1.37007 499.29984 2701.31153 1166.81 7058.8' 10500 760.96 4357.53 4/24/00 3:00 352.35 88.35 655.83 48 0.6042503 1.38272 489.69792 2711.51357 1098.66 7087.2 10500 870.57 4375.67 4/24/00 3:30 351.97 88.26 655.75 48 0.6138723 1.39544 476.0952 2721.43222 1105.96 7115.5 10500 884.16 4394.09 4/24/00 4:00 352.35 88.19 655.6 48 0.6095794 1.40619 547.30944 2732.6345 1264.88 7147.2 10500 972.99 4414.36 4/24/00 4:30 351.2 88.03 655.64 48 0.6101226 1.42095 547.30944 2744.23678 1219.85 7178.9 10500 972.99 4434.63 4/24/00 5:00 353.12 88.13 655.42 48 0.6132171 1.43371 420.084 2752.98853 38.3 1209.56 7203.9 10000 780.16 4450.89 4/24/00 5:30 351.2 88.01 655.38 48 0.5863527 1.44655 547.30944 2764.39081 1163 7235.5 10000 972.99 4471.16 4/24/00 6:00 351.77 87.99 655.49 48 0.621072 1.45941 448.0896 2773.72601 1198.83 7262.2 10000 832.17 4488.49 4/24/00 6:30 351.2 88.12 654.69 48 0.6208935 1.47699 562.51248 2785.44502 1266.56 7293.9 10000 957.79 4508.45 4/24/00 7:00 352.16 88.09 655.64 48 0.6203537 1.48992 512.1024 2796.11382 1161.65 7320.6 10000 768.15 4524.45 4/24/00 7:30 350.81 88.03 655.79 48 0.6199671 1.50283 462.0924 2805.740745 1103.91 7348.1 10000 858.17 4542.33 4/24/00 8:00 349.46 88.14 655.9 48 0.6210087 1.51577 462.49248 2815.376005 1267.52 7376.4 10000 897.78 4561.03 4/24/00 8:30 350.62 88.06 656.63 48 0.6226359 1.52874 532.1064 2826.461555 1306.27 7408.1 10000 988.20 4581.62 4/24/00 9:00 353.12 88.13 654.61 48 0.622843 1.54172 473.69472 2836.330195 36.8 1268.46 7434.8 10000 806.56 4598.42 4/24/00 9:30 351.2 88.14 655.71 48 0.6236784 1.55471 532.90656 2847.432415 1267.84 7465.6 10000 947.39 4618.16 4/24/00 10:00 352.35 88.33 655.97 48 0.626158 1.56776 476.0952 2857.351065 1240.8 7493.9 10000 884.18 4636.58 4/24/00 10:30 349.27 88.36 655.71 48 0.6286607 1.58085 490.098 2867.56144 1251.56 7523.1 10000 910.18 4655.54 4/24/00 11:00 350.42 88.32 655.97 48 0.6299871 1.59398 409.68192 2676.09648 1246.99 7549.8 10000 670.57 4673.68 4/24/00 11:30 350.23 88.23 656.05 48 0.6209631 1.60691 514.90296 2886.823625 1380.64 7582.3 10000 1045.41 4695.46 4/24/00 12:00 352.35 88.05 656.23 48 0.6281828 1.62011 434.0868 2895.8671 1403.81 7608.1 10000 806.16 4712.26 4/24/00 12:30 351.77 88.53 656.45 48 0.6274928 1.63318 547.30944 2907.26938 36.8 1401.08 7638.1 10000 892.98 4730.86 ~ 4/24/00 13;00 353.89 88.35 656.67 48 0.6295838 1.64629 504.1008 2917.77148 33.8 1183.41 7668.1 10000 936.19 4750.36 4/24/00 13:30 351.2 88.29 656.93 48 0.6268509 1.65935 503.30064 2928.25691 1181.91 7696.5 10000 856.97 4768.22 4/24/00 14:00 352.74 88.27 657.07 48 0.699109 1.67392 503.30064 2938.74234 1322.01 7724.8 10000 856.97 4786.07 4/24/00 14:30 367.58 86.23 582.32 48 0.8127809 1.69085 473.69472 2948.61098 1628.52 7751.5 10000 806.56 4802.87 4/24/00 15:00 Shut in well for 5 days 404.39 85.83 453.84 48 0.2663115 1.6964 355.27104 2956.01246 33.8 683.437 7771.5 10000 604.92 4815.48 Page 5 SURFACE TESTING REPORT Oil FLOW RATE CALCULATIONS DA TElTIME m/d/yr hr:rnm 4/19,100 2:00 4/19/00 2:30 4/19/00 3:00 4/1 9/00 3:30 4/19/004:00 4/1 9100 4:30 4/19,'00 5:00 4/19/00 5:30 4/1 9/00 6:00 4/19/00 6:30 4/19/00 7:00 4/19l00 7:30 4/19/00 8:00 4/19/00 8:30 4/19/00 9:00 4/19/009:30 4/1 9/00 10:00 4/19,'00 10:30 4/19/00 11:00 4/19l00 11 :30 4/1 9100 12:00 4/19100 12:30 4/1 9100 13:00 4/19/00 14:30 4/1 9/00 16:00 4/1 9/00 16:30 4/1 9100 17:00 4/1 9100 17:30 4/19/00 18:00 4/1 9/00 18 :30 4/1 9/00 19:00 4/1 9/00 19:30 '/19:0020:00 . 9/00 20:30 100 21 :00 0 21 :30 FLOW INT. min 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 HYDROMETER GRAVITY TEMP ;::,'./ri',~ >..~~.! . . : .""" i: . , "'.:: .: ~ . ... '. . . .. " . :", ~ .' ~ . . . '. . . . , , , . . '... . ." . .' .' . .. . ~ : '.. . : . .. , . .I' .' :"'0 .." . :. . . . . . ~ .. ."'.. ... '" . . . " . . ",/" "':1 . . . : . ... . ;. > .; > ;<"~,: ':. . COR. GRA VlTY @6(r . :. ~ ~ . . '. " . ..", :".'" . . . . . . . . . . , , . . .. ~. . . ,.! ''''''''''~~'101 ~~ ~~ COMPANY: FIELD: lease: Well#: ARca Alaska,lnc Wildcat Nanuk 2 ............... HALLIBURTON ARca Alaska, Inc. . . VOLUME INC. bbls 0.167 15.837 28.056 1 9.954 1 5.003 7.335 13.003 1 7.3368 0.6668 0 0 0 0 0 0 0 0 0 0 0 0 0 0 19.1705 21.23758 11 .43562 0.76682 4.001 6.168 0.000 6.96806 6.801 7.335 4.001 4.40088 9.0018 "., . . ...> .' . . r '. . .r '. '? : , :'" ." . . OIL BS&W (~, 0.25°~ 10.00° Ó 45.00° ° 2.50"~ 35.00°0 98.00o~ 100.00°0 100.00°0 100.00°0 100.00°0 .. 100.00°0 100.00°0 1 00 .00°'0 100.00°0 100.00°0 100.00°0 1 00.000~ 100.000ó 1 OO.OO~ó 100.00°0 0.00°0 2.00°0 2.00° 0 96.00°0 60.00~0 80.00~0 100.00°0 78.00°0 88.00°0 80.00~o 80.00°'0 76.00°0 70.00°0 : 75.00~0 80.00° 0 73.00% . .'''' Kf TANK COR. TEMP COR. VOL OIL RATE factor" ~tq.., stb/d .. . .:.' . . .-<~ 7.50 . .. 760.15 . . . ''''', 1346.67 :' ...., ". . ." . '~:..:::~~¡..i..:".~ 957.79 . . , ,"'. ",. .... . '. ". .'. 720.14 '. : . '.' '. . ., . ',".," ,,'. . ' 352.07 . . ~ , . -:" ~:;. r 624.12 : .,'. ;~::. 1188.81 : ; ':" .~5.:., ~ ~~o~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 920.18 1019.40 548.91 36.81 192.04 296.06 0.00 334.47 326.47 352.07 192.04 211.24 :.,....m......m... ... :.m.....--..-- -- :--:..:~.. . .'...... ...m . .. . .......... --- --....~.:. "''':''--....:.......:.:............... ...:.....:..,~ ........:...............,...............: 432.09 OIL Kf Cf Mf TEMP TEMP Mf . Wf METER degf foetor t<Jctor foctor ,. '. .. ., .. .. Wf METER TANK SHRKG COR. VOL INC. foetor stb bbls TANK TEMP ~.~F ,.. . . . . .. . ..' .... . . ." . . . . . , . . . . .: . ... . . .. . .. '. . ", . . . . '. ." ".: :".". ..." . . . . . . . " . . . . . . . . '. . . . . , . .' .j. .' :" ~ ":. ~ . .". ':".:. :'''" '.'.:'..:::;r..~~ , . . . .. . . . ,..... . . :..' :~;:~ . ; . . , . . .. . , . ..., ... . 1'. ., . . . . .";';'.:.:'; :.:.(.( f , . . . ., . "'. . .~. .;;":. ~ . . . .. . . "^..' ." '. ;"~~h ~ ~. .. . . '.. '. .' . ". ~ ~ < : .. . . . .. '. ..... .' .,¡ .. . .' ."..':' ,,./ ,::': :~.(~ ¿~ ~ '( ~,..,:~~~.>,'~. ~ :. ":. ~,...:... .~.~. ',~: :":. ,'. ... '. > .' ,. . . . . :. .,: . ~!;':..:: '=: ....,.~~.:~:.< . . . ..~ . . ... . " .' .. '". '. ~ : .' '. .. "I . ~.' . '. . .. . . "I'" . . .. . . . . I' .. ..: '., . . ., . . .. ., ~ ~':'" ..., . ...' . "". . .' ..'" . . .... . ", . ".. .'. ". ... . .. . Page1 OIL CU MM. stb 35.00 50.84 78.89 98.85 113.85 121 .18 134.19 151.52 152.19 152.19 152.19 1 52.1 9 152.19 152.19 1 52.19 1 52.19 152.19 152.19 1 52.1 9 152.19 1 52.1 9 152.19 152.19 171.36 192.60 204.03 204.80 208.80 214.97 214.97 221 .94 228.74 236 .07 240.07 244.48 253.48 ) ) SURFACE TESTING REPORT OIL FLOW RATE CALCULATIONS DA TEfTIME rn/d/yr hr:mrn 4/19/0022:00 4/19/0022:30 4/1 9/00 23 :00 4/1 9/00 23 :30 4/20l00 0:00 4/20/00 0:30 4/20/00 1:00 4/20/00 1 :30 4l20/00 2:00 4/20.'00 2:30 4/20100 3:00 4l20/00 3:30 4/20.'00 4:00 4/20/00 4:30 4/20.'00 5:00 4l20.'00 5:30 4l20/00 6:00 4/20/00 6:30 4/20/00 7:00 4/20/00 ì:30 4/20/00 8:00 4/20/008:30 4/20l00 9:00 4/20l00 9:30 4/20/00 10:00 4/20/00 10:30 4/20/00 11 :00 4/20/00 11 :30 4/20/00 12:00 4/20/00 12:30 4/20/00 13:00 4/20/00 13:30 4/20/ÛO 14:00 4/20/00 14:30 4/20/00 15:00 4/20/00 15:30 FLOW INT. rnin 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 HALLIBURTON .~...""""""""'''''''''''''''...",,..'''''''''~'''''~ HYDROMETER COR. GRAVITY TEMP GRAVITY a~. '. ...' ~~ f .. .. @ roo :. :. ... .~. . .., .. . I' i : ~... .~ : :"..: '. . .".:.".. :".. . :. . ~ ':: .- : . ..... . . . :....:h.:.:>;~:::.:~.'~:.;.'~>;<:::.~\:: VOLUME INC. bbls 9.1685 7.001 9.90198 10.002 9.5019 . . . :' : ,~ '.. ...' ''''''':' ~ 10.002 l' ""'.'. . 9.5019 . .. :.. 10.002 . .' 11 .0022 . . 10.002 9.5019 11.09 11.09 . 11.09 : 11.10222 7.401 1 2.950 19.740 12.950 7.500 , 7.900 10.420 . ~ ;, . .....".'" .. . .. : .: . :. ..". 9.000 1 0.000 14.000 1 0.490 12.000 8.670 14.340 15.600 10.500 8.800 11. 7 40 1 0.670 1 0.450 12.330 . . . .". :.. . .. .... . . . . .' .' : . .. . . . .. . . . .. . . .' . 1. . . . . . ..1' \". ...... .. ".." \.'.". . . .' . . : . . . " . .' 1'.. .' . . '. .. ".. ... . .. . . .. . ".", . .. ," ." . . ~... ~ . . .': : ... ~::'::;/ <:~..:';.< :':~,: ;,: :y~;~:; : OIL TEMP ~~rT' ~ . .. . .. .. .. "," ... . .. . . . . .. ... ...: . .. . . . . .. . . . . ," ... .. . ~ . . . , .j...:. ... , ... '.." ,/ :. . . :". :~.~\. ;::...:.:~.~;,~.. 1'...."..: ",'. ...." ~~ ~" ARca Alaska, Inc. COMPANY: FI ELD: Lease: Well#: Kf TEMP tactor Cf Mf Wf METER TANK Mf. Wf METER SHRKG COR.VOL INC. fc1ctor foetor factor stb bb\s ., . TANK TEMP .~egF .. . . ".." ':, ".:' .: . .. .. . . . . . . .. ,/'..' . . '. . ": ...: .":" ." . . .. '.'. . '; .. ,',:::~:';:'~ : '. . . . , . . . .... .. . . . . .' . . , . . . . . .. . . . . . . ...... ... . OIL BS&W % 70.000~ ìO.oo° ~ 70.000~ .... 70.00° ° 70.00% .:..' "::. 70.00° ~ 70.00°.~ 70.00°0 . 65.00°0 65.00~0 65.000~ 63.00°0 . 63.00,:)~ '. 63°0 63~~ 63% 63~~ 63°~ 63~0 73°~ 75°~ 75°0 75°0 65°~ 700,~ 63°'0 60°0 60°0 57°,~ 61% 65°~ 68% 68°~ 68~0 67% 60~0 .. . . . . . . . . . ."'., .. . . . , ,. ", :. ,I' .. .. ".. ".I" .. ..1" Page2 . .I' . , . " . '" . . '. ..... p . . '. , ' ;.:.' ", '. . . .' . .. .. ."..:" '" . .. . ., . . . ~~: ;..: ~> ".,: '. . . . . . ., , . , OJ . "'. .. ....,. . . . ..., . '.. . ",' d .: ....... '.": . :.: .," .." -":..~ ~.:::- .Y : ). . ~ .: .,.." :.'.' '" ': "'~' .'~: :'::j':.{~:.'~~ . . ",". . . ., , , . . ' . , , . , , . . .. . ., ARCO Alaska,lnc Wildcat Nanuk 2 . .. Kf TANK COR. TEMP COR.VOL OIL RATE factor stb stb/d .: . . .""'. . :~,:'~:'~~'.:::': 440.09 . ". .... ~. ':.,: ~~ ::.. :"::/~.G ;.~ 336.07 .. "','J:~) 475.30 . :.--~. ,':-:,,,:,"<'i~'~':.~ 480.10 . .... '.:; ..!.~t\~ :::~~ . ...'. ". "..' 456.09 "'> .:'.' ( 480.10 . "'.. ., . ~ 528.11 480.1 0 456.09 532.11 . .::.. ,, . . .: '. '. 532.11 532.11 532.91 355.27 621.72 947.39 621.72 360.07 y : ~. ."::::: .~ . 380.08 500.1 0 " ~. ~~::~. ~~ 432.09 480.10 672.13 503.30 576.12 416.08 688.14 748.95 504.10 422.48 563 .31 512.00 501.70 592.12 . . ;. . ;", . :.::~ .": ~ .. "....." '.:-:.:~f~:"", . . J.~: .."" : , , "'.. .. . : :',: <:; ~.::~I~\~: ... '. . . . .'. .: --: ':";. ..: .... ' . .': ./:'. '. : . '..:.. ,¡ .' : .x,~;.r,"~ . . ..' .. , ...':. ' . .. OIL CUMM. stb 262.65 269.65 279.55 289.55 299.05 309.05 318.56 328.56 339.56 349.56 359.06 370.15 381.24 392.33 403.44 410.84 624.39 637.34 657.08 670.03 677 .53 685.43 695.85 704.85 718.85 729.34 741.34 750.01 764.35 779.95 790.45 799.25 810.99 821 .66 832.11 844.44 ) ) SURFACE TESTING REPORT OIL FLOW RATE CALCULATIONS DA TEffIME rn/d/yr hr:mm 4/20/00 16:00 4/20100 16:30 4/20/00 17:00 4/20./00 17:30 4/20/00 18 :00 4/20/00 18:30 4/20/00 19:00 4/20/00 19:30 4120/0020:00 4.'20/00 20:30 4/20/00 21 :00 4/20/00 21 :30 4/20/0022:00 4/20/00 22:30 4/20/0023:00 4/20/0023:30 4/21/000:00 4/21/00 0: 30 4/21/001:00 4/21/001:30 4/21/002:00 4/21/002:30 4/21/00 3:00 4/21/003.30 4/21/004:00 4/21/004:30 4/21/00 5:00 4/21/005:30 4/21/00 6:00 4/21/006:30 4/21/00 7:00 4/21/007:30 4/21/008:00 4/21/008:30 4/21/009:00 4/21/009:30 FLOW INT. min 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 HYDROMETER COR. GRAVITY TEMP GRAVITY .. ~F~. .deg!: ..~ éJJ' . ." .. .' "...". . . . '. . . . '. . . '. :.. ," : ,: ..:' : ..;. "," .>~ :-. : . .."... ..". . .. '. .". .. . : ".'" .. . . ., .' . . , '. , . .. . . . . '. . I : ," ... . ~ : . , . . ., . . " ,. . . .. "'." .:: ..".. . . . . . . . . . .., .. ., '"-..:' .~., .~. ': "..; :~/\\ ::::~ <::~': ~::,~~>~ ." . " :"'."/ :..:.~~:., .:.: :: :~ ~ : '. >.: ~ ::'.. ~..'.. '. ~ > . .: ..;... .. ~ HALLIBURTON . ~ VOLUME INC. bbls 11.080 9.250 15.300 9.900 10.002 20.800 6.335 6.000 9.870 16.003 18.670 9.602 1 4.003 11.102 12.002 12.002 23.338 9.602 12.603 1 4.670 10.769 12.669 23.338 8.235 13.336 18.904 13.336 12.002 17 .103 17.337 7.585 12.252 1 2.336 9.919 10.502 11.669 . . ..' ~ . ' .. , OIL BS&W % 65°0 65°0 65°0 70°;;' 63°0 61 °0 62°0 64"0 63°~ 60°0 60°0 64"0 65°0 63°0 600~ 60°0 600~ 52°0 58°0 60"0 62°0 60°0 60°0 62°" 60°0 58°Co 60°0 60° co 62°~ 60°'0 65°0 65~0 63°0 63°0 63°0 65°0 OIL TEMP deÇJ ! . ~'. .. . .. . Kf TEMP factor . .. .. : : ." ... '' . . .: .. . . .' . . ". . ", .'". . ..." ." .... . . .. . . . . .. ~~ ~~ ARCa Alaska, Inc. Cf Mf Wf METER Mf * Wf METER SHRKG COR. VOL factor factor factor sib . , , ,. . . . . . . , . . . : ; ~-J >:.,.' "<'~:j:';~':;';: ;Y-':.:>.'. . '.. ':.:" .. .. .. . .. '. . .. .' . " - ,., .. . Page3 . . ., . . . , . . . . . . . . . ': I' ':0 .. . . . . ,"'., .. .: . . . .. '.' ..' '. .'" ., . . . . . . , . , . , . ,'..1 '. . .' , ,. . . . . . . .I.' . ..." , . . ''':. ,': :, " , ',: ,: ~ ' .. , .. . , . . . . .. , .. " '. '. . . COMPANY: FI ELD: Lease: Well#: TANK TEMP . . :~~:'~..: TANK INC. bbls . ... .':' . . . . . . . . ','. '.' , '. . . ".'" . . ,. .: I' . . . '. , .. ".. . . '. . . . . . . "', .. . , .. '''.' , . ...~ ".: : ' ARCO Alaska,lnc Wildcat Nanuk 2 .' TANK COR. COR. VOL OIL RATE stb stb/d . ", . :', .- . '.:- 532.11 . . .:.: ';. :<:Ir'l ~:~~ ." '.":.~' . :::>./::-/ 473.70 ., .. :" ~?~~:D ~~.~ ::~~~~ . . . . : , -= 304.06 .' '.":. ,,:' J 288.06 <. 473.69 .' ...'. ... 768.15 896.18 460.89 672.13 532.91 576.12 576.12 1120.22 .' .,'. . 460.89 . , .. /..<:: .,~ 604.92 704.14 516.90 608.12 1120.22 395.28 640.1 3 907.38 640.13 576.12 820.96 832.17 364.07 588.12 592.12 476.10 504.10 560.11 Kf TEMP factor . ..' ...' . . .. . . . :: .; ~~~. ~ :.; ., . . .. .., . . I' .,' " . . "', ...1' . ., ., . , :: . ,. .' '. ... .; . .... : . .'.~ , '. , OIL CUMM. stb 855.52 864.77 880.07 889.97 899.97 920.77 927.11 933.11 942.98 958.98 977.65 987.25 1001.25 101 2.36 1024.36 1036.36 1059.70 1069.30 1081.90 1096.57 1107.34 1120.01 1143.35 1151.58 1164.92 1183.82 1197.16 1209.16 1226.27 1243.60 1 251 .19 1263.44 1275.78 1 285.70 1296.20 1307.8ì ) ) SURFACE TESTING REPORT OIL FLOW RATE CALCULATIONS DA TEffIME rn Id/yr hr rnm 4/21/0010:00 4/21/0010:30 4/21/00 11 :00 4/21/0011 :30 4/21/0012:00 4/21/00 12:30 4/21/00 13 :00 4/21/00 1 3 :30 4/21/00 1 4 :00 4/21/00 14:30 4/21/00 15:00 4/21/00 15:30 4/21/0016:00 4/21/00 16:30 4/21/00 17:00 4/21/0017:30 4/21/0018:00 4/21/00 18:30 4/21/00 19:00 4/21/00 19:30 4/21/0020:00 4/21/0020:30 4/21/00 21 :00 4/21/0021 :30 4/21/0022:00 4/21/00 22:30 4/2 1/00 23 :00 4/21/0023:30 4/22/00 0:00 4/22/00 0:30 4/22/001:00 4/22'00 1 :30 4/22/00 2:00 4/22/00 2:30 4/22/00 3:00 4/22/00 3:30 . . .' ..". .. " ..' '. . . .. .' . I' . \',.. .. I . . "':':'. ..":.'~ -: . ~ , . """""""""""" . . 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 36 . ~ '. .'INUIIIA."""'''''''''''''''ð'''~~'''''''''''''''''''''''''''''''"'''''''''''''-'''' ~~ ~~ COMPANY: FIELD: Lease: Well#: HALLIBURTON J VOLUME INC. bbls 12.036 18.337 8.835 18.337 18.004 6.668 2.334 9.902 6.968 10.002 12.252 9.502 12.252 8.502 8.335 10.135 7.918 8.502 10.135 9.502 9.602 10.502 9.002 11 .002 8.268 10.502 15.837 6.001 11.402 8.235 11.102 9.502 7.401 15.837 11.252 9.252 FLOW HYDROMETER COR. INT. GRAVITY TEMP GRA VlTY rnin a~~ OOg t @ (jJ" 30 30 30 30 30 :.' , 30 c.. . . 30 i 30 30 30 ,.' 30 30 30 30 ~ : C ' 30 30 ,: 30 30 c 30 , 30 30 30 1.. 30 30 30 30 ' 30 i" 30 30 30 30 30 30 30 30 30 .. OIL BS&W '~ 62°'0 45°c:. 47°0 45°,c:. 55~0 600~ 80°0 78c:.~ 78c:.o 700~ 65c:.o 70c:.o 65"0 651:.0 70~0 68c:.o 75°0 70~~ 6800 70~0 68°0 70°0 70°0 70o~ 691)0 65°0 62co 64"0 64°~ 62~~ 63~0 62°'0 63°0 50~0 55°0 63~0 . "', .,", '. ",. .,,-' . , . , . .I' . ", ...: .:. ".' :' . ," .~.. J. . . ,"' . '.... . '" . , '. . J . . . ", '. '" ,.1': . . . . . . ..' . '. . . . '.. . ; ,,>:: ,:..~':;:;: .;::iú~~~~;J . . . J.: . " .. '", . :," ~:; <' ... ~~~'~'<~:.~':~¿',,~~,: ARca Alaska, Inc. OIL TEMP degt Kf Cf Mf Wf METER TANK TEMP Mf . Wf METER SHRKG COR. VOL INC. factor factor factor factor stb b~s TANK TEMP deg F . . . . . . . . ,", . . ", . 1"" .~... '.. . . . . ",", ... . . . .. ... . "" .. . ... . . . . ., . . . .. .'. . . . . . . ....:.......:..................................:.., '." 1 01.77 0.98032 99.83 0.98128 100.06 0.98080 97.15 0.98224 96.68 0.98239 96.3 0.98272 96.06 0.98269 96.03 0.98270' . . 92.67 0.98464 90.93 0.98512 91.99 0.98503 91.95 0.98505 91.67 0.98518 91.69 0.98517 92.29 0.98489 92.01 0.98502 92.18 0.98494 91.16 098542 90.66 0.98565 ,'''.'. ':' '. '., . 90.23 0.98585.. . . , ., 90.34 0.98580';' . ;". .:. '.". '. 92.41 0.98483 91.12 0.98544 91.15 0.98542 93.06 0.98453 95.46 0.98341 92.38 0.98485 96.89 0.98274 97.57 0.98242 97.06 0.98266 ., '. . . . '. . . . : .. . . " . .'. . . . . .\' .' , . . " .,~. .:.:...~.." ..... ... ~, .. , ~ ~.:..:. Page4 ARCO Alaska,lnc Wildcat Nanuk 2 '. Kf TANK COR. TEMP COR.VOL OIL RATE factor stb stb/d . ,..... ".: . .:'. . ":.. .' .'.. .~) 577.72 .: ' . ' ':.' : ~:.~. ':~ :~:~: ". :' ~,: ,: ..::. ",,: "> .':~.}. ~ 880.18 '. . . .' : '.' "'.) 864.17 . '.' . '.... ..'=,. 320.06 ,'.'. ' 112.02 ... . " '. . .".'.;';:::.; ~~:¡~ . . .. . . . '. " . 480.10 ., 588.12 456.09 588.12 ... -::. 408.08 .. ... >"..., .., 400.08 . . . 486.50 ., .. 190.04 : :; ~ ..: " . '. "'. '? 408.08 486.50 456.09 460.89 504.10 432.09 528.11 396.88 504.1 0 760.15 288.06 547.31 395.28 532.91 456.09 355.27 760.15 540.11 444.09 " . .. . . . . '. .. . . . . .. OIL CU MM. stb 1319.90 1338.24 1347.07 1365.41 1383.41 1390.08 1392.42 1402.32 1409.29 1419.29 1431.54 1441.04 1 453.30 1461.80 1470.13 1480.27 1488.19 1496.69 1506.82 1516.32 1 525.93 1 536.43 1545.43 1 556.43 1 564.70 1575.20 1591.04 1 597.04 1608.44 1616.68 1627.78 1637.28 1644.68 1660.52 1671.77 1681.02 ) SURFACE TESTING REPORT OIL FLOW RATE CALCULATIONS DA TEfTIME m/d/yr hr:rnm 4/22/00 4:00 4/22/004:30 4/22/00 5:00 4/22/00 5:30 4/22/00 6:00 4/22/006:30 4/22100 7:00 4/22/007:30 4/22/00 8:00 4l22.'00 8:30 4/22/00 9:00 4/22/009:30 4/22/0010:00 4/22/0010:30 4/22/00 11 :00 4/22/00 11 :30 4/22/00 1 2 :00 4/22/00 12:30 4/22/00 1 3 :00 4/22/00 13:30 4/22/00 14:00 4/22/00 14:30 4/22/00 15:00 4/22/00 15:30 4/22/00 16 :00 4/22/0016:30 4/22/00 17:00 4122/00 17 :30 4/22/00 18:00 4/22/00 18 :30 4/22/0019:00 4/22/00 19:30 4/22/00 20 :00 4/22/0020:30 4/22/0021 :00 4/22/00 21 :30 FLOW INT. min 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 HYDROMETER GRAVITY TEMP '.": . a~ ~~.~.~ ~ ,. .. ..: .. :-"-'!" .. (." " ;" . '" ....." . , .... . : . . . .. ... ""'..' 1'. . :. ..., , .. ~ , ' ., , . .. ; . " .. .. " ;< ,~:'~~/..::: :-) ¡. ~'~, ~;,.:~.; .~/ ~;,;::Jf~i~: i(~;jJ;~;~: . , COR. GRAVITY @W' 36 36 36 36 36 36 40.2 40.2 40.2 39.8 39.8 43.4 43.4 43.4 43.4 43.4 43.4 43.4 39.7 39.7 39.7 39.7 39.7 39.7 39.7 39.7 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 39.5 39.5 . , . , . . . , HALLIBURTON VOLUME INC. bbls 9.869 11.402 10.802 10.769 11 .902 12.002 14.003 7.602 11.719 11 .336 12.603 10.502 10.669 11 .002 10.794 1 1 .669 10.769 1 1 .402 11.402 1 1 .086 9.627 10.502 10.135 12.953 11 .002 12.336 10.335 11 .086 11.902 8.752 11.086 9.869 11.252 10.769 11 .402 10.802 OIL BS&W % 63°~ 62°~ 62°~ 62°'0 58°~ 600~ 60°0 62"0 63°0 60°'° 58°0 65°0 6000 600~ 65°0 60°" 62°~ 62°0 62°(' 62c.~ 65°,~ 65°~ 62°0 58°0 60°'~ 60°0 60°0 62°'0 58% 65°~ 65°,~ 63°'Q 62.5~~ 62°~ 62% 64°~ OIL TEMP deg f 96.22 96.46 97.25 98.1 98.27 97.61 96.98 97.46 98.21 99 99.32 99.46 98.56 98.02 98.01 98.45 99.23 99.48 98.76 97.72 97.3 96.89 96.45 96.97 97.69 98.09 98.71 98.54 98.34 97.39 97.32 96.99 97.1 97.26 97.85 98.16 Kf Cf Mf Wf METER TANK TEMP Mf" Wf METER SHRKG COR. VOL. INC. factor f(Jcter foctor foctor stb bbls 0.98305 0.98294 0.98257 0.98217 0.98209 0.98240 0.98186 0.98163 0.98126 0.98096 0.98080 0.97994 ; 0.98040 0.98068 0.98068 0.98045 0.98006 0.97993 0.98110 0.98160 0.98181 0.98201 0.98222 0.98197 0.98162 0.98142 0.98141 0.98150 0.98159 0.98205 0.98208 0.98224 0.98219 0.98211 0.98158 0.98143 '. '" .. .. Page5 ~~ ~~ ARCO Alaska, Inc. COMPANY: FIELD: Lease: Well#: TANK TEMP ~.eg F .. .' . . .. . . .... ", . . . . '. '.' . .. .. ARca Alaska,lnc Wildcat Nanuk 2 .. Kf TANK COR. TEMP COR. VOL OIL RATE factor stb stb/d 473.69 .. J "~ ~ 547.31 518.50 516.90 571.31 576.12 672.13 364.87 .. .. ~."" 562.51 ." ! 544.11 604.92 504.1 0 512.10 , J 528.11 : '::'" ~ , "} 518.1 0 .:. ~.: ~~:~<~. ~ 560.11 516.90 547.31 547.31 532.11 ": ^f'"',.. ~ 462.09 ,.:-.:... i? ~ 504.10 . ".. ,'. 486.50 . .... ~ . ~ 621.72 528.11 592.12 496.10 532.11 571.31 420.08 532.11 473.69 540.11 516.90 547.31 518.50 .. .. . :, .. ~..:.., ~~~ ;.,Ö ..: ...... .. .. .. , . '" .. . . ":f .. .;::~'.~:.~ . ....., ~~".~.~r~~~,.~ OIL CUMM. stb 1690.89 1702.30 1713.10 1723.87 1735.77 1747.77 1761.77 1 769.38 1781.09 1792.43 1805.03 1815.53 1826.20 1837.21 1848.00 1859.67 1870.44 1881.84 1893.24 1904.33 1913.95 1 924.46 1934.59 1947.54 1958.55 1970.88 1981.22 1992.30 2004.21 2012.96 2024.04 2033.91 2045.16 2055.93 2067.33 2078.14 ) ) SURFACE TESTING REPORT OIL FLOW RATE CALCULATIONS DATEfTIME rn/d/yr hr mm 4/22/0022:00 4/22/00 22:30 4/22/00 23 :00 4/22/0023:30 4/23'00 0:00 4/23'00 0:30 4/23.'00 1 :00 4/23/00 1 :30 4 '23l00 2:00 4/23/00 2:30 4/23'003:00 4/23.100 3:30 4/23l00 4:00 4/23/00 4:30 4/23/00 5:00 4/23,'00 5:30 4/23'006:00 4/23'006:30 4/23/007:00 4/23/00 7:30 4/23.'008:00 4/23/00 8:30 4/23.'00 9:00 4/23'00 9:30 4/23/00 10:00 4/23/00 10:30 4/23/00 11 :00 4/23/00 11 :30 4/23100 12:00 4/23100 12:30 4/23/00 13:00 4/23/00 13:30 4/23100 14:00 4/23/00 14:30 4/23100 15:00 4/23/00 15:30 FLOW INT. min 30 30 30 ; 30 30 30 30 30 30 30 ~ 30 30 30 30 30 30 30 30 30 30 30 30 30 i 30 30 30 30 30 30 30 30 30 30 30 30 30 HYDROMETER GRAVITY TEMP api ~g t .. " ... .. . ." ". ... .. ."," ":" .. : ~~ ~ ~... "'." ." :::. ~: . y ." . . . .. ,. , .. ". ". ... -."...'" ~... . "~ . ..: 1'. .. , .. .... ..".. i':r~::X~ ¡U~~j',~:f~1 ;~~~,+~.:~:~~~~ . . COR. GRAVITY @t:IJ" 39.5 39.5 39.5 39.5 39.5 39.5 39.4 39.4 39.4 39.4 39.4 39.4 39.4 39.4 39.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8 39.8 39.1 39.1 39.1 39.1 39.1 39.1 39.1 36.4 36.4 36.4 36.4 36.4 36.4 .: ."""......""~"""".......,....~...""""""",,,""""'C HALLIBURTON VOLUME INC. bbls 11.102 10.485 9.869 10.802 9.602 10.202 10.485 9.002 11.052 11.402 9.869 9.252 10.485 8.402 10.202 9.602 10.485 12.644 11.669 12.377 12.252 11.336 10.335 13.261 10.852 11.052 12.002 10.936 9.919 11.277 10.452 10.177 12.352 10.335 12.544 11 .336 OIL BS&W '1é 63°0 63co 63°~ 64°0 64~0 64°~ 63°0 63°0 61 °0 62°0 63°0 63':'0 63°.:. 64°0 64~0 64Co 63°0 59co 60°0 55°0 58°0 60°0 60~0 5iOo 58°0 61°.~ 600~ 59% 65~~ 59~0 62°.~ 63~o 61°~ 60% 57°'0 60% OIL TEMP deg t 98.43 98.56 98.66 99.1 99.23 99.01 98.96 98.16 97.93 97.69 97.62 97.61 97.72 97.98 98.66 98.99 99.12 99.29 99.19 99.17 99.29 99.2 99.04 98.8 97.83 97.38 97.94 98.17 98.35 97.42 97.49 99.03 98.48 97.94 99.65 99.58 ~~ ~", COMPANY: FIELD: Lease: Well#: ARCO Alaska, Inc. TANK TEMP deg ~ . . . .. .. .. .. .. . . '. ... .. , . h Page6 ARCO Alaska,lnc Wildcat Nanuk 2 TANK COR. eOR.VOL OIL RATE stb stb/d ,. .. ."" ,'. 532.91 :. . .~.: 503.30 473.69 ". 518.50 '. 460.89 . . .. 489.70 . ..'.' ., 503.30 432.09 .., 530.51 547.31 473.69 444.09 503.30 403.28 ,,:' 489.70 460.89 . .\:.;.'~ 503.30 606.92 . .. ~i., 560.11 594.12 588.12 544.11 496.10 636.53 520.90 530.51 576.12 524.90 476.10 541.31 501 .70 488.50 592.92 496.10 602.12 544.11 Kf TEMP factor . . 'd .. .. .. . . '. .. OIL eUMM. stb 2089.24 2099.72 2109.59 2120.40 2130.00 2140.20 2150.68 2159.69 2170.74 2182.14 2192.01 2201.26 2211.75 2220.15 2230.35 2239.95 2250.44 2263.08 2274.75 2287.13 2299.38 2310.72 2321.05 2334.31 2345.17 2356.22 2368.22 2379.16 2389.07 2400.35 2410.80 2420.98 2433.33 2443.67 2456.21 2467.55 ) ) Kf Cf Mf Wf METER TANK TEMP Mf" Wf METER SHRKG COR.VOL INC. foetor foctor factor factor stb bbls 0.98130 0.98124 0.98119 0.98097 0.98091 0.98102 0.98106 0.98145 0.98156 0.98168 0.98171 0.98172 0.98167 0.98154 0.98112 0.98096 0.98090 0.98082 . 0.98087 ' 0.98088 0.98082 0.98086 0.98094 0.98120 0.98167 0.98189 0.98162 0.98151 0.98142 0.98187 0.98238 0.98165 0.98191 0.98217 0.98136 0.98140 :: . : : ~ :.:.~~ . . . ... ~ . ~ <~ .., :'", :~:::'2à'/) :.... :.\.~.:..; ~ : ~. ~~, ~< .? J' . . \. \ ~ . ~ .". : .~:~:~=:" :..~ <;':::;"::::'< ~:.:::,:':::.:,.. '., . ::i' ,: ":'.:" ..' .. ::.. " :;. :.:,,'<i.r~:c:':..~:r..~<~t;~~111~ ::i;;.<},_;~4s~~~;:'::~:"':::::""';~Y:~::n 'n ::.::::;:~.': m:::~:::~::LL~:"n'::':'n:/:;";;~:~~;~îj SURFACE TESTING REPORT OIL FLOW RATE CALCULATIONS DA TEfTIME rn/d/yr hr rnrn 4/23/00 16:00 4/23/00 16:30 4/23/00 17:00 4/23/00 17:30 4/23/00 18:00 4/23/00 18:30 4/23,'0019:00 4/23/00 19:30 4.'23/00 20:00 4/23/00 20:30 4/23..00 21 :00 4/23/00 21 :30 4/23,'00 22:00 4/23/0022:30 4/23/00 23:00 4/23/0023:30 4:2--1,'000:00 4,.24:00 0:30 4/24'00 1 :00 4.'24/00 1 :30 4/24.'00 2:00 4/24/00 2:30 4/24/003:00 4/24/00 3:30 4/24.'004:00 4/24'00 4:30 4/24'00 5:00 4.'24,'00 5:30 4/241006:00 4/24100 6:30 4/24100 7:00 4/24/00 7:30 4/24/00 8:00 4/24100 8:30 4/24/00 9:00 4/24/00 9:30 FLOW INT. min 30 30 30 30 30 30 30 30 30 30 30 '30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 30 HYDROMETER GRAVITY TEMP .~~~ ~:~ ~ .. '."". ".," '. .. ... "": " . '.. ...' .... :- ....: j .: : '.". . . :. j'. . , .... ".. J' , . .. .. .. 1 1 .' .. . .' .. .. ". ¿ '. . .. .. ... : ... .. ... ..~ . . . '. ::":-.1:"..: '~:. ~...'~ ~'. . ..' ,- ", ~ ". .. ., . ~ . .'". : ~:. ~ '" : ". . J' . .. . , ~,:~~',~:. {;:~~:,:. ~:':;~~. ~~: i}~.~~~f~ :;~~~I:~ìgTh~! ;...' ...~.:..._...~:.~.:' ...:.. 0":'" .u~~~--~'A COR. GRAVITY @W' 36.4 36.4 35.7 35.7 35.7 35.7 35.7 35.7 35.7 35.7 39 39 39 39 39 39 39 39 37.7 37.7 37.7 37.7 37.7 37.7 37.7 37.7 38.3 38.3 38.3 38.3 38.3 38.3 38.3 38.3 36.8 36.8 ."IA.~""'''~~''''''''''VI.'''''''''''''''''''''"' HALLIBURTON VOLUME INC. bbls 10.669 12.669 11 .669 10.452 10.936 13.936 7.401 10.202 10.202 11.552 8.752 11.719 9.335 10.502 10.135 11.669 9.60192 11.40228 9.86864 10.20204 10.48543 10.40208 10.20204 9.91865 11.40228 11 .40228 8.75175 11.40228 9.3352 11.71901 10.6688 9.626925 9.63526 11 .08555 9.86864 11.10222 OIL BS&W '!c. 6000 6000 6000 62~0 5900 62°~ 63~~ 63c:.0 66~0 6700 65~0 65°0 65°0 6500 6200 6500 64':'0 6400 6300 64°~ 6300 61 DO 64c:.~ 65c:.~ 64°~ 6400 65°~ 64°c 65~~ 6200 60~~ 65°~ 66°~ 65°~ 6300 64°0 OIL TEMP deg f 98.51 98 98.18 98.22 97.72 98.22 97.76 97.7 97.7 97.5 97.8'3 98.09 98.51 99.03 99.18 99.41 99.44 99.34 99.26 98.92 98.14 97.86 97.77 97.38 97.97 96.84 97.44 97.91 98.29 98.69 98.54 97.99 97.58 97.51 97.38 97.69 Kf Cf Mf Wf METER TANK TEMP Mf. Wi METER SHRKG COR.VOL INC. toctor factor t~:tor foctor stb bbls 0.98190 0.98214 ' 0.98219 0.98217 0.98241 0.98217 0.98239 0.98242 0.98242 0.98251 0.98139 0.98157 0.98137 0.98111 0.98104 0.98093 0.98092 0.98096 0.98128 0.98144 0.98181 0.98194 0.98199 0.98217 0.98189 0.98243 0.98202 0.98180 0.98162 0.98142 0.98150 0.98176 0.98196 0.98199 ,.., ~ I' . , '" 0.98235 0.98220 . . , . '. Page7 . . . . ~~ ~", ARCa Alaska, Inc. '. . . '" . "'.. .. .. . . " ; . , . :~'.';' r . ....:~ ~ ... ...'.. .: . . . .~ "'''~ --: ~ .' :. .. ':~. ::< . . ..:...':~ .,' . . ~ . . y ':' '. :~ ,'~~:;\:~.' ; COMPANY: FIELD: Lease: Well#: TANK TEMP ~.~F .. .. ... ". . . '. . . ., ."' : .. .' .. Kf TEMP toctor .'.. ''''".:.. . . .. ." ., .. ARCO Alaska,lnc Wildcat Nanuk 2 . . TANK COR. COR.VOL OIL RATE stb stb/d 512.10 . ~ .::.':: .; 608.1 2 . ~ ~ . .. .. 560.11 501 .70 524.90 668.93 ~~~~~ 355.27 . ",'" .,t ::::;~ 554.51 ,=. 420.08 562.51 .. 448.09 .... '. m.., 504.10 . . "~ .. =. 486.50 . :. 560.11 460.89 . > 547.31 '.."' : 473.69 ',..'..) 489.70 503.30 499.30 489.70 476.10 547.31 547.31 420.08 547.31 448.09 562.51 512.10 462.09 462.49 532.11 473.69 532.91 : . .... ".; . -:. : . ":=.".."'-:' : '. =. . . .. .. OIL CU MM. stb 2478.22 2490.89 2502.56 2513.01 2523.94 2537.88 2545.28 2555.48 2565.68 2577.24 2585.99 2597.71 2607.04 2617.54 2627.68 2639.35 2648.95 2660.35 2670.22 2680.42 2690.91 2701.31 2711.51 2721.43 2732.83 2744.24 2752.99 2764.39 27ì3.73 2785.45 2796.11 2805.74 281 5.38 2826.46 2836.33 2847.43 ) SURFACE TESTING REPORT OIL FLOW RATE CALCULATIONS DA TEfTIME m/d/yr hr:mm 4/24'0010:00 4/24'00 10:30 4/24/00 11 :00 4/24/0011 :30 4/24'00 12:00 4/24/00 12:30 4/24/00 13 :00 4/2410013:30 4/24/0014:00 4/24/0014:30 4/24/0015:00 FLOW INT. min 30 30 30 30 30 30 30 30 30 30 30 HYDROMETER GRAVITY' TEMP ,.",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,"....,,,~~,~.,.,,,,,,,~ HALLIBURTON COR. VOLUME. GRAVITY INC. @ roo bbls 36.8 9.91865 36.8 10.210375 36.8 8.53504 36.8 10.727145 36.8 9.043475 36.8 11.40228 33.8 10.5021 33.8 10.48543 33.8 10.48543 33.8 9.86864 33.8 7.40148 OIL BS&W % 65% 65% 68% 67% 65% 62% 65% 63% 63% 63~'~ 63% OIL TEMP degf 98.54 98.54 98.75 98.29 97.59 97.46 98.05 99.43 99.38 97.8 97.27 Kf . TEMP fae tor 0.98180 0.98180 0.98170 0.98192 0.98225 0.98231 0.98262 0.98199 0.98202 0.98274 0.98298 ~~ ~~ . ARCO Alaska, Inc. COMPANY: FIELD: Lease: Well#: ARCO Alaska,lnc Wildcat Nanuk 2 Cf Mf Wf METER TANK TANK. Kf TANK COR~ '. . Mf" Wf METER SHRKG COR.VOL INC.' - TEMP' TEMP COR. VOL OIL RATE . factor factot factor stb, b~s .....9~F...........~~~.t0.....~.........~~.~........: stb/d' . 476.1 0 490.10 409.68 514.90 434.09 547.31 504.10 503.30 503.30 473.69 355.27 Page8 . OIL' CUMM. stb: 2857.35 2867.56 2876.10 2886.82 2895.87 2907.27 2917.77 2928.26 2938.74 2948.61 2956.01 ) ) OHÃWBURTON T~,!.D* . . ,.,. (IÜ 2 u'J 4, HMXI 2 3(1 .1' I ~ ljo) 3 (¡{I . .1~O'.J3jlJ .1, 19 (IIj 4.00 4'I9Ù(4)0 .1' 19 1)1) 5.i)t) 4,19 (J') 5)0 4'19(10600 4 19 ')'j f.'. )(, 4 l'dt (10 i .I~tll .119(10730 4 I ~'(IO 8.0(1 .1 I 9 1)1) €I )(1 J. I c;o ')0 ~ l't) 4 I ~ (II) ':t j(' 4, 1<:0 0ÏJ 1').(11) 4. 1<3 0(1 1(1 j,) 4. Hi (II) 1 I (10 4.' Ir. ':":1 1 I.)t) 4. I/"1 (II) 12 (II) 4. 1<3 ')Ù 1,,' j') 4. I~ (II) 1:'.(IIJ 4. 19 ,),) 14.jlj 4. 1<3 ,J,) 1 i3 ,j,J 4. 19 (.{, 16 jo) 4. 1 c:. (lIj 1 7 1)(' 4 l\j Ù(¡ 17:),) 4 I ~ (1(' I t.< (II) 41'1 (1(0 1io ),j 4 1';' (II') 19(11) 4. "~ (II) 1~ :11j 4. 1 'it (II) :¿rl) 1)(1 4, 1 ~ (10 :?(, )'j 4.'I~ (II) 21.(11) 4. 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0.134802 0.967 1039.13 19.837 952.190 2273.051 8.502 408.082 1461.797 3734.85 4/21/00 17:00 48 244.6 85.32 656.01 214.06 83.75 171.14 83.68 70% 14000 36 140.16 40.72 94.35 1.25 0.5576943 0.146421 0.967 2266.8 25.005 1200.240 2298.056 8.335 400,080 1470.132 3768.19 4/21/00 17:30 48 249.04 85.09 656.19 227.82 83.6 175.2 83.2 68% 14000 141.04 40.76 93.76 1.25 0.5599251 0.158086 0.967 1454.18 21.538 1033.807 2319.593 10.135 486.497 1480.267 3799.86 4/21/00 18:00 48 238.63 85.04 656.12 224.91 83.6 178.1 83.59 75% 14000 141.22 40.31 92.82 1.25 0.5577234 0.169705 0.967 1548.82 23.755 570.114 2343.348 7.918 190.038 1488.186 3831.53 4/21/0018:30 48 241.71 85.06 655.97 216.39 83.52 183.7 83.51 70% 14000 136.19 43,19 92.33 1.250.5678458 0.181535 0.967 1582.26 19.837 952.190 2363,185 8.502 408.082 1496.687 3859.87 4/21/00 19:00 48 234.97 84.9 656.08 209.41 83.45 179.25 83.42 68% 14000 135.87 41.9 92.75 1.25 0.5584394 0.193169 0.967 1 524.62 21.538 1033.807 2384.723 10.135 486.497 1506.823 3891.55 4/21/00 19:30 48 241.13 84.82 656.01 223.17 83.5 172.11 83.43 70010 14000 129.26 46.76 92.82 1.25 0.5764006 0.205178 0.967 1559.1 22.171 1064.213 2406.894 9.502 456.091 1516.325 3923.22 4/21/00 20:00 48 237.09 84.84 656.16 222.01 83.39 150.86 83.3 68% 14000 120.29 52.7 92.9 1.25 0.5920297 0.217511 0.967 1513.71 20.404 979.396 2427,298 9.602 460.892 1525.927 3953.22 4/21/00 20:30 48 228.03 84.79 656.3 208.64 83.31 158.2 82.7 70% 14000 118.05 52.14 93.93 1.25 0.6217274 0.230464 0.846 1401.33 24,505 1176.235 2451.803 10.502 504.101 1536.429 3988.23 4/21/0021 :00 48 236.89 84.98 656.27 209.8 83.43 150.67 83.04 70% 14000 118 52.45 93.81 1.25 0.6234897 0.243454 0.846 1283.3 21.004 1008.202 2472.807 9.002 432.086 1545.430 4018.24 ) 4/21/00 21 :30. 48 225.33 84.85 656.27 202.83 83.34 135.6 82.96 70% 14000 121.37 53.86 93.69 1.25 0.6379492 0,256744 0.852 1558.61 25.672 1232.246 2498.479 11.002 528.106 1556.433 4054.91 4/21/00 22:00 48 246.34 85.29 656.63 226.46 83.74 175 83.25 69% 14000 125.9 56.72 94.35 1.25 0.665389 0.270606 0.852 1900.76 18.404 883.377 2516.883 8.268 396.879 1564.701 4081.58 4/21/00 22:30 48 240.36 85.35 656.3 218.91 83.75 169.21 83.41 65% 14000 121.9 55.14 94.84 1.25 0.6460553 0,284066 0.852 2155.97 19.504 936.187 2536.387 10.502 504.101 1575.203 4111.59 4/21/00 23:00 48 234.77 85.02 657.04 201.86 83.48 147.96 83.05 62% 14000 119.74 53.59 94.22 1.25 0.632078 0.297234 0.852 2256.5 25.839 1240.248 2562.225 15.837 760.152 1591.040 4153.26 4/21/00 23:30 48 242.1 85.43 656.78 222.01 83.88 162.64 83.27 64% 14000 126.11 57.9 93.79 1.25 0.6731928 0.311259 0.852 1814.31 10.669 512.102 2572.894 6.001 288.058 1597.041 4169.93 4/22/00 0:00 48 202 84.97 656.45 183.07 83.9 148.16 83.54 64% 14000 85.16 37.29 92.76 1.25 0.4532855 0,320702 0.852 1510.82 20.271 972.995 2593.165 11.402 547.309 1608.443 4201.61 4/22/00 0:30 48 161.53 82.22 654.61 137.74 80.82 103.15 80.39 62% 14000 101.32 26.13 92.16 1.25 0.416771 0.329385 0.822 2535.78 13.436 644.929 2606.601 8.235 395.279 1616.678 4223.28 4/22/00 1 :00 48 182.54 73.08 653.03 170.86 73.97 140.82 73.26 63% 14000 138.95 13.87 92.55 1.25 0.3538072 0.336756 I 1334.17 18.904 907.381 2625.505 11.102 532.907 1627.780 4253.28 0.806 4/22/00 1 :30 48 201.43 81.2 653.62 187.14 78.78 147.19 78.93 62% 14000 147.36 35.81 91.57 1.25 0.5852046 0.348948' 0.806 1390.64 1 5,503 744,149 2641,008 9.502 456.091 1637.282 4278.29 4/22/00 2:00 48 191.21 75.54 651.93 183.46 75.43 161.48 72.77 63% 14000 147.03 13.1 93.68 1.25 0.3588504 0.356424 o.m 857.496 12.603 604.921 2653.610 7.401 355.271 1644.684 4298.29 4/22/00 2:30 48 305.13 81.73 653 287.49 80.46 255.17 80.43 50% 14000 151.05 17.19 94.84 1.25 0.4143826 0.365057 0.783 837.361 15.837 760.152 2669.447 15.837 760.152 1660.520 4329.97 4/22/00 3:00 48 297.61 81.86 653.44 278.77 80.76 247.05 80.59 55% 14000 146.72 16.96 93.97 1 .25 0.4063742 0.373523 0.783 589.2 13.753 660.132 2683.199 11.252 540.108 1671.772 4354.97 4/22/00 3:30 48 298.96 82.68 653.51 282.06 81.42 239.33 81.15 63% 14000 144.02 13.5 93.07 1.25 0.3603421 0.38103 0.78 576.248 15.753 756.151 2698.953 9.252 444.089 1681.024 4379.98 Gas D1f1 Total Choke Well Head Annulus Gas Static Press Gas Gas Flow Incremental Water tncremental Tota! on SiZe . Press Well Head Pr.:¡gs DSS"FP OSSFT DSCP' DSCT API@ Press Incl1as Gas Temp Orifice MMSCF Total Gas In~e B3rrel per Produced Increase Barrel per Produced Time & Date 64ths PSIG Temp (F) PSIG PSIG (F) PSIG (F) BS&W ChlQride 6IJF PSIG H2O (F) Size' DAY MMSCF Gas SG GOR (bbI) D;:¡y (bb1) (bbI) Day (bbJ) Total Auid 4/22/00 4:00 48 302.62 82.82 653.77 286.13 81.62 253.81 81.58 63% 11000 145.05 17.54 92.9 1.25 0.4163336 0.389704 0.764 807.982 16.803 806.561 2715.756 9.869 473.695 1690.693 4406.65 4/22/00 4:30 48 306.48 83.21 654.17 291.94 81.71 254.39 81.71 62% 11000 145.34 17.56 93.04 1.25 0.4168252 0.398388 0.764 804.409 18.604 892.979 2734.360 11 .402 547.309 1702.295 4436.65 4/22/00 5:00 48 305.51 83.04 653.99 290 81.82 250.14 81.71 62% 11000 146.01 17.64 93.51 1.25 0.4165176 0.407065 0.772 790.726 19.204 921.784 2753.564 10.802 518.504 1713.097 4466.66 4f22/oo 5:30 48 304.93 83.09 652.37 288.07 81.83 245.51 81.69 62% 11000 143.42 20.01 93.95 1.25 0.4397187 0.416226 0.772 833.047 17.570 843.369 2771.134 10.769 516.903 1723.866 4495.00 4/22/00 6:00 48 302.81 83.35. 654.06 286.13 82.01 245.9 82.06 58% 11000 130.38 21.61 90.86 1.25 0.4390447 0.425373 0.77 832.52 16.437 788.958 2787.570 11.902 571.314 1735.768 4523.34 4/22/00 6:30 48 305.9 84.03 654.28 291.55 82.55 246.47 82.75 60% 11000 124.39 23.63 93.22 1.25 0.4483264 0.404514 0.77 750.211 18.004 864.173 2805.574 12.002 576.115 1747.771 4553.34 4/22/007:00 48 300.31 84.08 654.69 287.1 82.84 250.72 83.05 60% 11000 40.2 124.63 23.59 94.1 1.25 0.447917 0.413846 0.77 741.73 21.004 1008.202 2826.578 14.003 672.134 1761.774 4588.35 4f22/00 7:30 48 308.21 84.28 654.94 286.52 82.82 247.05 83.48 62% 11000 124.45 23.56 94.34 1.25 0.4845645 0.423941 0.77 807.014 12.402 595.319 2838.981 7.602 364.873 1769.375 4608.36 4f22/00 8:00 48 307.83 84.38 654.83 286.32 83.44 248.99 83.59 63% 11000 124.3 23.5 94.86 1.25 0.4792321 0.433925 0.784 885,793 19.954 957.792 2858.935 11.719 562.512 1781.094 4640.03 4/22/00 8:30 48 307.83 84.21 655.13 284.39 83.34 251.11 83.54 60% 11000 39.8 124.81 23.61 95.44 1.25 0.4809654 0.443945 0.784 889.352 17.003 816.163 2875.938 11.336 544.109 1792.430 4668.37 4f22/oo 9:00 48 309.75 84.55 655.05 285.16 83.58 248.79 83.68 58% 11000 125.14 23.62 95.35 1.25 0.4817139 0.454002 0.784 891.428 17.403 835.367 2893.341 12.603 604.921 1805.032 4698.37 4/22/00 9:30 48 313.61 85.35 654.98 287.49 83.77 253.62 83.98 65% 11000 43.4 125.92 23.75 95.37 1,25 0.4873606 0.464155 0.774 905.26 19.504 936.187 2912.845 10.502 504.101 1815.534 4728.38 4/22/00 1 0:00 48 325.17 86.38 655.09 288.07 83.98 251.69 84.19 60% 11000 126.03 23.71 95.23 1.25 0.487212 0.474305 0.774 902.82 16.003 768.154 2928.849 10.669 512.102 1826.203 4755.05 ) 4/22/00 1 0:30 48 328.26 86.47 655.16 287.1 83.63 254.2 84.23 60% 11 000 126.26 23.69 95.12 1.25 0.4874507 0.484461 0.774 863.962 16.503 792.158 2945.352 11.002 528.106 1837.205 4782.56 4/22/00 11 :00 48 332.31 86.54 655.27 290.39 83.78 254.97 84.23 65% 11000 127.04 23.73 95.09 1.25 0.4892495 0.494653 0.774 864.594 20.046 962.192 2965.398 10.794 518.104 1847.999 4813.40 4/22/00 11 :30 48 332.11 86.39 655.53 290.97 83.66 256.71 84.39 60% 11000 127.74 23.81 95.37 1.25 0.4912422 0.504888 0.774 747.202 17.504 840.168 2982.901 11.669 560.112 1859.668 4842.57 4/22/00 12:00 48 333.65 86.45 655.57 294.07 83.91 253.81 84.12 62% 11000 128.15 23.86 95.83 1.25 0.4909961 0.515117 0.778 869.199 17.570 843.369 3000.471 10.769 516.903 1870.437 4870.91 4/22/00 12:30 48 332.69 86.32 655.53 293.88 83.77 254.78 84.19 62% 11000 128.14 23.71 95.71 1.25 0.4895306 0.525315 0.778 870.676 18.604 892.979 3019.075 11.402 547.309 1881.839 4900.91 4/22/00 13:00 48 335.58 86.68 655.64 299.11 83.98 263.09 84.53 62% 11000 39.7 128.59 23.64 94.8 1.25 0.4900164 0.535524 0.778 868.178 18.604 892.979 3037.679 11.402 547.309 1893.242 4930.92 4/22/00 13:30 48 334.62 86.33 655.57 292.13 83.89 263.86 84.81 62% 11000 128.72 23.55 93.94 1,25 0.4894003 0.54572 0.779 910.712 18.087 868.174 3055.766 11.086 532.106 1904.327 4960.09 4/22/00 14:00 48 333.46 86.54 653.88 292.72 84.05 263,67 84.85 65% 11000 129.04 23.59 93.48 1,25 0.4905673 0.55594 0.779 915.109 17.879 858.172 3073.644 9.627 462.092 1913.954 4987.60 4/22100 14:30 48 334,81 86.58 655.64 295.23 83.9 266.76 85.03 65% 11000 129.02 23.49 93.14 1.25 0,4897297 0.566137 0.779 989.448 19.504 936.187 3093.148 10.502 504.101 1924.456 5017.60 4/22fOO 1 5:00 48 335.39 86.76 655.24 296.59 83.92 266.18 85.15 62% 11000 130.17 23.53 93.04 1.25 0.4922027 0.576392 0.779 996.025 16.537 793.759 3109.685 10.135 486.497 1934.592 5044.28 4/22fOO 15:30 48 335.77 86.8 655.75 295.23 84.1 260.77 85.06 58% 11 000 129.43 24.35 93.32 1.25 0.4991893 0.586791 0.779 1009.13 17.887 858.572 3127.572 12.953 621.724 1947.544 5075.12 4/22/00 16:00 48 333.27 86.84 655.97 295.82 84.17 264.25 85.18 60% 11000 125.01 25.72 93.42 1.25 0.5049212 0.597311 0.779 1025.88 16.503 792.158 3144.075 11.002 528.106 1958.546 5102.62 4/22/00 16:30 48 337.12 86.92 655.94 296.2 84.23 272.55 85.66 60% 11000 126.11 25.74 93.77 1.25 0.506943 0.607872 0.779 1017.17 18.504 888.178 3162.579 12.336 592.118 1970.882 5133.46 4/22/0017:00 48 337,32 86.94 655.97 294.46 84.3 267.34 85.57 60% 11000 38.3 125.86 25.52 94.05 1.25 0.5042437 0.618377 0.779 1014.84 15.503 744.149 3178.082 10.335 496.099 1981.218 5159.30 4/22/00 17:30 48 337.51 86.89 656.01 293.88 84.2 265.79 85.44 62% 11000 125.98 25.63 93.86 1.25 0.5056344 0.628911 0.785 1017.39 18.087 868.174 3196.169 11.086 532.106 1992.303 5188.47 4/22/00 1 8:00 48 338.67 86.81 655.71 292.91 84.18 262.31 85.52 58% 11 000 126.1 25.15 93.75 1.25 0.4993043 0.638043 0.785 927.422 16.437 788.958 3212.605 11.902 571.314 2004.205 5216.81 4/22fOO 18:30 48 338.47 86.86 655.97 295.04 84.04 261.35 85.22 65% 11 000 125.79 24.99 93.18 1,25 0.4973849 0.648448 0.785 913.604 16.253 780.156 3228.859 8.752 420.084 2012.957 5241.82 4/22/00 19:00 48 339.44 86.88 656.01 293.88 84.11 263.28 85.22 65% 11000 126.96 25.21 93.25 1.25 0.5017067 0.658892 0.785 837.317 20.587 988.198 3249.446 11.086 532.106 2024.043 5273.49 4/22/00 19:30 48 340.02 86.91 656.12 293.49 84.09 262.51 85.45 63% 11000 127.43 25.25 93.36 1.25 0.5028375 0.669349 0.778 995.211 16.803 806.561 3266.249 9.869 473.695 2033.911 5300.16 4/22/00 20:00 48 338.47 86.94 656.27 298.92 84.13 264.63 85.37 62.5% 11 000 128.16 25.28 93.15 1.25 0.5067911 0.679853 0.778 945.877 18.754 900.180 3285.003 11 .252 540.1 08 2045.164 5330.17 4/22/00 20:30 48 339.63 86.94 656.12 298.92 84.12 265.79 85.57 62% 11000 129.12 25.31 93.19 1.25 0.5088201 0.690427 0.778 950.644 17.570 843.369 3302.573 10.769 516.903 2055.932 5358.51 4/22/0021:00 48 339.63 86.94 656.16 294.65 84.05 272.74 85.93 62% 10000 39.5 129.91 25.65 93.74 1.25 0.5134259 0.701038 0.778 980.57 18,604 892.979 3321 .177 11.402 547.309 2067.335 5388.51 4/22/00 21 :30 48 338.47 87.19 656.12 292.72 84.17 278.54 86.01 64% 1 0000 129.51 25.42 93.79 1.25 0.5102997 0.71164 0.78 958.663 19.204 921.784 3340.381 10.802 518.504 2078.137 5418.52 4/22/00 22:00 48 340.79 87.41 656.71 300.27 84.23 283.76 86.16 63% 10000 129.42 25.3 94.01 1,25 0.5082621 0.722247 0.78 1003.71 18.904 907.381 3359.285 11.102 532.907 2089.239 5448.52 4/22/0022:30 48 339.82 87.1 656.16 296.2 84.13 272.17 85.94 63% 10000 129.74 25.38 94.21 1.25 0.5095412 0.732852 0.78 976.204 17.854 856.971 3377.138 1 0.485 503.301 2099,725 5476.86 4/22/00 23:00 48 341.75 87.13 656.08 298.72 84.09 271.97 85.88 63% 10000 146.32 22.16 95.53 1.25 0.5027407 0.743482 0.778 1011.9 16.803 806.561 3393.942 9.869 473.695 2109.593 5503.53 4/22/00 23:30 48 342.14 86.76 656.08 299.88 83.85 269.85 85.67 64% 10000 143.28 22.27 95.23 1.25 0.4997521 0.753839 0.778 982.314 19,204 921.784 3413.145 10.802 518.504 2120.395 5533.54 4/23/00 0:00' 48 341.56 86.69 655.83 299.69 83.88 273.9 85.62 64% 10000 144,02 22.63 95.37 1.25 0.5050109 0.764261 0.778 1020.36 17.070 819.364 3430.216 9.602 460.892 2129.997 5560.21 4/23/00 0:30 48 344.06 86.68 655.83 303.95 83.77 272.55 85.38 64% 11000 143.83 22.63 95.3 1.25 0.5047474 0.77477 0.778 1005.57 18.137 870.574 3448.352 10.202 489.698 2140.199 5588.55 4/23/00 1 :00 48 341. 56 86.68 655.68 301.63 83.77 272.17 85.51 63% 11000 39.4 143.96 22.56 95.33 1.25 0.5040937 0.785302 0.778 1014.19 17 .854 856.971 3466.206 10.485 503.301 2150.685 5616.89 4/23/00 1 :30 48 342.14 86.28 655.57 298.92 83.66 258.64 85.15 63% 11000 143.15 22.54 94.84 1.25 0.5034548 0.795833 0.776 982.46 16.003 768.154 3482.209 9.002 432.086 2159.687 5641.90 4/23/00 2:00 48 341.75 86.52 655.79 298.92 83.64 273.13 85.25 61% 11000 143.26 22.49 94.47 1.25 0.5032449 0.806366 0.776 1009,04 17.287 829.766 3499.496 11.052 530.506 2170.739 5670.23 4/23/00 2:30 48 341.36 86.57 655.64 299.11 83.61 271.78 85.22 62% 11000 143.08 22.46 94.29 1.250.5027424 0.816884 0.776 928.621 18.604 892.979 3518.100 11.402 547.309 2182.141 5700.24 4/23/00 3:00 48 344.06 86.68 655.6 301.43 83.58 278.93 84.97 63% 11000 144.64 22.66 94.33 1.25 0.5074481 0.827428 0.776 953.486 16.803 806.561 3534.903 9.869 473.695 2192.010 5726.91 4/23/00 3:30 48 346.38 86,63' 655.49 302.21 83.53 278.15 85.18 63% 11 000 145.19 22.75 94.6 1.25 0.5086507 0.838007 0.778 981.868 15.753 756.151 3550.656 9.252 444.089 2201.262 5751.92 4/23/00 4:00 48 348.3 86.53 655.46 298.92 83.58 278.73 85.01 63% 11000 146.69 23.05 94.87 1.25 0.5143479 0.848655 0.778 1001.43 17.854 856.971 3568,510 10.485 503.301 2211.747 5780.26 4/23/00 4:30 48 347.34 86.36 655.71 297.95 83.44 281.82 85.2 64% 12000 146.71 23.1 94.9 1.25 0.5149166 0.85936 0.778 1018,26 14.936 - 716.943 3583.446 8.402 403.281 2220.149 5803.59 Gas om Tolal Choke Well Head Annulus Gas ,Static Press Gas Gas Flow Incremental Water Incremental Total OR SIZe Press Well Head Press DSSFP ,DSSFT DSCP DSCT AP:t @ Press 1 nches Gas Temp Orifice MMSÇF T etal Gas Increase Barrel per' Produœd Increase Barrel per: 'Produced' Tìm!J' &. Date 641hs PSIG Temp iF} PSIG PSIG, (F) PSIG, (F) BS&W Chlonde 60F PSIG H2O (F) Size DAY MMSCF Gas SG GOO (bbI) D3Y (bbl) (bbI) Day (bhI) ' T olal Ruid 4/23/00 5:00 48 345.03 86.3 655.57 298.72 83.2 290.71 85.34 64% 12000 39.8 146.4 23.16 95.2 1.25 0.514864 0.870054 0.778 1042.77 18.137 870.574 3601.583 10.202 489.698 2230.351 5831.93 4/23/00 5:30 48 347.15 86.38 656.08 298.72 83.48 293.03 85.51 64% 12000 147.26 23.16 95.47 1.25 0.5161216 0.880769 0.778 1026.2 17.070 819.364 3618.653 9.602 460.892 2239.953 5858.61 4/23/00 6:00 48 344.06 86.44 655.83 303.76 83.55 299.21 85.53 63% 12000 147.12 23.28 95.55 1.25 0.5172904 0.891505 0.778 1048.96 17,854 856.971 3636.507 10.485 503.301 2250.438 5886.94 4/23/00 6:30 48 341.94 86.52 655.75 304.53 83.6 299.98 85.62 59% 12000 147.3 23.21 95.69 1.25 0.5167237 0.903666 0.778 1009.8 18.195 873.375 3654,702 12.644 606.921 2263.082 5917.78 4/23/00 7:00 48 341.94 86.65 655.94 297.17 84.02 301.53 85.8 60% 12000 147.5 23.24 95.73 1.25 0.5173122 0.914444 0.778 1008.95 17.504 840.168 3672.206 11.669 560.112 2274.751 5946.96 4/23/00 7:30 48 342.14 86.73 655.94 299.3 84 300.56 85.78 55% 12000 147.66 23.29 95.69 1.25 0.518188 0.925239 0.778 1014.21 15.128 726.145 3687,334 12.377 594.119 2287.129 5974.46 4/23/00 8:00 48 342.14 86.92 656.01 300.08 83.96 297.47 85.97 58% 12000 148.16 23.32 95.93 1.25 0.5191857 0.936056 0.778 1015.79 16.920 812.162 3704.254 12.252 588.118 2299.381 6003.63 4/23/00 8:30 48 345.03 86.96 655.75 304.53 84.05 302.68 85.93 60% 12000 148.95 23.42 95.99 1.25 0.5215611 0.946922 0.778 1018.94 17.003 816.163 3721.257 11.336 544.109 2310.717 6031.97 4/23/00 9:00 48 343.68 87.21 655.75 298.53 84.23 302.49 85.96 60% 12000 39.8 149.21 23.45 95.61 1.25 0.5225027 0.957807 0.778 1022.6 15.503 744.149 3736.760 10.335 496.099 2321.052 6057.81 4/23/00 9:30 48 345.99 86.94 655.68 307.25 84.37 301.33 85.99 57% 11000 39.1 149.61 23.48 95.8 1.25 0.5234599 0.968712 0.778 1022.98 17.579 843.769 3754.339 13.261 636.527 2334.313 6088.65 4/23/00 10:00 48 348.11 86.81 655.86 305.5 84.36 299.59 85.92 58% 11000 149.19 23.55 94.9 1.25 0.5240089 0.979643 0.778 1021.68 14.986 719.344 3769.325 10.852 520.904 2345.165 6114.49 4/23/00 10:30 48 347.15 86.85 655.79 305.31 84.85 302.3 86.04 61% 11000 149.56 23.5 94.49 1.25 0.5242496 0.990565 0.778 1023,95 17.287 829.766 3786.612 11.052 530.506 2356.218 6142.83 4/23/00 11 :00 48 346.18 86.99 657.77 307.05 84.54 305.39 86.17 60% 11000 149.91 23.56 95.27 1.25 0.5250921 1.0015 0,778 972.759 18.004 864.173 3804.615 12.002 576.115 2368.220 6172.84 ) 4/23/00 11 :30 48 345.8 87.2 655.97 305.5 84.7 303.07 86.25 59% 11 000 150.39 23.65 95.42 1.25 0.5267377 1.01248 0.778 929.961 15.736 755.351 3820.352 10.936 524.905 2379.155 6199.51 4/23/00 12:00 48 345.8 87.02 655.86 306.66 84.73 299.98 86.2 65% 11000 149.9 23.63 95.8 1.25 0.5255603 1.02343 0.778 928.454 18.420 884.177 3838.772 9.919 476.095 2389.074 6227.85 4/23/00 12:30 48 342.71 87.4 655.97 310.15 84.79 306.74 86.35 59% 11000 39.1 150.03 23.64 94.57 1.25 0.5265318 1.0344 0.778 1090.75 16.228 778.956 3855,000 11.277 541.308 2400.351 6255.35 4/23/00 13:00 48 349.65 87.56 655.75 308.41 85.1 310.41 86.48 62% 11 000 36.4 151,09 23.71 94.5 1.25 0.5290524 1.04542 0.78 1095.8 17.053 818.564 3872.054 1 0.452 501.700 2410.803 6282.86 4/23/00 13:30 48 349.85 87.59 655.71 310.73 85.11 312.15 86.46 63% 11000 151.22 23.77 95.87 1.25 0.5286409 1.05642 0.78 1099.52 17.328 831.766 3889.382 10.177 488.498 2420.980 6310.36 4/23/00 14:00 48 351.39 87.48 655.71 311.51 85.12 312.92 86.38 61% 11000 156.86 22,22 95.55 1.25 0.5200952 1.06726 0.78 1080.23 19.321 927.385 3908.703 12.352 592.919 2433,333 6342.04 4/23/00 14:30 48 351.58 87.44 655.42 313.25 84.97 312.73 86.21 60% 11000 159.84 21.55 93.93 1.25 0.5175848 1.07804 0.78 1086.78 15.503 744.149 3924.206 10.335 496.099 2443.668 6367.87 4/23/00 1 5:00 48 356.21 87.39 656.19 312.09 84.96 310.99 86.11 57% 11000 144.86 26.58 95.87 1.25 0.5479429 1.08946 0.78 1157.59 16.628 798.160 3940.834 12.544 602.120 2456.213 6397.05 4/23/00 15:30 48 348.88 87.58 656.49 305.31 84.96 308.67 86.42 60% 11000 137.48 28.32 96.25 1.25 0.5517773 1.10095 0.78 935.621 17.003 816.163 3957.838 11.336 544.109 2467.548 6425.39 4/23/00 16:00 48 351.39 88.01 656.3 310.15 85.47 312.92 86.74 60% 11000 134.04 33.38 95.55 1.25 0.5925048 1.1133 0.78 1051.88 16.003 768.1 54 3973.841 10.669 512.102 2478.217 6452.06 4/23/00 16:30 48 348.69 88.04 656.45 307.05 85.53 307.13 86.9 60% 11000 36.4 126.52 31.77 95.49 1.25 0,5629209 1.12503 0.78 998.898 19.004 912.182 3992.845 12.669 608.122 2490.886 6483.73 4/23/00 .17:00 48 352.74 88.01 655.6 307.44 85.56 303.26 86.91 60% 11 000 35.7 125.85 32.6 95.39 1.25 0.5689269 1.13647 0.78 1003.69 17.504 840.168 4010.348 11.669 560.112 2502.555 6512.90 4/23/00 17:30 48 352.74 88.11 657 308.41 85.68 303.65 86.96 62% 11000 124.95 32.55 95.23 1.25 0.5645896 1.14823 0.786 997.098 17.053 818.564 4027.402 10.452 501.700 2513.007 6540.41 4/23/00 18:00 48 352.16 88.23 657.04 307.44 85.62 302.3 87.07 59% 11000 124.72 31.73 94.93 1.25 0.55707 1.1566 0.786 1 043.15 15.736 755.351 4043.138 10.936 524.905 2523.943 6567.08 4/23/00 18:30 48 350.81 88.38 657.96 307.44 85.59 300.75 87.12 62% 11 000 126.53 32.16 95.54 1.25 0.564229 1.16864 0.786 1066.3 22.738 1091.418 4065.876 13.936 668.934 2537.879 6603.75 4/23/00 19:00 48 349.07 88.48 658.03 304.53 85.52 299.59 87.29 63% 11 000 114.78 40.6 95.49 1.25 0.6066964 1.18093 0.786 1104.87 12.603 604.921 4078.478 7.401 355.271 2545.280 6623.76 4/23/00 19:30 48 348.11 88.72 657.48 300.46 85.47 299.21 87.49 63% 11000 112.12 39.59 95.61 1.25 0.5926358 1.19335 0.786 1122.89 18.137 870.574 4096.615 10.202 489.698 2555.482 6652.10 4/23/00 20:00 48 352.54 88.81 657.26 296.98 85.54 294.19 87.31. 66"10 11000 109.31 42.48 95.64 1.25 0.6069904 1.20588 0.786 1185.89 19.804 950.590 4116.419 10.202 489.698 2565.684 6682.10 4/23/00 20:30 48 350.23 88.75 656.96 299.88 85.67 291.67 87.28 67% 11000 107.04 44.73 95.64 1,25 0.6171159 1.21858 0.786 1250.08 23.455 1125.825 4139.874 11.552 554.511 2577 .237 6717.11 4/23/0021:00 48 350.81 88.72 657.11 296.59 85.35 294.77 87.29 65% 9000 39 1 07.56 42.74 95.87 1.25 0,6043226 1.23127 0.786 1283.24 16.253 780.1 56 41 56.127 8.752 420.084 2585.988 6742.12 4/23/0021:30 48 350.42 88.71 656.49 295.04 85.46 294.19 87.31 65% 9000 107.35 44.11 95.95 1.25 0.6149406 1.24404 0.782 1204.63 19.954 957.792 4176.081 11.719 562;512 2597.707 6773.79 4/23/00 22:00 48 349.07 88.65 657.26 293.49 85.38 293.03 87.29 65% 9000 107.17 43.96 96.28 1.25 0.6132244 1.2567 0.782 1171.27 17.337 832.166 4193.418 9.335 448.090 2607.043 6800.46 4/23/00 22:30 48 342.71 88.57 656.74 293.1 85.1 294.57 87.11 65% 9000 113.21 42.05 96.56 1.25 0.6145255 1.26925 0.782 1257.02 19.504 936.1 87 4212.922 10.502 504.101 2617.545 6830.47 4/23/00 23:00 48 350.81 88.56 656.6 294.46 85.05 289.74 87.08 62% 9000 113.21 42.29 96,77 1.25 0.6161462 1.28184 0.782 1245.6 16.537 793.759 4229.459 10.135 486.497 2627.680 6857.14 4/23/00 23:30 48 354.86 88.42 656.56 289.23 84.83 292.25 86.95 65% 9000 39 114.89 40.82 97 1.25 0.6091722 1.29447 0.782 1131.54 21.671 1040.208 4251.130 11.669 560.112 2639.349 6890.48 4/24/00 0:00 48 350.23 88.33 656.41 291.36 84.76 290.13 86.64 64% 9000 116.95 40.3 96.94 1.25 0.6102214 1 .30703 0.782 1146.62 17.07008 819.36384 4268.200 9.60192 460.89216 2648.951 6917.15 4/24/00 0:30 48 349.65 88.29 656.27 291.55 84.75 287.43 86.89, 64% 9000 39 119.02 39.62 96.78 1.25 0.6099828 1.31961 0.782 1204.54 20.27072 972.99456 4288.470 11.40228 547;30944 2660,353 6948.82 4/24/00 1:00 48 349.46 88.25 656.41 289.81 84.7 290.32 86.79 63% 10500 37.7 119.12 37.73 96.7 1.25 0.595447 1.3322 0.782 1165.24 16.80336 806.56128 4305.274 9.86864 473.69472 2670.222 6975.50 4/24/00 1 :30 48 346.38 88.13 656.27, 291.55 84.55 293.8 86.78 64% 10500 118.81 38.69 96.53 1,25 0.6023865- 1.34481 0.782 1156.39 18.13696 870.57408 4323.411 10.20204 489.69792 2680.424 7003.83 4/24/00 2:00 48 350,81 88.26 656.16 290 84.58 293.99 86.72 63% 10500 119.17 36.37 96.22 1.25 0.585005 1.35743 0.782 1142.78 17.85357 856.97136 4341,264 10.48543 503.30064 2690.909 7032.17 4/24/00 2:30 48 353.32 88.04 657.37 292.33 84,37 294.19 86.5 61% 10500 120.75 38.77 96.04 1.25 0.6077433 1.37007 0.782 1168.81 16.26992 780.95616 4357.534, 10.40208 499.29984 2701.312 7058.85 4/24/00 3:00 48 352.35 88.35 655.83 284.77 84.44 290.52 86.57 64% 10500 118.89 38.86 95.95 1.25 0.6042503 1.38272 0.782 1098.66 18.13696 870.57408 4375.671 10.20204 489.69792 2711.514 7087.18 4/24/00 3:30 48 351.97 88.26 655.75 282.25 84.47 292.83 86.6 65% 10500 118.19 40.23 96.03 1.25 0.6138723 1.39544 0.78 1105.96 18.42035 884,1768 4394.092 9.91865 476.0952 2721.432 7115.52 4/24/00 4:00 48 352.35 88.19 655.6 287.87 84.41 291.48 86.5 64% 10500 117.79 39.8 96.15 1.25 0,6095794 1.40819 0.78 1264.88 20.27072 972.99456 4414.362 11.40228 547.30944 2732.835 7147.20 4/24/00 4:30 48 351.2 88,03 655.64 285.16 84.31 287.43 86.49' 64% 10500 118.09 39.68 94.95 1.25 0.6101226 1.42095 0.78 1219.85 20.27072 972.99456 4434.633 11 .40228 547.30944 2744.237 7178.87 4/24/00 5:00 48 353,12 88.13 655,42 286.13 84.36 291.1 86.4 65% 10000 38.3 118.44 40.03 95.66 1.25 0.6132171 1.43371 0.772 1209.56 16.25325 780.156 4450.886 8.75175 420.084 2752.989 7203.87 4/24/00 5:30 48 351.2 88.01 655.38 284.39 84.25 287.43 86.34 64% 10000 120.77 35.63 95.85 1.25 0.5863527 1.44655 0.772 1163 20.27072 972.99456 4471.157 11 .40228 547.30944 2764.391 7235.55 Gas Diff T otaf Choke Well Head Annulus Gas Static Press Gas Gas Flow Incrementaf Water Incremental Total Oil Size Press Well Head Press DSSFP DSSFT DSCP DSCT API@ Press Inches Gas Temp Orifice MMSCF T otaf Gas Increase Barrel per Produced Increase Barrel per Produced Time & Date 64ths PSIG Temp (F) PSIG PSIG (F) PSIG (F) BS&W Chloride 60F PSIG H2O (F) Size DAY MMSCF Gas SG GOR (bbl) Day (bbl) (bbl) Day (bbl) Total Ruld 4/24/00 6:00 48 351.77 87.99 655.49 294.85 84.23 288.39 86.33 65% 10000 117.74 40.91 96.08 1.25 0.621072 1.45941 0.772 1198.83 17.3368 832.1664 4488.494 9.3352 448.0896 2773.726 7262.22 4/24/006:30 48 351.2 88.12 654.69 285.94 84.32 286.85 86.39 62% 10000 118.17 40.78 96.48 1.25 0.6208935 1.47699 0.772 1266.56 19.95399 957.79152 4508.448 11.71901 562.51248 2785.445 7293.89 4/24/00 7:00 48 352.16 88.09 655.64 294.46 84.33 287.81 86.38 60% 10000 118.83 40.5 96.36 1.25 0.6203537 1.48992 0.772 1161.65 16.0032 768.1536 4524.451 10.6688 512.1024 2796.114 7320.56 4/24/00 7:30 48 350.81 88.03 655.79 288.45 84.29 290.9 86.28 65% 10000 118.75 40.46 96.24 1.25 0.6199671 1.50283 0.772 1103.91 17,878575 858.1716 4542.330 9.626925 462.0924 2805.741 7348.07 4/24/008:00 48 349.46 88.14 655.9 284 84.33 293.8 86.34 66% 10000 119.15 40.44 95.79 1.25 0.6210087 1.51577 0.772 1267.52 18.70374 897.77952 4561.033 9.63526 462.49248 2815.376 7376.41 4/24/00 8:30 48 350.62 88,06 656.63 289.62 84.34 290.52 86.32 65% 10000 119.82 40.46 96.03 1.25 0.6226359 1.52874 0.772 1306.27 20.58745 988.1976 4581.621 11.08555 532.1064 2826.462 7408.08 4/24/00 9:00 48 353.12 88.13 654.61 287.68 84.52 295.15 86.33 63% 10000 36.8 118.63 41.56 95.93 1.25 0.622843 1.54172 0.786 1268.46 16.80336 806.56128 4598.424 9.86864 473.69472 2836.330 7434.75 4/24/00 9:30 48 351.2 88.14 655.71 291.75 84.75 288.97 86.27 64% 10000 118.17 41.85 96.29 1.25 0.6236784 1.55471 0.786 1267.84 19.73728 947.38944 4618.161 11.10222 532.90656 2847.432 7465.59 4/24/00 10:00 48 352.35 88.33 655.97 292.33 84.72 289.36 86.33 65% 10000 118.08 42.25 96.81 1.25 0.626158 1.56776 0.786 1240.8 18.42035 884.1768 4636.582 9.91865 476.0952 2857.351 7493.93 4/24/00 10:30 48 349.27 88.36 655.71 290 84.92 289.94 86.42 65% 10000 116.02 43.31 97.3 1.25 0.6286607 1.58085 0.786 1251.56 18.962125 910.182 4655.544 10.210375 490.098 2867.561 7523.11 4/24/00 11 :00 48 350.42 88.32 655.97 297.95 85.02 291.48 86.25 68% 10000 116.88 43.23 97.61 1.25 0.6299871 1.59398 0.786 1246.99 18.13696 870.57408 4673.681 8.53504 409.68192 2876.096 7549.78 4/24/00 11 :30 48 350.23 88.23 656.05 299.11 85.05 288.2 86.05 67% 10000 117.18 41.89 97.33 1.25 0.6209631 1.60691 0.786 1380.64 21.779 1045.409 4695.460 10.727145 514.90296 2886.824 7582.28 4/24/00 12:00 48 352.35 88.05 656.23 298.72 85.05 294.19 86.04 65% 10000 118.69 42.34 96.98 1.25 0.6281828 1.62011 0.786 1403.81 16.795025 806.1612 4712.255 9.043475 434.0868 2895.867 7608.12 ) 4/24/0012:30 48 351. 77 88.53 656.45 297.17 85.02 286.65 86.05 62% 10000 36.8 119.6 41.94 96,76 1.25 0.6274928 1.63318 0.786 1401.08 18.60372 892,97856 4730.859 11.40228 547.30944 2907.269 7638.13 4/24/00 13:00 48 353.89 88.35 656.67 298.92 85.18 296.5 86.3 65% 10000 33,8 119.11 42.4 97.01 1.25 0.6295838 1.64629 0.786 1183.41 19.5039 936.1872 4750.363 10.5021 504.1008 2917.771 7668.13 4/24/00 13:30 48 351.2 88.29 656.93 297.75 85.16 289.36 86.17 63% 10000 118,29 42.36 97.77 1.25 0.6268509 1.65935 0.786 1181.91 17.85357 856.97136 4768.216 10.48543 503.30064 2928.257 7696.47 4/24/00 14:00 48 352.74 88.27 657.07 301.63 85.08 286.07 85.96 63% 10000 121.39 51.4 97.57 1.25 0.699109 1.67392 0.786 1322.01 17.85357 856.97136 4786.070 10.48543 503.30064 2938.742 7724.81 4/24/00 14:30 48 367.58 86.23 582.32 310.73 83.02 302.49 83.91 63% 10000 189.7 45.66 96.86 1.25 0.8127809 1.69085 0.786 1628.52 16.80336 806.56128 4802.873 9.86864 473.69472 2948.611 7751.48 4/24/00 15:00 48 404.39 85.83 453.84 366.91 82.66 376.47 83.88 63% 10000 33.8 112.17 8.04 98.13 1.25 0.2663115 1.6964 0.786 683.437 12.60252 604.92096 4815.476 7.40148 355.27104 2956.012 7771.49 Total Water Total Oil Produced Produced during 4013.330 2341.622 Report Interval during Report Interval ) HALLIBURTON FILL OUT SHEET COMPLETELY PLACE COpy IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER ... .:~ ';: YaV_",""^""'¥IoVI';'_____- SURFACE SAMPLE DATA SHEET Customer: Arco Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 1 Sample Bottle No: NANUK #2 K21626 IDENTIFICATION Sample Type: Sample Date: Time Start/Finish: Sample Point: Anerobic Oil 4/21/00 17:45/19:10 Oil Leg Seperator TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 142.52 Sample No.: 92.33 WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f): Gas SG: .756 Depth (ft. ): Gas Meter Run Pressure ( psi ):110 DatelTime: Gas Meter Run Temperature (f ):85 WHP (psi ): 241.71 Fpv (supercompressability factor): WHT (f): 85.06 Fb (basic orifice factor): Separator Pressure (psi): 142.52 Stock Tank Oil Flow Rate @ Std. Conditions ( bpd): Separator Temperature (f): 92.33 Corrected by (shrinkage or tank): CO2 (0/0): Shrinkage Factor Used (if applicable): H2S ( ppm ) Separator Oil Flow Rate ( bpd): BS&W (%) 70 Meter Factor Used: Oil API @ 6Of:29.5 Oil Line Temp (f ):88 Water Flow Rate @ Separator ( bpd ) Separator GaR ( use rates as per PE ): Stock Tank GaR ( use rates as per PE ): Choke Size @ Time of Sampling (64ths): Stabilization Time: 0.561506 0.967 142.52 92.33 348.53 1 35.3@60F 91.95 1102 1611.09 48 Sample Taken By: Remarks: Tony Soares Page 1 ) HALLIBURTON FILL OUT SHEET COMPLETELY PLACE COpy IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER WELL TESTIPRODUCTIONCONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: .756 ' Depth (ft. ): Gas Meter Run Pressure ( psi ):110 Date/Time: Gas Meter Run Temperature (f ):85 WHP ( psi ): 246.34 Fpv (supercompressability factor): WHT (f): 85.29 Fb (basic orifice factor): Separator Pressure (psi): 127.03 Stock Tank Oil Flow Rate @ Std. Conditions (bpd): Separator Temperature (f): 94.35 Corrected by (shrinkage or tank): CO2 ( % ): Shrinkage Factor Used (if applicable): H2S ( ppm) Separator Oil Flow Rate (bpd): BS&W (%) 70 Meter Factor Used: Oil API @ 60f:29.5 Oilt-ine Temp {f ):88 Water Flow Rate @ ~ Separator ( bpd ) Separator GOR ( use ratesä~ per PE ): Stock Tank GOR ( use rates as per PE ): Choke Size @ Time of Sampling ( 64ths): Stabilization Time: . ":'..:..:NN.~~___------ SURFACE SAMPLE DATA SHEET Customer: Arco Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 1 Sample Bottle No: ID ENTIFICA TION Sample Type: Sample Date: Time StarVFinish: Sample Point: Sep. Liq. Press. Sample 4/21/00 21 :42/22:23 Oil Leg Seperator TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 127.03 Sample No.: 90.66 40 min Sample Taken By: Remarks: Tony Soares NANUK #2 262507D 1000cc Core Lab 1000 cc 800 cc 200cc Zero 125.62 90.23 0.67073 0.852 127.03 94.35 360.26 1 35.3@60F 90.66 1059 1861 48 WELL TESTIPRODUCTIONCONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: .756 . Depth (ft. ): Gas Meter Run Pressure (psi ):110 Date/Time: Gas Meter Run Temperature (f ):85 WH P ( psi ): 228.22 Fpv (supercompressability factor): WHT (f): 84.98 Fb ( basic orifice factor): Separator Pressure (psi ): 122.17 Stock Tank Oil Flow Rate @ Std. Conditions ( bpd): Separator Temperature (f ):93.46 Corrected by (shrinkage or tank): CO2 ( % ): Shrinkage Factor Used (if applicable): H2S (ppm) Separator Oil Flow Rate (bpd): BS&W (0/0) 62 Meter Factor Used: Oil API @ 60f:29.5 Oil tine Temp (f ):88 Water Flow R~te @ ~ Separator ( bpd ) Separator GaR ( use ratesä~ per PE ): Stock Tank GaR ( use rates as per PE ): Choke Size @ Time of Sampling (64ths): Stabilization Time: . ) «:)iiAITiUÜRTON SURFACE SAMPLE DATA SHEET Customer: Arco Alaska, Inc. Well No. Test: #1 Lease: Field: Peris: Sample No. 2 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time Start/Finish: Sample Point: Sep. Liq. Press. Sample 4/21/00 22:55/23:30 Oil Leg Seperator TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMP ANION SAMPLES 122.17 Sample No.: 90.87 35 min Sample Taken By: Remarks: Tony Soares NANUK #2 2625450 1000cc Core Lab 1000 cc 900 cc 100 cc Zero 128.11 92.41 0.644112 0.852 122.17 93.46 334.43 1 35.3@60F 90.87 1191 1926 48 ) ) O-¡::ìAUIB URTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 1 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time Start/Finish: Sample Point: Gas 4/22/00 09:40/09:50 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 125.91 Sample No.: 95.37 Cylinder No.: 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT (f): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi ): Date/Time: Gas Meter Run Temperature ( f): WHP ( psi ): 319.01 Fpv (supercompressability factor): WHT (f): 86.13 Fb ( basic orifice factor): Separator Pressure (psi ): 125.91 Stock Tank Oil Flow Hate @ Std. Conditions Separator Temperature (f): 95.37 Corrected by (shrinkage or tank): CO2 (0/0): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W ( 0/0) 65 Meter Factor Used: Oil API @ 6Ot: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GOR ( use rates as per PE ): Stock Tank GOR ( use rates as per PE ): Choke Size @ Time of Sampling ( 64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 2 thru 11 NANUK #2 349859D Gas 126.14 95.23 0.487345 0.774 125.91 95.37 1 314.95 604 539 39.5 99.2 896 903 48 ') ".'~~';:"J!A:V""",~-~..- FILL OUT SHEET COMPLETELY PLACE COpy IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER HALLIBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Peñs: Sample No. 2 Sample Bottle No: IDENTIFICATION Sample Type: Sample Date: Time Start/Finish: Sample Point: Gas 4/22/00 10:00/10:10 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 126.14 Sample No.: 95.23 Cylinder No.: 2 thru 11 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT (f): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi ): Date/Time: Gas Meter Run Temperature (f): WHP ( psi ): 325 Fpv (supercompressability factor): WHT (f): 86.38 Fb ( basic orifice factor): Separator Pressure (psi ): 126.14 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 95.23 Corrected by (shrinkage or tank): CO2 (°10): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W ( °10) 65 Meter Factor Used: Oil API @ Got: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GOR ( use rates as per PE ): Stock Tank GOR ( use rates as per PE ): Choke Size @ Time of Sampling (64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 NANUK #2 193436D Gas 125.92 95.72 0.487734 0.774 126.14 95.23 1 314.95 512 539 39.5 98.56 896 904 48 ) ) tJ)HAiIïBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: .Sample No. 3 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time StarVFinish: Sample Point: TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: Gas 4/22/00 10:20/10:30 Gas Outlet bf Daniels SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 126.14 Sample No.: 95.23 Cylinder No.: 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: Depth (ft. ): Gas Meter Hun Pressure ( psi ): Date/Time: Gas Meter Run Temperature (f): WHP (psi): 328.26 Fpv (supercompressability factor): WHT (f): 86.47 Fb (basic orifice factor): Separator Pressure (psi): 126.28 Stock Tank Oil FlowRate @ Std. Conditions Separator Temperature (f): 95.12 Corrected by (shrinkage or tank): CO2 ( % ): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W ( % ) 60 Meter Factor Used: Oil API @ 6ot: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GaR ( use rates as per PE ): Stock Tank GaR ( use rates as per PE ): Choke Size @ Time of Sampling ( 64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 2 thru 11 NANUK #2 193436D Gas 126.23 95.73 0.487632 0.774 126.28 95.12 1 314.95 528 566 39.5 98.02 865.1 860 48 ) ) OHALLïBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 4 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COpy IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time StarVFinish: Sample Point: Gas 4/22/00 . 10:40/10:50 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 126.23 Sample No.: 95.73 Cylinder No.: 2 thru 11 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP ( psi ): Gas Flow Rate @ Std. Conditions (mmscfd): BHT (f): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi ): Date/Time: Gas Meter Run Temperature (f): WHP (psi): 335.2 Fpv (supercompressability factor): WHT (f): 86.56 Fb (basic orifice factor): Separator Pressure (psi): 126.23 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 95.73 Corrected by (shrinkage or tank): CO2 ( % ): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W ( % ) 65 Meter Factor Used: Oil API @ 6Ot: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GOR ( use rates as per PE): Stock Tank GOR ( use rates as per PE ): Choke Size @ Time of Sampling ( 64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 NANUK #2 193507D Gas 126.99 95.09 0.486978 0.774 126.23 95.73 1 314.95 518 565 39.5 99.94 863 861 48 ) ". .::.;: VN.Y'JVYV'J\"""""'--...... FILL OUT SHEET COMPLETELY PLACE COpy IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER HALLIBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 5 Sample Bottle No: IDENTIFICATION Sample Type: Sample Date: Time Start/Finish: Sample Point: Gas 4/22/00 10:50/11 :00 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 126.99 Sample No.: 95.09 Cylinder No.: 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi ): Date/Time: Gas Meter Run Temperature (f): WHP (psi): 332 Fpv (supercompressability factor): WHT (f): 87 Fb (basic orifice factor): Separator Pressure (psi ): 126.99 Stock Tank Oil FlowRate @ Std. Conditions Separator Temperature (f): 95.09 Corrected by (shrinkage or tank): CO2 (%): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W ( % ) 65 Meter Factor Used: Oil API @ 6Ot: Oil Line Temp (f ): Water Flow Rate @ Separator ( bpd ) Separator GOR ( use rates as per PE ): Stock Tank GOR (use rates as per PE): Choke Size @ Time of Sampling ( 64ths): Stabilization Time: Sample Taken By: Remarks: Doug Scott Page 1 2 th ru 11 NANUK #2 11EK095 Gas 127.08 95.7 0.489181 0.774 126.99 95.09 1 314.95 518 566 39.5 98 864 864 48 ) ) GHAiliBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 6 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time StarVFinish: Sample Point: Gas 4/22/00 11 :25/11 :35 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 126.99 Sample No.: 95.09 Cylinder No.: 2 thru 11 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f): Gas SG: Depth (ft. ): Gas Meter Run Pressure (psi): Date/Time: Gas Meter Run Temperature (f): WHP ( psi): 332 Fpv (supercompressability factor): WHT (f): 87 Fb (basic orifice factor): Separator Pressure (psi): 126.99 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 95.09 Corrected by (shrinkage or tank): CO2 (%): 0.2 Shrinkage Factor Used (if applicable): H2S ( ppm ) 0 Separator Oil Flow Rate ( bpd): BS&W (%) 65 Meter Factor Used: Oil API @ 60f: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GOR ( use rates as per PE ): Stock Tank GOR ( use rates as per PE ): Choke Size @ Time of Sampling ( 64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 NANUK #2 02EK095 Gas 127.08 95.7 0.489181 0.774 126.99 95.09 1 314.95 518 566 39.5 98 864 864 48 ".':;';:~~"it^"""",''''''YII''IL__w.... FILL OUT SHEET COMPLETELY PLACE COpy IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER HALLIBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 7 Sample Bottle No: IDENTIFICATION Sample Type: Sample Date: Time StarVFinish: Sample Point: Gas 4/22/00 11:15/11:25 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 127.08 Sample No.: 95.7 Cylinder No.: 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP ( psi ): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi ): Date/Time: Gas Meter Run Temperature (f): WHP ( psi ): 331 Fpv (supercompressability factor): WHT ( f ): 86.5 Fb ( basic orifice factor): Separator Pressure (psi): 127.08 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 95.7 Corrected by (shrinkage or tank): CO2 (%): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W (0/0) 60 Meter Factor Used: Oil API @ 6ot: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GOR ( use rates as per PE): Stock Tank GOR (use rates as per PE): Choke Size @ Time of Sampling (64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 2 thru 11 NANUK #2 01 EK096 Gas 127.35 95.37 0.489028 0.774 127.08 95.7 1 314.95 560 564 39.5 99.5 863 865 48 ) C)HAUiBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 8 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time Start/Finish: Sample Point: Gas 4/22/00 11 :25/11 :35 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 127.35 Sample No.: 95.37 Cylinder No.: 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP ( psi ): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi ): Date/Time: Gas Meter Run Temperature (f): WHP (psi): 332 Fpv (supercompressability factor): WHT (f): 86.4 Fb (basic orifice factor): Separator Pressure (psi): 127.35 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 95.37 Corrected by (shrinkage or tank): CO2 ( % ): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W (%) 60 Meter Factor Used: Oil API @ 6Ot: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GaR ( use rates as per PE ): Stock Tank GaR ( use rates as per PE ): Choke Size @ Time of Sampling (64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 2 th ru 11 NANUK #2 03EK098 Gas 128 95.5 0.489778 0.774 127.35 95.37 1 314.95 560 562 39.5 98.45 861 867 48 ) ". ':;';:I..¡¡AH!Þ'''M'Y\'''''V¥fI'II-_~..-- FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER HALLIBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 9 Sample Bottle No: IDENTIFICATION Sample Type: Sample Date: Time StarVFinish: Sample Point: TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: Gas 4/22/00 12:10/12:20 Gas Outlet bf Daniels SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 128.3 Sample No.: 95 Cylinder No.: 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP ( psi ): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi): Date/Time: Gas Meter Run Temperature (f): WHP (psi ): 333.5 Fpv (supercompressability factor): WHT (f): 86.4 Fb ( basic orifice factor): Separator Pressure (psi): 128.3 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 95 Corrected by (shrinkage or tank): CO2 ( % ): 0.2 Shrinkage Factor Used (if applicable): H2S (ppm) 0 Separator Oil Flow Rate (bpd): BS&W ( %) ) 62 Meter Factor Used: Oil API @ 6ot: Oil Line Temp (f ): Water Flow Rate @ Separator ( bpd ) Separator GaR ( use rates as per PE): Stock Tank GaR ( use rates as per PE ): Choke Size @ Time of Sampling ( 64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 2 thru 11 NANUK #2 758102A Gas 128 95.7 0.491753 0.778 128.3 95 1 314.95 547 562 39.5 98 859 874 48 ) OHÃilIBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 10 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time Start/Finish: Sample Point: Gas 4/22/00 12:20/12:30 Gas Outlet bf Daniels TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 128 Sample No.: 98.7 Cylinder No.: 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP (psi): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f ): Gas SG: Depth (ft. ): Gas Meter Run Pressure ( psi): Date/Time: Gas Meter Run Temperature ( f): WHP (psi): 332 Fpv (supercompressability factor): WHT (f): 86.3 Fb (basic orifice factor): Separator Pressure (psi): 128 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 98.7 Corrected by (shrinkage or tank): CO2 ( % ): 0.2 Shrinkage Factor Used (if applicable): H2S ( ppm ) 0 Separator Oil Flow Rate ( bpd): BS&W (0/0) 62 Meter Factor Used: Oil API @ eOf: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GOR ( use rates as per PE ): Stock Tank GOR ( use rates as per PE ): Choke Size @ Time of Sampling (64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 2 th ru 11 NANUK #2 257970D Gas 128 95 0.489287 0.778 128 98.7 1 314.95 547 562 39.5 99.5 859 870 48 ) OìiAliIBURTON SURFACE SAMPLE DATA SHEET Customer: ARCO Alaska, Inc. Well No. Test: #1 Lease: Field: Perfs: Sample No. 11 Sample Bottle No: FILL OUT SHEET COMPLETELY PLACE COPY IN PLASTIC BAG AND ATTACH TO SAMPLE CONTAINER IDENTIFICATION Sample Type: Sample Date: Time StarVFinish: Sample Point: TRANSPORTATION CONDITIONS Sample Bottle Type: Bottle Volume: Sample Volume: Volume H2O Removed From Gas Cap: Volume H2O Left in Bottle: Ending Pressure: Ending Temperature: Gas 4/22/00 12:35/12:45 Gas Outlet bf Daniels SAMPLING CONDITIONS Sampling Pressure: Sampling Temperature: Sampling Method: Duration: COMPANION SAMPLES 128 Sample No.: 95 Cylinder No.: 2 thru 11 10 min WELL TESTIPRODUCTION CONDITIONS DURING SAMPLING BHP ( psi ): Gas Flow Rate @ Std. Conditions (mmscfd): BHT ( f): Gas SG: Depth (ft. ): Gas Meter Run Pressure (psi): Date/Time: Gas Meter Run Temperature (f): WHP ( psi): 335 Fpv (supercompressability factor): WHT ( f ): 86.3 Fb ( basic orifice factor): Separator Pressure (psi ): 128 Stock Tank Oil Flow Rate @ Std. Conditions Separator Temperature (f): 95 Corrected by (shrinkage or tank): CO2 ( % ): 0.2 Shrinkage Factor Used (if applicable): H2S ( ppm) 0 Separator Oil Flow Rate (bpd): BS&W ( % ) 62 Meter Factor Used: Oil API @ 6Ot: Oil Line Temp (f): Water Flow Rate @ Separator ( bpd ) Separator GaR ( use rates as per PE ): Stock Tank GaR ( use rates as per PE ): Choke Size @ Time of Sampling (64ths): Stabilization Time: Sample Taken By: Doug Scott Remarks: Page 1 NANUK #2 72A1289 Gas 128 95 0.490188 0.778 128 95 1 314.95 547 563 39.5 98 861 563 48 Permit to Drill No. MD 9112 2000300 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. NANUK 2 Operator PHILLIPS ALASKA INC. AP1 No. 50-103-20332-00-00 Name TVD 8241 Completion Date 5/7/2000 Completion Status P&A Interval Start Stop Sent Received Cuttings Core Chips 108 9112 Current Status P&A Dataset Number Comments UIC N 1040~,,'~ ~o4o ~ ADDITIONAL INFORMATION Well Cored? (~/N Chips Received? ~N Analysis Received? ~/N Daily History Received? Formation Tops Receuived? Comments: Compliance Reviewed By: Date: Permit to Drill No. DATA SUBMITTAL COMPLIANCE PORT 5/13/2002 2000300 Well Name/No. NANUK 2 Operator PHILLIPS ALASKA INC. AP1 No. 50-103-20332-00-00 MD 9112 TVD 8241 Completion Date 5/7/2000 / Completion Status P&A ~--~'- Current Status P&~' Lc., UIC N REQUIRED INFORMATION Mud Log ~ '~1'~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Ttpe Media Format D T C T C C C C Name R '-..-D~SRVY× L ,.~X-DT/CNP)~ L ~)~R4-~ L USITe-~~ L L C~~NP/SLD-MD L ~SCTA L~-AIT~CFL~ L ~~ L ~OD PACKER L~ ~ L L~SI ~ ~CNP/SLD-~D ~Vell Cores/Samples Information: Samples Directional Survey (data taken from Logs Portion of Master Well Data Maint) Log Log Scale Media Interval Run OH / No Start Stop CH Received Dataset Number Comments 5 25 25 5 5 25 2 5 5 5 2 25 2 25 FINAL 4720 8386 0 9112 FINAL 2217 9030 FINAL 118 8190 FINAL 2200 8000 4800 8320 FINAL 4761 8930 FINAL 2219 9112 FINAL 4796 8930 FINAL 2217 9040 FINAL 7050 7200 FINAL 2000 6772 ~. 4800 8020 ~4NAL~d I 5500 9030 FINAL 2000 8990 FINAL 2058 8190 108 9112 FINAL 108 9112 OH OH OH OH O CH OH OH OH OH O OH CH CH OH OH OH OH OH OH 6/1/2000 8~3~2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 6/1/2000 5/4/2000 6/1/2000 SPERRY. 09644 ~ 51-9059 BL(C) 09643 ~2217-9030 EPOCH BL(C) DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND (;AS May 30, 2002 Richard P. Mort, Vice President Exploration & Land Phillips Alaska, Inc. P.O, Box 100360 ~ Anchorage, Alaska 99501-0360 Approval of extended confidentiality Nanuk ~2 w/ill, C~ilgill~Ri~ei"Uhit ................. : ........... T.(' .... ~ KNOWLI~;, GO'VF. RNOfl RECEIVED Dear Mr. Mort: I am responding to your letter of March 22.2002, to Commissioner Pourchot in which you requeste~.t, on behalf of Phillips Alaska, Inc. (PA1) and the working interest owners, extended confidentiality under 11 AAC 83.153(a) for the Nanuk #2 well data, reports, and information filed with the Alaska Oil and Gas Conservation Commission (AOGCC). I understand that these data, reports and information are scheduled for public release on June 7, 2002. As you know, under 11 AAC 83.153(a) the Commissioner will grant extended confidentiality beyood the 24-month period set out in AS 31.05.035(c) to data, reports and inforrnatiori filed with the AOGCC if it can be shown that the data, reports and information contain significant informatio, n relating to the valuation of unleased land within a three-mile radius of the well. Following technical reviews and discussions with Phillips Alaska, Inc. staff on May 23 and 28,.2002, I find that the -'Niakuk ~2 Well'data, reports and information contain significant information relating to the evahmtion of unleased land within a three-mile radius of the Nanuk #2 well (Tract 0917). Accordingly 1 asking that the Alaska Oil and Gas Conservation Commission (AOGCC) extend the Nanuk #2 confidentiality term until 30 days after the 2002 Areawide North Slope Oil and Gas lease Sale now scheduled for October'23, 2002. By copy of this letter I am requesting that the AOGCC release the data, reports and information from ~he Nanuk #2 well, API #501032033200, on November 22, 2002. A person affected by this decision may appeal it in accordance withy 11 AAC 02. Any appeal must be received within 20 calendar days after the date of "issuance" Of this decision, as defined in ! 1 AAC 02.040 (c) and (d) and may be mailed or delivered to Pat Pourchot, Commissioner, Department of Natural Resources, $$0 West 7~h Avenue, Suite 1400, AnChorage, Alaska 99501; faxed to 1-90%269- 8918, or sent by electronic mail to dnr ~pp_¢als_@_dn_r,.state.,'tk.u.~.~. This decision takes effect "Dsvelop~ Conserve, and Enhance Natural Resources for Present and Future Alaskans." M~Y ~f~ '02 0~:18PM ST-~Ii ~ W~TER ~07 ~69 8D47 (' immediately, ff no appeal is filed by the appeal deadline, this decision becomes a final administrative order and decision of the department on the 31s~ day after issuance. An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court. A copy of 11 AAC 02 may be obtained from any regional information office of the Department of Natural Resources. Mark D. Myers Director Cci Daniel Seamount, Commissioner, AOGCC Cammy Taylor, Commissioner, AOGCC Jeff Landry, Department of Law .... lim_.C0Waa, DO&G PHILLIPS Alaska, inc. A Subsicfiary of PHILLIPS PETROLEUM COMPANY EXPLORATION & LAND P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 PHONE (907) 263-4556 FACSIMILE (907) 265-6339 Richard P. Mott Vice President March 22, 2002 Pat Pourchot, Commissioner State of Alaska Dep~ent of Natural Resources Division of Oil and Gas 550 West 7th Ave., Suite 1400 Anchorage, AK 99501-3510 Request for Extended Confidentiality Under 11 AAC 83.153(a) Nanuk #2 (API# 501032033200) Colville River Unit Pursuant to 11 AAC 83.153(a), Phillips Alaska, Inc, as operator for and on behalf of the working interest owners of the Nanuk #2 well data, hereby respectfully requests extended confidentiality for the Nanuk #2 well data, reports, and information filed with the Alaska Oil and Gas Conservation Commission as required by state law. Unleascd land is located within a three-mile radius of the Nanuk #2 well. A map of the well location and the unleased acreage is attached for your reference. If you have any questions, please do not hesitate to call me or Mr. Jim Winegamer at 265- 6914. Sincerely, Richard P. Mott Vice President Exploration and Land RPM:JPW RECEIVED APR 5 2002 Attachment Cc: Mark Myers, Department of Natural Resources, Division of Oil and Gas Teresa Imm, Arctic Slope Regional Corporation John Bridges, Anadarko Petroleum Corporation ~'e~mmy Taylor, Alaska Oil and Gas Conservation Commission ~ EXHIBIT"I" ~' ' .... Well Name: Nanuk #2 ,,~,s~,, (APl# 501032033200) Scale: 1" -- 3,000' 3-22-02 02012201A01 I' ~s l~c 22% ~ / ~ ~ x~'~E '- _/ ~~ ~ I , /~iON'R4E TIO~-R5E ~ 'k / / ~ ' ~/22/-~ ,' v I ~ .. ~ [ ( ADL3889~ .--'~- 52,~/ A~ '~ F i L l I, ,v,,~ ~ .... TRANSMITTAL TO: AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 OPERATOR: DATE: 10 APR 00 AIRBILL: NIA ABV#: ABV 00-04-10-04 CHARGE CODE#: N/A WELL: NANUK #2 SAMPLE TYPE: DRIES SAMPLES SENT: NUMBER OF BOXES: I Bundle (8boxes) NANUK #2 SURFACE-8850 SENT BY: Mike McCracken UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: Arco Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski ! PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, ATO1486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 Bob Crandall AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: Nanuq 2 DATE: 02/20/2001 Transmitted herewith is the following: Nanuq 2 501032033200 J D ROM Digital data: __ Core Labs Slabbed core UV and natural light core photos yS3.5' disk idewall and rotary core description and core chip descriptions Paper fi/es I//Nanuq 2 detailed core description graphic plot- by Dave Bannan 12/2000 i/Summary: RFT 1 and 2 for Nanuq 2 by Dave Bannan I/Core analysis results-Rotary sidewall core analysis with 3.5" disk of digital data tables- Core Labs 7/26/2.00/0 V Conventional Core Analysis, Core Labs, June 5, 2000 V/Epoch Well Services Final Well report-includes v"'l) color formation log - 108'-9112'; TVD 2"=100' v~.2) color formation log - 108-9112'; MD 2"-100' /3) Drilling dynamics log - 108'- MD 2"=100' please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) OO: Dave Bannan, Renee Hannon Approved for transmittal by: D. Bannan Return receipt to: Phillips Alaska, Inc. ATTN: $. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: C~--~O-O / Prepared by: Sandra D. Lemke Phillips Alaska Ti' Technical Databases 2CO-OBo ARCO ALASKA INC. NANUK NO. 2 FINAL WELL REPORT Section 25, TllN-R4E, UM North Slope Borough, Alaska EPOCH WELL SERVICES INC. Phillips Alaska, Inc. Internal Correspondence Date: Subject: From/Location: Telephone: To/Location: February 8, 2001 Summary: RFT 1 and 2 for Nanuk #2 David Bannan ATO 866 X4733 Files Enclosed is a summary of the fluids collected from two RFT runs in the Nanuk #2 well which was drilled in 2000. Pressure data was also collected in these sandstones as well as Albian age sandstone. The pressure data is listed in the Schlumberger log displays. All depths listed are measured depths determined by the wireline logging. Samples: 8309.2 Open 2 3/4 gal. For 1 hr 27 min, close @ 945 psig, get stuck. (Alpine) 620 psig @ surface. Recover 300 cc bottle of gas at pressure. Dump 2.6 ft3 gas and 8250 cc liquids, approx 750 cc oil. Lab Report Separated 600 mi oil, 40.2 deg APl. CI of 1655 ppm. 7964 Open 2 3/4 gal. For 1 minute, close @ 3226 psig. Mobility 367 md/cp. (Kuparuk) (Surface pressure registered 1350 psig?? Gauge suspect.) Dump 5.9 ft3 gas, 10000 cc liquid & foam (2200 cc oil & foam.) Filtrate very emulsified. Lab Report Separated 30 mi oil, 37.3 deg APl. Lots of sand. CI of 1655 ppm. 4802 (K-2) Open 1 gal. For 39 minutes, close @ 445 psig. Mobility 8 md/cp. 330 psig @ surface. Recover 300 cc bottle, though valves and fittings very oily. Dumped 0.1 ft3 gas, 2500 cc dark liquid. Lab Report Separated 100 mi oil, 27.3 deg APl. CI of 1655 ppm. CC: M. Ireland, PAl D. W. Masterson, PAl J. Zawila, PAl E. Reinbold, PAl ARCO ALASKA INC. NANUK NO. 2 FINAL WELL REPORT 108' to 9112' 3124100 to 4112100 Prepared By: JOHN MORRIS AND ARTEM RATCHKOVSKI EPOCH WELL SERVICES INC. Well Resume ARCO ALASKA, INC. NANUK NO. 2 WELL RESUME OPERATOR: WELL NAME: LOCATION: FIELD: COORDINATES: ELEVATIONS: COUNTY: STATE: APl INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE: CONTRACTOR: RIG NUMBER: RIG TYPE: MUD PUMPS: COMPANY GEOLOGISTS: COMPANY REPS: MUD COMPANY: MUD TYPES: CASING DATA: HOLE SIZE: MUDLOGGING SERVICES: TYPE UNIT: UNIT NUMBER: LOGGING GEOLOGISTS: SAMPLE TECNICIANS: LWD I MWD: ARCO ALASKA INC. NANUK NO. 2 SEC. 25, T11N-R4E, UM COLVILLE RIVER UNIT 465' FNL, 864' FEL 40' AMSL (KB) 12' AMSL (PAD) NORTH SLOPE BOROUGH ALASKA 50-103-20332-00 MARCH 24, 2000 9112' APRIL 1, 2000 DOYON DRILLING INC. 141 SCR DIESEL-ELECTRIC I LAND (2) EMSCO FB1600 MARK MYERS, DAVE BANNON MIKW WHITELEY, DARRAL GLADDEN BAROID DRILLING FLUIDS INC. SPUD MUD TO 2228' LSND MUD TO 9112' 9 $18" AT 2219' 12 114" TO 2228' 8 112" TO 9112' EPOCH WELL SERVICES INC. DML I RIGWATCH I FID GAS DETECTION MLOA1 (RIG ROOM INSTALLATION) JOHN MORRIS, ARTEM RATCHKOVSKI, MARK LINDLOFF ISAAC STOTTS, SCOTT HODGES SPERRY SUN Daily Activity Summary ARCO ALASKA INC. NANUK NO. 2 DAILY ACTIVITY 3~24~2000 HELD PRE SPUD SAFETY/OPERATIONS/COMPLIANCE MEETING WITH CREW AND SERVICE HANDS. SPILL DRILL. REVIEWED SHALLOW GAS HAZARD. MUD MOTOR FROZE UP, THAW OUT MOTOR, MAKE UP BIT AND RE-ORIENT TOOLS. FILL HOLE AND CHECK FOR LEAKS. DRILL FROM 108' TO 790'. BUILD MUD VOLUME. REPAIR CUTTING CONVEYOR IN ROCK WASHER. DRILL FROM 790' TO 1452' 3/25/2000 DRILL 12 %" SURFACE HOLE FROM 1452' TO 2228' TOTAL DEPTH. PUMP SWEEP AROUND, CIRCULATE CLEAN FOR SHORT TRIP, OBSERVE WELL. SHORT TRIP TO 400', NO PROBLEMS. PUMP SWEEP AROUND; CIRCULATE AND CONDITION MUD TO RUN CASING. DROPPED SURVEY, OBSERVED WELL, SLUG DRILL PIPE. POOH WITH DRILL PIPE, CHANGE OUT JARS, LAY DOWN BHA, CLEAR RIG FLOOR. RIG UP CASERS, PJSM. RUN 51 JOINTS 9 5/8" CASING TO 2200'. MAKE UP HANGER/LANDING JOINT, LANDED CASING, MAKE UP CEMENTING HEAD, BREAK CIRCULATION. CIRCULATE AND CONDITION MUD AND HOLE FOR CEMENT JOB. 3/26/2000 CIRCULATE AND CONDITION MUD AND HOLE FOR CEMENT JOB. RECIPROCATE PIPE. PJSM. PUMPED 25 BBL LCM/POLYMER PILL. SET AND CEMENTED 9 5/8" CASING - SHOE @2219'. DOWELL PUMPED 20 BBLS ARCO WASH, 50 BBLS SPACER AT 10.5 PPG, 398 SX LEAD AT 10.7 PPG, AND 350 SX TAIL AT 15.8 PPG. DISPLACE AT 8 BPM WITH RIG PUMPS. FULL RETURNS. STOPPED RECIPROCATING WITH 250 BBLS LEAD MIXED. FULL RETURNS THROUGHOUT JOB. PLUG BUMPED. FLOAT HELD. CIP @ 4:45 HRS. CIRCULATE 130 BBLS GOOD 10.7+ PPG CEMENT TO SURFACE. CEMENT STOOD AT SURFACE. RD CEMENTING HEAD. LD LANDING JT. LANDING JT. CLEAR RIG FLOOR- WASH OUT DIVERTER. NIPPLE UP 11" 5M SPLIT SPEED HEAD. 3/27/2000 PJSM. TEST 9 5/8" CASING TO 2500 PSI FOR 30 MIN. HELD. DRILL OUT PLUGS, FLOATS, GOOD CEMENT, AND DRILLED 20' NEW FORMATION TO 2248'. DISPLACED WELL WITH 9.6 PPG LSND MUD. RAN F.I.T. - EMW = 16.0 PPG. DRILLED 8.5" HOLE FROM 2248' TO 3635'. PUMP SWEEP AROUND. CIRCULATE CLEAN. OBSERVE WELL. SLUG DP. MADE SHORT TRIP TO 2219', OBSERVED WELL. RIH. NO PROBLEMS, HOLE IN GOOD SHAPE. DRILL FROM 3635' TO 3945~. 3/28/2000 DRILL FROM 3945' TO 5306'. PUMP SWEEP AROUND. CIRCULATE HOLE CLEAN. OBSERVE WELL. SLUG DP. MADE 17 STAND SHORT TRIP TO 3600'. NO PROBLEMS. HOLE IN GOOD SHAPE. DRILL FROM 5306' TO 5986'. PRE-RESERVOIR MEETING. KICK DRILL. 3/29/2000 DRILL FROM 5996' TO 6946'. PUMP SWEEP AROUND. CIRCULATE CLEAN. OBSERVE WELL. SLUG DP. START POOH FOR ROTARY BHA. HOLE IN GOOD SHAPE. 3/30/2000 FINISHED POOH WITH DP. HOLE IN GOOD SHAPE.. REMOVE RADIOACTIVE SOURCE AND DOWNLOAD LWD'S. LAY DOWN MOTOR,STAB, LWD. MAKE UP ROTARY BHA. CHANGE OUT DENSITY TOOL AND LOAD RADIOACTIVE SOURCE. RIH TO SHOE @ 2219'. CUT DRILLING LINE. ADJUST BRAKES. RIH TO 6900'. NO PROBLEMS. MAD PASS FROM 6900' TO 6946'. DRILL FROM 6946' TO CORE POINT AT 7071'. TOP FOR NANUK SAND AT 7051' MD, 6185' TVD. CIRCULATE FOR SAMPLES. MAX GAS 325 UNITS. CIRCULATE CLEAN. OBSERVE WELL. SLUG DP. POOH FOR CORE BARRELS. HOLE IN GOOD SHAPE. REMOVE RADIOACTIVE SOURCE. DOWNLOAD LWD'S. STAND BACK MWD/LWD'S PJSM. MAKE UP CORING BHA- 120' 6 %" OD BARRELS. SPACE OUT INNER BARRELS.RIH SLOW WITH CORE BARREL TO 7030' WASH TO BOTTOM. SPACE OUT. DROP BALL. CUT CORE #1 IN NANUK SAND FROM 7071 TO 7193. 3/31/2000 CORE FROM 7120' TO 7193'. FILLED CORE BARREL. CIRCULATE BOTTOMS UP FOR SAMPLES. OBSEVE WELL. POOH SLOW WITH CORE BARRELS. LAY DOWN INTER BARRELS - PULL UP AND CHECK CORE BIT. RECOVERED 120' CORE - FULL RECOVERY. LAY DOWN CORE BARRELS. MAKE UP BHA #5 - 8.5" PDC, 6 %" OD MACH 1CL: - AKO, 1.2 DEG., STAB, LWD'S, MWD. ORIENT TOOLS -LOAD RADIOACTIVE SOURCE. RIH TO 7052'. MAD PASS FROM 7060' TO 7193'. DRILL FROM 7193' TO 7905'. 4/1/2000 PJSM "FIRE HAZARDS", DRILL 7905' TO 9112' (T. D.). SWEEP HOLE, CIRCULATE CLEAN, OBSERVE WELL, PUMP DRY JOB. WIPE HOLE TO 2200', OBSERVE WELL. RIH. Rig Activity DALLY RIG ACTIVITY BREAKDOWN ARCO ALASKA, INC. NANUK NO. ~ II ACTIVITY AND HOURS o o w o o DATE DAY '"' MAR ~3.o ,~o~ .................. 2000 24 1 1,452 1344 16.0 0.5 6.5 1.0 24.0 25 2 2,228i 7?$ 10.5 ,5.5 3.5 4.,5 24.0 25 3 2,225 0 3.0 3.5 17.5 24.0 · 27' 4 3,~1~ 1717' 17.5 1.0 2.0 1.0 2.,5 24.0 , 28 $ $,~85 2041 21.5 1.5 1,0 24.0 , , ~ s ~,e4~ e~o 20.5 ,;,.5~.o 24.0 , ,~ , ~ .... 30 7' 7,120 17'4 3.5 16.,5 1.0 0.5 110 1.5 24.0 31 8 ?,~$ 78~ 6.5 4.5 1.0 12.0 24.0 ' APR 1 e e,ll~ 1~07 t7.5 5.o 1.5 24.0 =ooo "~' ~0 ' ' o.O 3 11 0'0 .... . 4 t2 , I 0.0 ~ .t3 o.o 's ..... o.o ................. 7 15 0.0 ~ ,,, 21 16 0.0 ...... 22 17' 0.0 , , , , , , 23 18 0.0 ..... 24 19 0.0 ,, , , ,, , , 2~ 2o o.O 26 21 0.0 , , ,, , , , ,, , ,, , : , , 27 22 0.0 , ....... 28 23 r 0.0 .......... 29 24 0.0 . 1 25 0.0 2 2~ 0.0 3 27 0.0 ...... 4 28 o.O , , , S 29 0.0 6 30 ' o.o' I ii i/ ~ / i CUMMTOTAI. HOURS t13,S 36,S 14,~ 0.0 0,,S 4,S 23'0 6.S 0,0 17.0 216,0 i iii i i i Rig Utilization Chart ARCO ALASKA, INC NANUK NO. 2 RIG UTILIZATION RIG/WORK ON RIG 3% CASING/CEMENT 11% OTHER 8% RIG/TEST BOPE 2% CIRCULATE 7% DRILLING 52% TRIP/WIPE/BHA 17% Daily Progress Chart ARCO ALASKA INC. DALLY DRILLING PROGRESS NANUK NO. 2 I I RUN 9 5/8' CASING i i i i i i iii 0 5 10 -"-'--ACTUAL] DAYS Bit Record I i i BIT RECORD ARCO ALASKA, INC. NANUK NO. 2 BIT SIZE MAKE AND sERIAL I JETS DEPTH FTG HRS HRS AVG DRILLING PARAMETERS MuD ' NO.i W0B BIT RPM PUMP PRES DULL GRADE TYPE HUMBER IN OUT ROT $~nE ROP AVG AVG AVG WT VIS I I ii I 12.3 · HTCMX1 F90DS 3X15,1X1£ 108 2228 212~) 16.3 5.8 95.9 16 51 1510 10.3 80 45VVTA E2NOTD 2 8.5 HYCDG70FNP~ 22154 6X12 2228 6946 4718 35.1 0.0 134.4 7 78 1940 9.6 43 30NOALL Xl NOTD , 3RR 8.5 HTC'ATJLO5D 'V29C1' 3X15,1X1C6946 7072 126 2.75 0.0 45.8 24 107 2090 9.7 43 1 1 NOA E 1 NOCP , 4 8.5 HCARC425C3 190201 6X12 7072 7193 121 1.0 0.0 121.0 4 72 790 9.8 44 00NOA Xl NOBHA 2RR 8.5 HYCDG70FNP~ 22154 6X12 7193 9112 1919 15.0 0.0 127.9 7 88 2175 9.8 41 , ~ , I i I I· Ii i I I I Mud Record DAILY MUD REPORTS ARCO ALASI~, INC. NANUK NO. 2 Mud Data Provided By: BAROID WATER BASE MUD OIL WATER I DATE DEPTH MW FV PV YP GELS FL CAKE SOL % % SD I~T Ph CI- CA 3124/00 627 10.0 92 25 28 21/38 10.0 2/0 8 0 92% 0.75 20 8.9 450.0 40 3124/00 1452 10.3 105 30 48 18/38 6.4 2/0 9.9 0 90% 1.5 13.8 9.2 900.0 56 ,, 3~25~00 2164 10.3 80 28 34 22/58 6.1 2/0 10.9 0 89% 0.6 17.5 9.4 1150.0 52 3/25/00 2228 10.3 80 32 36 22/54 5.4 210 10.9 0 89% 0.5 18.8 9.2 1150.0 44 , , 3/26/00 2228 9.6 35 5 4 1/1 13.8 3/0 9.5 0 90.5% 0.5 10 10.4 600.0 68 , 3/27/00 2674 916 51 15 22 7/10 6.3 2/0 9 0 91% tr 17.5 9.7 650.0 36 , 3/27/00 3945 9.60 51 15 24 9113 6.6 2/0 9 0.0 91% tr 15 9.4 450.0 40 , ~ 3128100 4~5~ 9.6 54 17 25 10/16 6.0 2/0 8.8 0.2 91% tr 18.8 9.3 350.0 44 3/28/00 5986 9.6 42 11 16 5/8 5.6 2/0 8.5 0.5 91% tr 15 8.9 350.0 48 3129100 7059 9.7 43 12 18 6/8 4.4 2/2 7 0.2 92.8% tr 11.3 9.0 250.0 60 , 3/30100 7120 9.8 44 11 16 5/8 4.3 2/2 6.8 0.2 93% tr 12.5 9.1 250.0 48 3/31/00 7240 9.7 41 9 16 5/8 4.0 2/2 '7.1 0.1 92.8% tr 11.3 9.6 250.0 48 3/31/00 7905 9.6 43 10 19 7110 3.9 2/2 7 0.1 92.90% tr 12.5 9.4 250.0 44 , , i 4/1/00 9112 9.7 43 10 18 7/9 4.0 1.0 9 0.2 00.8 tr 16.3 9.0 250.0 56 Survey Record i i SURVEY RECORD ARCO Al~Sl~, INC NANUK NO. 2 MEASURE£ HOLE HOLE COORDINATES VERT. DEPTH ANGLE AZIMUTH TVD N {+) S {-} E {+) W {-) SECTION DOGLEG 124.41 0.15 228.33 124.41 -0.01 -0.02 0.02 0.93 , , 217.71 0.23 290.05 217.71 -0.03 -0.29 0.20 0.22 , 316.27 0.11 286.51 316.27 0.06 -0.56 0.53 0.12 40~.16 0.29 200.58 409.16 -0.11 -0.77 0.77 0.3 , 499.89 0.25 198.45 499.89 -0.5 -0.94 1.03 0.07 588.54 0.33 218.88 588.54 -0.88 -1.16 1.34 0.15 , ~ , 677.98 0.8 232.1 677.97 -1.47 -1.82! 2.12 0.55 [ , , 731.37 1.31 246.07 731.35 -1.95 -2.671 3.06 1106 768.23 2.18 245.57 768.2 -2.41 -3.7 4.16 2.36 799.38 3'.33 "'249.t 799131 ' -2.g7 -5.09' 5.64 ....3.73 827.68 4.42 249.38. 827.54 -3.64 -6.88 7.54 3.85 860.45 5.3 250.3t 860.2 -4.6 -9.48 10.3 2.69 951.41 8.65 254:27 950.47 -7.87 -20.02 21.31 3.72 1042.13 11.65 258.95 1039.76 -11.47 -35.58 37.28 3.42 ' 1137.83 i5.42 262.22 1'1'32.:70 -15.05" -57.67 59.59 '' 4.02 1230.04 18.1 260.26 1221.08 -19.13: -83.94 86.08 2.97 1324.46 21.54 257.85 1309.89 -25.261 -115.35 118.05 3.74 1415.03 24.9 256.79 1393.12i -33A2 -150.17 153.74 3.74 1509.07 28.77 258.08 1477.02 -42.32 -191.59 1~6:17 4.17 1600.51 32.33 256 1555.75. -52.78 -236.87 242.63 4.06 1693.34 33.54 255.69 1633.66 -65.13 -285.8 293.09 1.31 '1'786.22 35.14 '255.87 17i0.351 ' -77.99' .-336.59' 3'45.48 1.73 1879.05 36.96 255.8 1786.13 -91.49 -390.07 400.64 1.94 ....i974,24 06.82 '255.97 1061.54 -105.3 '-4~14'.96 457.24 0.18 2064;66 36.66 254.67 1934i -119 -497.28 511.32 0.88 . ..2!89.0' .06.41 255.54 2010.45{ -!30.56 .-552.01 567.94 .0.61 2250.63 . 36 .... 255.84 2083.74 -146.82 -604. 621..5.9 ... 0.48 2346.03 35.27 256.58 2161.27i -160.07 -657.98 677.17 0.89 2437.79 35.88 255.55 2235.9 -172.93: -709.79 730.55 0.93 2531.15 38.07 256.7 2310.49 -186.38 -764.3 786.69 2.46 .. .262!.3 38.16 .256.9 238.1.42i . --199:09.. -8!8.47 .842.34 . 0.17 2717,1 37.99 256.68 2456.83 -212.59 -875.99. 901.42 0.22 2808,36 37.42 256.35 2529.031 -225.6 -930.27 957.23 0.67 2902.55 37.31 256.26 2603;89 -239.14 -985,81 1014.,~ 0.13 ..... 29~5'.74 37.i4 256.45 2678.091 -252.44 -1040.6 1'070.78 " 0.22 3089.84 37.19 256.87 2753.07 -265.56! -1095.91 1127.63 0.27 3181.8 37.04 256.8 2826.4 -278.2 -1149.95 1183.12 0.17 3274.47 36.98 256.17 2000.4 -291..24 -1204.19; 1238.91 0.42 3368.51 36.86 256.8: 2975.58 -304.44 -1259.11 1295,39 0.42 '34~9.87 "38.22 256.9 3048.02 -317.11 '-i313.'32 i35i".06 '' '1.49 SURVEY RECORD ARCO Al~Sl~, INC, NANUK NO. 2 MEASURE[: HOLE HOLE COORDINATES VERT. DEPTH ANGLE AZIMUTH 'rVD N (+) S (-) E {+} W l'l SECTION DOGLEG 3557.37 39.23 257.9 3124.09 -330.41 -1372.84 1412.04 1.21 , , 3~5.77 38.82 255.73 3192.77 -343.1 -1427.03 1467.$0 1.61 , 3733.19 38.89 256.69 3260.85 -356.18 -1480.29 1522.53 0.69 , 3825.83 38.7 256.25 3333.05 -369.75 -1536.72 1580.57 0.36 ,,,, ,,,, 3919 :ttt.54 255.86 3405.85 -383.76 -1593.15 1638.72 0.31 4011.75 38.46 255.84 3478.43 -397.88 -1649.14 1696.46 0.08 4104.22 38.22 255.88 3550.05 -411.89 -1704.77 1753.8~ 0.27 4196.7 38.11 255.96 3623.67 -425.79 -1760.2 1810.96 0.12 4289.77 37.93 255.9 3696.99 -439.73 -1815.8 1868.29 0.2 4382.29 37.91 256.26 3769.98 -453.4 -1870.99 1925.14 0.24 4475.68 37.69 255.87 3843.77 '-467.19 -1926.54 1982.38 0'.35 4568.03 37.2 255.98 3917.09 -480.84 -1981.01 2038.53 0.53 4660.75 36.7 255.97 3991.19 -494.35 -2035.08 2094.26 0.54 4753.67 36.21 256.27 4065.03 -507.59 -2008.67 2149.47 '0.56 4846.89 35.98 255.91 4141.26 '520.79 -2141.98 2204.39 0.34 4939.19 35.36 256.14 4216.24 -533.8 -2194.21 2258.21 0.69 5037.28 34.56 256.5 4296.63 -547.09 -2248.82; 2314.41 0.84 5131.46 34.01 256.54 4374'.'45' -559.46 -2300.41 ''2367.46 0158 ' 5223.88 33.28 "'25E86 4451.39 ' -571.67 -2350.13 2418.66 0.89 5317.79 31159 256.14 4530.64! -583.851 -2399 2469.03 1.81 5408.1 29.89 256.4 4608.26 -594.82 -2443.85 2515.19 1.89 5503.54 27.64 255.994691.92 -605,77 -2488.44 2561.11 2.37 ....5594.59 25.96 .... 256.7 4773.19 . -61.5.47 -2528.33 2602.16 1.88 5688.14 24.16 .256 4857193 -624.81 -2566.83 26411.78' ' 1.95 5781.05 22.02 255.51 4943.39: -633.77 -2602.14 2678.21 2.32 5872.65 21 255.58 5028.61 -642.15 -2634.66 2711.79 1.11 5960.54 19.74 255.04 5111.01 -649.91 -2664.25 2742.37 1.45 6053.51 17.48 254.5 5199.11 -657.68 -2692.87 2772.02 2.44 6146.97 15.43 254.49 5288.74 -664.76 -2718.38 2798.48 2.18 6209.1 14.2 251.70 5077.0: -671.58 -2740.93 2822 1.54 6332.18 13.28 ' 250.95 5468.22 '-678.65 '-2761'.88 2844.03 '1.02 , 6424.43 11.58 251.59 5558.3 -685.03 -2780.68 2863.8 1.85 65~8.83 9.48 249.19 5656.03 -691.09; -2797.79 2881.86 2.16 6618.1.3 7.89 249.96 5749.24 -696.06 -2811.13 2896 1,69 6708.66 6.31 254,11 5839.08 -699.56 -2821.75 2907.14 1.83 6800.73 5.42 255.7 5930.66 -702.01 -2830.83 2916.55 0.99 6864.32 3.92 259.5 5994.04 -703.15 -2835.88 2921.72 2.4 ' 6924.96 2.09 270.78"6054.59 "'-703.51 -2839.02' 2924.86' 3.'16 ~ , 7025.43 1.87 273.24 6155 -703.4: -2842.49 2928.21 0.24 " 7064.62 1.9 272.73 6'~94.i'7 -703.33 -2843.78 2929.44 0.09 I iiii [ i I I i i i ii i I i SURVEY RECORD ARCO Ai,~SI~, INC, NANUK NO. 2 M~,SURED HOLE HOLE COORDINATES VERT. DEPTH ANGLE AZIMUTH TVD N I+) S (-) E !+) W I-}i SECTION DOGLEG 7064.62 1.9 272.70 6194.17 -703.00 -2843.78 2929.44. 0.09 , 7144.81 1.77 276.98 6274.32 -703.12 -2846.34 2931.88 0.23 , 7234.61 1.77 270.45 6364.08 -702.94 -2849.1 2934.52 0.22 , 7329.11 1.4 267.57 6458.54 -702.97 -2851.71 2937.06 0.4 7422.94 1.25 268.6 6552.35 -703.05 -2853.87 2939.18 0.16 , 7514.21 1.01 269.52 6643.6 -703.08 -2855.68 2940.94 0.26 , 7606.46 0.91 257.73 6735.84 -703.24 -2857.21 2942:47 0.24 7701.12 1.1 258.68 6830.48 -703.58: -2858.84 2944.13 0.2 7791.6 0.68 242.75 6920.95 -704 -2860.16 2945.52 0.54 7879.67 0.43 238.41 7000.02 -704.41 -2860.91 2946.34 0.2~ 7973.17 0.21 208.9 7102.52 -704.74 -2861.29 2946.79 0.2~ 80~5.14 0.19 170.9 7194.49 -705.03 -2861.34 2946.91 0.1ti 8158.89 0.38 153.27 7288.23 -705.46 -2861.18 2946.85 0.2~ 8250.76 0.54 156.73 7380.1 -706.14 -2860.87 2946.71 0.18 8343.5 0.5 159.30 7472.84 -706.91 -2860.56 2046.59 0.06i 8436.61 i 0.41 15g';73 7565.95 -707.6 '-2860.3 2946.5 0.09! 8529.:?.81 0.58 128.3 7658.61 -708.21 -2859.82 2946.18 0.3~ 8628.39: 0.52 118.15 7757.72 -708.73 -2859.02 2945.53 0.12 8719.49 0.49 99.05 7848.81 -708.99 -2858.27 2944.86 0.19 8811.09 0.61 83.36 7941.21 -708.99 -2857.39 2944.01 0'2 8904.26 0.67 73.54 8033.57 -708.78 -2856.39 2942.98 0.14 9000.52 0.89 58.98 8129.82 -708.24 -2855.2 2041.7 0.3 9026,32 0.87 69.23 8155.62 -708.07 -2854.85 2941.32 0.61 9112 0.87 69.23 8241.29 -707.61 -2853.64 2940.03 0 i i i ii I i I I ii i Formation Log MD EPOCH Copyright 1999 by Epoch Well Service~, Inc. LOG INTERVAL DEPTHS: 108' TO 9112' DATES: 3/24/2000 TO 4/1/2000 SCALE: 2"= 100' Spud Mud MUD TYPES TO 2228' LSND TO 9112' TO TO HoustofL TX (281) 874-9166 Bakersfield, CA (661) 328-1595 1004O59783 CASING DATA ~K 16" AT 108' 9 5/8" AT 2219' AT AT HOLE SiZE 12 114" TO 2228' 8 1/2" TO 9112' TO TO ABISREVIATIONS NB NEWBIT PV PLASTIC VISCOSITY RRB RERUN BIT YP YIELD POINT CB CORE BIT FL FLUID LOSS WOB WEIGHT ON BIT CL PPM CLORIDE ION RPM ROTARY REVlMIN Rm MUD RESISTIVITY PP PUMP PRESSURE Rmf FILTRATE RESISTIVITY SPM STROKESlMIN LAT LOGGED AFTER TRIP MW MUD WEIGHT LAS LOGGED AFTER SURVEY ViS FUNNEL VISCOSITY PR POOR RETURNS LC LOST CIRCULATION CO CIRCULATE OUT NR NO RETURNS TG TRIP GAS SG SURVEY GAS WG WIPER GAS CG CONNECTION GAS Formation Lc COMPANY: ARCO Alaska In WELL: Nanuk #2 FIELD: Colville River U~ REGION: North Slope Ala,, COORDINATES: 465' FNL, 864'F $ec.25, T11 N, !~ ELEVATION: RKB 40' AMSL Pad 12' AMSL County, State: N. Slope Boroug APl Index: 50-103-20332-0t Spud Date: 3~24~2000 Contractor: Doyon Ddlling In Co. Rep.; M.Whiteley/D. G RIg/Type: #141 Logging Unit: A1 (Built-in roorr Geologists: John Mords Artem Ratchkov: Add. Persons Isaac Stotts/Mar Scoff Hodges Co. Geologist: D. Bannon/M M ALTERED ZONE F-~ CHERT-ARG,LL ANDESITE [~ CHERT-GLASSY ANHYDRITE [~ CHERT-PORCEL BASALT ~ CHERT- TIGER STRIPE BIOTITIZATION ~ CHERT-UNDIFF BRECCIA ~ C~Y CALCAREN~TE ~ C~Y-MUDSTONE CALCAREOUS TUFF ~ CLYST-TUFFACEOUS CALClLUTITE ~ CHLORITI~TION CARBOnaTeS ~ COAL CARBORAC~OUS ~T ~ CON~OU~T~ CARBONACEOUS SH ~ CONGL. SAND DACITE DIATOMITE DIORITE DOLOSTONE FELSIC SILIC DIKE GABBRO GRANITE GRANITE WASH GRANODIORITE GYPSUM HALITE HORNBL-QTZ-DIO LIMESTONE [~ SAND MARL- DOLO ~ SANDSTONE MARL - CALC ~ SERICITIZTIO~ METAMORPHICS ~ SERPENTINE OBSIDIAN ~ SHALE PORCELANITE ~ SHALE TUFFA PORCELANEOUS CLYST ~ SHELL FRAGIV PYRITE ~ SILICIFICATIOI PYROCLASTICS ~ SILTSTONE QUARTZ DIORITE ~ SILTST-TUFFA QUARTZ LATITE ~ TUFF QUARTZ MONZONITE ~ VOLCANICLAS P-,,-,-,,-~s~-~-~,. ~-,,-,-. ~., ~,~,,- ~ · ,~, Formation Log TVD EPOCH Houston, TX (281) 874-9166 Bakersfie{d, CA (661) 328-1595 Copy~ght 1999 by Epoch Well ServiceJ, Inc. LOG INTERVAL DEPTHS: 108' TO 9112' DATES: 3~24~2000 TO 4/1/2000 SCALE: 2"= 100' Spud Mud MUD TYPES TO 2228' LSND TO 9112' TO TO 10O4059783 CASING DA I A 16" AT 108' 9 5/8" AT 2219' AT AT HOLE SiZE 12 1/4" TO 2228' 8 1/2" TO 9112' TO TO NB RRB CB WOB RPM PP SPM MW VIS NEWBIT RERUN BIT CORE BIT WEIGHT ON BIT ROTARY REVlMIN PUMP PRESSURE STROKESlMIN MUD WEIGHT FUNNEL VISCOSITY ABBREVIATIONS PV PLASTIC VISCOSITY YP YIELD POINT FL FLUID LOSS CL PPM CLORIDE ION Rm MUD RESISTIVITY Rrnf FILTRATE RESISTIVITY LAT LOGGED AFTER TRIP LAS LOGGED AFTER SURVEY PR POOR RETURNS LC LOST CIRCULATION CO CIRCULATE OUT NR NO RETURNS TG TRIP GAS SG SURVEY GAS WG WIPER GAS CG CONNECTION GAS Formation COMPANY: ARCO Alaska In( WELL: Nanuk #2 FIELD: Colville River Un; REGION: North Slope Alas COORDINATES: 465' FNL, 864' FI Sec.25, T11N, R ELEVATION: RKB 401AMSL Pad 12' AMSL County, State: N. Slope Borougl APl Index: 50-103-20332-0( Spud Date: 3/24/2000 Contractor: Doyon Ddlling In, Co. Rep.; M.Whiteley/D. Gl Rig/Type: #141 Logging Unit: A1 (Built-in room Geologists: John Morris Artem Ratchkov., Add. Persons Isaac Stotts/Marl Scott Hodges Co,Geologist: D. Bannon/M. M, ALTERED ZONE [~ ANDESITE ~:~ ANHYDRITE ~--~ BASALT ~--~ BIOTITIZATION ~ BRECCIA ~ CALCARENITE ~-~ CALCAREOUS TUFF ~ CALCILUTITE ~ CARBONATES ~ CARBONACEOUS MAT ~ CARBONACEOUS SH ~ ~,1:: MF NT C,(3NTAM ~ CHERT - ARGILL CHERT - GLASSY CHERT - PORCEL CHERT - TIGER STRIPE CHERT - UNDIFF CLAY CLAY-MUDSTONE CLYST-TUFFACEOUS CHLORITIZATION COAL CONGLOMERATE CONGL. SAND C,C)N~I DACITE DIATOMITE DIORITE DOLOSTONE FELSIC SILIC DIKE GABBRO GRANITE GRANITE WASH GRANODIORITE GYPSUM HALITE HORNBL-QTZ-DIO INTEl IRIVI::,~ LIMESTONE ~ SAND ~ MARL- DOLO ~ SANDSTONE ~ MARL- CALC ~ SERICITIZTIOh METAMORPHICS ~ SERPENTINE OBSIDIAN ~ SHALE PORCELANITE ~ SHALE TUFFA' PORCELANEOUS CLYST ~ SHELL FRAGIV PYRITE ~ SILICIFICATIOt PYROCLASTICS ~ SILTSTONE QUARTZ DIORITE ~ SILTST-TUFFA QUARTZ LATITE ~ TUFF QUARTZ MONZONITE ~ VOLCANICLAS EI:::("..~YRTAI I 171ct'} ~AI ~ITI: ~ VC~I ,Drilling Dynamics Log EPOCH Col~ht 1999 by Epoch Well Service~, Inc. LOG iNTERVAL DEPTHS: 108' TO 9112' DATES: 3/24/2000 TO 4/1/2000 SCALE: 2"= 100' Spud Mud MUD TYPES TO 2228' LSND TO 9112' TO TO Houston,, TX (281) 874-9166 E)akersfie~d, CA (661) 328-1595 J ~f~v~_tte. LA 1004050783 16" AT 108' 9 5/8" AT 2219' AT AT HOLE SiZE 12 1/4" TO 2228' 8 1/2" TO 9112' TO TO NB NEWBIT PV RRB RERUN BIT YP CB CORE BIT FL WOB WEIGHT ON BIT CL RPM ROTARY REVlMIN Rm PP PUMP PRESSURE SPM STROKESlMIN MW MUD WEIGHT VIS FUNNEL VISCOSITY PR At~t~REVtATtON$ PLASTIC VISCOSITY YIELD POINT FLUID LOSS PPM CLORIDE ION MUD RESISTIVITY Rrnf FILTRATE RESISTIVITY /_AT LOGGED AFTER TRIP LC LOST CIRCULATION CO CIRCULATE OUT NR NO RETURNS TG TRIP GAS SG SURVEY GAS WG WIPER GAS CG CONNECTION GAS LAS LOGGED AFTER SURVEY POOR RETURNS Drillin Dynamic, COMPANY: ARCO Alaska In WELL: Nanuk #2 FIELD: Colville River Ur REGION: North Slope Ala., COORDINATES: 465' FNL, 864' F Sec.25, T11 N, I; ELEVATION: RKB 40' AMSL Pad 12' AMSL County, State: N. Slope Borou~ APl Index: 50-103-20332-0~ Spud Date: 3/24/2000 Contractor: Doyon Drilling In Co. Rep.; M.Whiteley/D. G Rig/Type: #141 Logging Unit: A1 (Built-in rooff Geologists: John Morris Artem Ratchkow Add. Persons Isaac Stotts/Mar Scott Hodges Co. Geologist: D. Bannon/M. M ~ ALTERED ZONE ~ ANDESITE ~ ANHYDRITE ~ BASALT ~ BIOTITIZATION ~ BRECCIA ~ CALCARENITE ~ CALCAREOUS TUFF CALCILUTITE · ..... ~,.~ ~ CARBONATES [~ CARBONACEOUS MAT ~ CARBONACEOUS SH ~ CEMENT CONTAM. CHERT - ARGILL CHERT-GLASSY CHERT - PORCEL CHERT- TIGER STRIPE CHERT- UND,F~ cLAY CLAY-MUDS~ONE C~YS~-~U~*CEOUS CHLO.m~ON CO, L CONSLO~RATE CONS~. S*N~ CON~. S*N~S~ONE DACITE DIATOMITE DIORITE DOLOSTONE FELSIC SILIC DIKE GABBRO GRANITE GRANITE WASH GRANODIORITE GYPSUM HALITE HORNBL-QTZ-DIO INTRUSIVES LIMESTONE [-~ SAND MARL - DOLO [~ SANDSTONE MARL - CALC ~-~ SERICITIZTIOI~ METAMORPHICS ~ SERPENTINE OBSIDIAN ~ SHALE PORCELANITE ~ SHALE TUFFA, PORCELANEOUS CLYST [~ SHELL FRAGIV PYRITE ~ SILICIFICATIOI PYROCLASTICS ~ SILTSTONE · QUARTZ DIORITE ~ SILTST-TUFFA QUARTZ LATITE ~ TUFF QUARTZ MONZONITE ~ VOLCANICLAS RECRYSTALLIZED CALCITE ~ VOLCANICS MEMORANDUM TO: THRU: Dan Seamount, Chairman Blair Wondzell, ~ P. I. Supervisor "/~ FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission ~'~~'~ DATE: August 3, 2000 Location Clearance Nanuk 2 PTD #200-0030 Wednesday, August 2t 2000; I made a Location Clearance Inspection on the abandoned exploratory well Nanuk #2. I was accompanied today by Lee Gooding (Phillips environmental tech) and Rick Overstreet (Phillips KRU drilling superintendent). We flew to the location by helicopter and verified proper location by G:P.S. coordinates. Nanuk 2 was drilled and abandoned this last winter exploratory' season. Other than the mound of clean gravel over the cellar there was no indications of any drilling activity on this location. We flew the ice road path this was clean and seemed well vegetated. I recommend this location be approved for final clearance. SUMMARY: I made a Location clearance inspection on Nanuk 2. No problems were observed. Attachments: Loc Clear Nanuk #2 8-2-00 LG.xls Digital Photographs (3); Nanuk mound.jpg Nanuk.aimhot.jpg Nanuk airshot2.jpg "As Built" fOr location cc: Phillip's Petroleum Co: NON-CONFIDENTIAL Loc Clear Nanuk #2 8-2-00 LG.doc 00-03-00 12:24pm From-KUPARUK ;N¥1RONk~NTAL 007-6507712 T-13O P.O,/O? 5, GEO~APHIC CO~[NA~ ARE N~ 27. ~ ~. [LEVA~ONS ~0~ ARE BRITI~ PE~EUM MEAN ~ ~" 5. ALL DISTilS ~E TRUE. ~ 6. ICE PAD ROTATION FROM GRID N~TH IS 8'. ~ - z ~ ~-~- - . ~ UMIAT MERIDIAN ~ ~e'_ ~' NANUK ~2 -, ~ > , .Go~ TOP OF ICE PAD z ~ GROUND ELEV. = 9.8' i .............. 5se' DIMENSI~ ~O O~ER ~TAI~ ARE %~&~,o.~ ~~ LOUNSBURY ........... ARCO Alaska, Inc. NANUK2 ~ ~PL~ATORY ~ ~DUCT~ Subsidiory of Atlontic Richfiel~ ~gony AS-BUILT LOCA~ ALASKA OIL AND GAS CONSERVATION CO~IISSION : / TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7,542 November 30, 2000 Paul Mazzolini Exploration Drilling Team Leader Phillips Alaska, Inc PO Box 100360 Anchorage, Alaska 99510-0360 Re: Location Clearance, Some NPRA Wells Dear Mr. Mazzolini' On August 2, 2000 our inspector Lou Grimaldi accompanied your representatives, Lee Gooding and Rick Overstreet, on final lOcation clearance inspections of some North Slope wells. Mr. Grimaldi concluded that the wells listed below met the requirements for Location Clearance. Well Name Nanuk #2 Clover #A Meltwater North #1 Meltwater North #2 & 2A PTD No.. '"'-' 200-030 '"'" 200-007 '""200-012 x,,,, 199/130 & 200-031 The Location Clearance inspections showed the locations were in compliance with 20 AAC 25.170 Onshore Location Clearance and therefore the Commission requires no further work on subject wells, however Phillips Alaska, Inc. remains liable if problems with the wells occur in the future. Sincerely, L-lc-4pans._do~ ~ ? Blair E. Wondzell, P~. Sr. Petroleum Engineer JUN 1 2 003 PHILLIPS Alaska, Inc. ( A ~ ~ I~lllJJl~ F~-I'I~'~M ~ TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 Ak. Oil & Gas Conservation Comm. ATTN: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99510 RE: Directional survey data DATE: 08/01/2000 Transmitted herewith is the followine: · r Transmittal of directional survey data for 4 1999-2000 North Slope Exploration wells: Permit 200-012 Meltwater North 1; Sperry Sun Job # AKMM90251 Permit 200-031 Meltwater North 2A; Sperry Sun Job # AKMM90261 Permit 199-130 Meltwater North 2; Sperry Sun Job # AKMM90232 Permit 200-030 Nanuk 2; Sperry Sun Job # AKMM0002 CC: Mark McDermott Sharon AIIsup-Drake Approved for transmittal by: Sandra Lemke R E C E l¥ E D Return receipt to: {~ Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 Date: AUG 0 3 2000 Alaska 0il & Gas Cons. Commission Anchorage Prepared by: Sandm D. Lemke Phillips Alaska IT Geoscience Group Well .',Ta...n~e Review the well file, an~.' cmmaauc o:~ plu~i~g, well hea~ scacus, ' i - . c!eaz", co~e. s.ua ccaC!cn c!aa_~s.uce ~=cvi~a loc. Well head ~C oRE: ~~~~' , ............. ~;~a~ Poac =~ place: ..... i m ii ii m I i iiii i i i iii ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG · Status of well Classification of Service Well Oil E] Gas r-] Suspended E] Abandoned [~ Service D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface = - -' - 7. Permit Number 200-030 ! 300-118 8. APl Number 50-103-20332-00 9. Unit or Lease Name 465' FNL, 864' FEL, Sec. 25, T11N, R4E, UM (ASP: 377335, 5954678) I COMPLETION j At Top Producing Interval At Total Depth 1172' FNLt 3718' FELt SEC 25t T11Nt R4E,: UM (ASP: 374470t 5954017) 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 28 & Pad 11' I ADL 354209 ALK 4700 12. Date Spudded March 24, 2000 Colville River Unit lO. Well Number Nanuk #2 11. Field and Pool Exploration Water Depth, if offshore 13. Date T.D. Reached 114. Date Comp., Susp. Or Aband. 115. April 1, 2000 I 5/7/2000 Abandoned I N/A 18. Plug Back Depth (MD + TVD) 119. Directional Survey 120. Depth where SSSV set 9024' MD / 8154' TVD lYES r~ No r-1 I N/A feet MSL feet MD 17. Total Depth (MD + TVD) 9112' MD / 8241' TVD 16. No. of Comple~;~ions 21. Thickness of Permafrost 722' MD 22. Type Electric or Other Logs Run Neutron/Density/4_phase Resistivity/GR, PEX/CMR, DSI, FMI, RI:T, USIT/GR/CCL, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT'. GRADE SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 2219' Surface 9105' HOLE SIZE CEMENTING RECORD 16" 62.5# B 20" 200 cu ft. 9.625" 53.5# L-80 12.25" 397 sx AS III LW, 350 sx Class G 7" 29# L-80 8.5" 198 sx Class G Lead, 245 sx Class G Tail cement plug @ 6707' MD 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 7048'-7108' MD 6178'-6238' TVD 5 spf 7948'-7962' MD 7077'-7091' TVD 6 spf set bridge plug @ 334' RKB AMOUNT PULLED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6906' 6791' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED I 7048'-7108', 7948'-7962' I FRAO: 293550# of 16/20 behind pipe with 12 ppa I I on formation. Left 2450# prop in we,bore I bridge plug: 12.75 bbls AS 1 Icement Plug #1:113 bbls Class G 27. PRODUCTION TEST Date First Production April 19, 2000 Date of Test 4/19-24/2000 Hours Tested 133 hrs Method of Operation (Flowing, gas lift, etc.) Abandoned Production for Test Period > OIL-BBL 588 GAS-MCF 306 WATER-BBL 869 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL 3tess. 350 Psi 655 24-Hour Rate > 740 N/A 935 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ICHOKE SIZE IGAS-OIL RATIO 48/64 I 575 SCF/STB OIL GRAVITY - APl (corr) 39° To be sent under separate cover ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. t 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. refer to attachment Wellbore P&A'd 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Geologic Tops, Time and mud weight chart, memo of abnormal pressure, as-built 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed?~4,~ ~~ Title Exoloration Drilling Team Leader Date O&/~.~ , Paul Mazzolini Prepared by Sharon Al/sup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Ga~njecti~ Shut-in, Other-explain. ' '/'~,~!'"~' V ~,D Item 28: If no cores taken, indicate "none". Form 10-407 JUN 2 6 2000 Ar¢chorac..je Nanuk #2 Confidential Geological Tops: Measured Depth SubSea DEPTH Permafrost 722 683 C-30 2672 2383 K3/Seq 100 4474 3805~ K~Seq 99 4795 4061 Sequence 98 5007 4233 Sequence 97 6705 5796 Sequence 96 7051 6142 Seq 96 Base 7228 6321 Sequence 95 7603 6896 LCU 7970 7060 UJU 8300 7390 Nuiqsut 8525 7615 Nechelik 8800 7890 J3 NR NR TD 9112 8202 JUN 2 6 2000 Ata~ka Oi~ & G,~s Cons. Commission A~chorz~e 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 116" set @ lO8'I DRILLING TIME AND MUD WEIGHT CURVE = Depth Nanuk ~f2 --"--Mud Weight '--F'~--F--F--F J~ F--F T--F ...... T--T--T--T ..... 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J--J--J--J--- I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0 5 10 15 20 25 30 35 Spud 0230 hrs 3/24/00 10.8 10.6 10.4 10.2 10 9.8 9.6 ~~ 9.2 8.8 8.6 8.4 8.2 TIME TO DRILL (DAYS) Rig Release 1900 hrs 4/11/00 prepared by TJB 5/10/00 ARCO Alaska, Inc. Date: Subject: 5/10/00 Abnormal Pressure in Nanuk #2 Internal Correspondence From/Location: Telephone: To/Location: T.J. Brassfield 265-6377 Sharon AIIsup-Drake As requested from the DNR for data submittal on the Nanuk #2 well, there were no abnormally pressured zones encountered while drilling this well. Please find attached the mud weight graph plotted by depth for this well. Any questions, please call me at 265-6377 or Paul Mazzolini at 263-4603. Tom Brassfield a~s.field ~ Staff Drilling Engineer Cc~ MWN#2 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany JUN 2. 6 2000 Alaska 0~! & Gas Cons. Commissio~ Date: 05/10/00 ARCO ALASKA INC. WELL SUMlW_ARY REPORT Page: 1 WELL:NANUK#2 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD:03/24/00 START COMP: RIG:DOYON 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20332-00 03/22/00 (D1) TD/TVD: 80/80 SUPV:MIKE WHITELEY MW: 0.0 VISC: 0 PV/YP: 0/ 0 ( 80) RIGGING UP ON NANUK #2 APIWL: 0.0 Moved camp from MWN#2 to Nanuk#2. Set camp. Move rig modules 25 miles to Nanuk. 03/23/00 (D2) TD/TVD: 80/80 SUPV:MIKE WHITELEY MW: 10.0 VISC: 112 PV/YP: 35/45 APIWL: 10.6 0) Spudded at 02:45 hrs - drilling ahead at 400' at 0600 Pre-spud meeting with both crews. Move rig modules to Nanuk location. Spot sub over hole. Set rig modules. N/U diverter. Accept rig at 12:00 hrs. 3/23/00. Function test diverter. 03/24/00 (D3) TD/TVD: 108/108 SUPV:MIKE WHITELEY MW: 10.3 VISC: 104 PV/YP: 30/48 ( 28) Drilling ahead at 2000' APIWL: 6.4 Pre-spud safety/operations/compliance meeting. Spill drill. Mud motor froze up. Thaw out motor. Fill hole and check for leaks. Drill from 108' to 790'. Build mud volume, repair cuttings conveyor in rock washer. Drill from 790' to 1452' 03/25/00 (D4) MW: 10.3 VISC: 80 PV/YP: 32/36 TD/TVD: 2228/2065 (2120) WASH CEMENT OUT OF DIVERTER SUPV:MIKE WHITELEY APIWL: 5.4 Drill 12.25" surface hole from 1452' to 2228' TD. Pump sweep around. Circ clean for short trip. Observe well. Short trip to 400'. No problems. Pump sweep around, circ cond mud to run casing. PJSM. Run 9-5/8" casing to 2200' Circ and condition mud and hole for cement job. 03/26/00 (D5) TD/TVD: 2228/2065 ( SUPV:MIKE WHITELEY MW: 9.6 VISC: 35 PV/YP: 5/ 4 0) DRILLING AHEAD AT 2350' APIWL: 13.8 Circ and condition mud and hole for cement job. Reciprocate pipe. PJSM. Pump 25 bbls LCM/polymer pill. Set and cemented 9-5/8" casing, shoe at 2219'. Full returns. Plug bumped. Floats held. ND Diverter. NU BOPs. Test BOPs to 250/5000 psi. RIH. Circ out contaminated mud, condition mud. Kick drill and kill drill. JUN 2 6 2000 Date: 05/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 03/27/00 (D6) TD/TVD: 2228/2065 ( SUPV:MIKEWHITELEY MW: 9.6 VISC: 53 PV/YP: 15/24 0) drilling ahead @ 4500' APIWL: 6.6 PJSM. Test 9-5/8" casing to 2500 psi for 30 min. Held. Drill out plugs, floats and good cement and drilled 20' new formation to 2248' Displaced well with 9.6 ppg LSND mud. Ran FIT, EMW = 16.0 ppg. Drilled 8.5" hole from 2248' to 3635'. Pump sweep around, circ clean, observe well, slug DP. Made short trip to 2219', observed well, RIH. No problems hole in good shape. Drill from 3635' to 3945' 03/28/00 (D7) MW: 9.6 VISC: 42 PV/YP: 11/16 APIWL: 5.6 TD/TVD: 5986/5223 (3758) DRILLING AHEAD AT 6310 SUPV:MIKE WHITELEY Drill from 3945' to 5306'. Pump sweep around, circ hole clean. Observe well. Slug DP. Made 17 stand short trip to 3600'. No problems, hole in good shape. Drill from 5306' to 5986'. Pre-reservoir meeting, kick drill. 03/29/00 (D8) MW: 9.7 VISC: 43 PV/YP: 12/21 APIWL: 4.7 TD/TVD: 6946/6075 (960) RIH WITH ROTARY BHA. SUPV:MIKE WHITELEY Drill from 5996' to 6946'. pump sweep around, circ clean, observe well, slug D.P. Start POOH for rotary BHA. Hole in good shape. 03/30/00 (D9) MW: 9.8 VISC: 44 PV/YP: 11/16 TD/TVD: 7120/6249 ( 174) POOH WITH CORE#i ( 7,072' - 7,191') SUPV:MIKE WHITELEY APIWL: 4.3 Finished POOH with DP hole in good shape. Remove RA source. RIH to shoe at 6900'. No problems. MAD pass from 6900' to 6946'. Drill from 6946' to core point at 7072'. Circ for samples. Circ clean. Observe well, slug DP. POOH for core barrels. Hole in good shape. PJSM. RIH with coring BHA to 7030'. Wash to bottom. Cut core #1 from 7072' to 7120' 03/31/00 (D10) MW: 9.6 VISC: 43 PV/YP: 10/19 APIWL: 3.9 TD/TVD: 7905/7170 ( 785) DRILLING AHEAD AT 8275' SUPV:MIKE WHITELEY Core from 7120' to 7193' Filled core barrel. Circ bottoms up for samples. Observe well. POOH slow with core barrels. Recovered 120' core, full recovery. RIH BHA #5. MAD pass from 7060' to 7193'. Drill from 7193' to 7905' 04/01/00 (Dll) MW: 9.7 VISC: 43 PV/YP: 10/18 TD/TVD: 9112/8241 (1207) POOH TO RUN OH LOGS SUPV:MIKE WHITELEY APIWL: 4.0 Drill from 7905' to 9112' TD. Had 1500 unit gas show at 7958' MD. Spill drill. Pump sweep around, circ hole clean, observe well, pump slug. POOH to shoe at 2219'. Tight across sands and HRZ. RIH to 6800', hole in~.~,~.~p~,,~,~-~ JUN 2 6 20O0 Alaska Q)& Gas Cons. 6ommi~ion Date: 05/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/02/00 (D12) TD/TVD: 9112/8241 ( SUPV:MIKE WHITELEY MW: 9.7 VISC: 43 PV/YP: 9/15 0) RUN#2 - FMI / DIPOLE SONIC APIWL: 4.0 Finish making wiper trip, RIH, tagged up at 9052' Wash and ream from 9010' to bottom at 9112'. Pump sweep around, condition mud and hole for OH logs. POOH for logs. Run #1, platform express/CMR from 9095' to 2500'. Run #2, FMI/Dipole sonic. 04/03/00 (D13) TD/TVD: 9112/8241 ( SUPV:MIKE WHITELEY MW: 9.6 VISC: 47 PV/YP: 9/18 0) RIH OVERSHOT STRIPPING OVER WIRE LINE AP IWL: 4.2 Run FIT/dipole sonic, tool rotating in hole. POOH with tools. Install swivel on top of FIT/dipole sonic. Ran log from 9056' to 2219'. Run #3 RFT. Attempted 30 pressures. Stuck RFT tool taking sample at 8309'. Work wire line to 75% of weak point minimum, 3300 lbs overpull. Work wire line pulling to 100% of weak point max, 6000lbs overpull. No tool movement - did not pull out of rope socket, prepare to cut and thread. Top of fish at 8278' 04/04/00 (D14) MW: 9.6 VISC: 52 PV/YP: 11/18 APIWL: 4.4 TD/TVD: 9112/8241 ( 0) TIH W/ CO ASSY SUPV:DEARL W. GLADDEN PJSM. TIH stripping over wireline to 8173'. CBU. Baker tool operator pull fish into overshot, pull off wireline at rope socket. POOH. Shear circu sub, pump dry job, flow check. TOH w/fish, flow check @ shoe, OK. Continue TOH. Set test plug and test BOPs. Test BOPs 250/5000 psi. 04/05/00 (D15) MW: 9.6 VISC: 46 PV/YP: 11/16 APIWL: 3.8 TD/TVD: 9112/8241 ( 0) LOGGING (RUNNING ROT SIDE WALL CORES) SUPV:DEARL W. GLADDEN PJSM. Test BOPs to 25/5000 psi. Pull test plug. TIH to shoe. Tag tight spot at 9020'. Wash and ream from 9020' to 9112'. TOH. Run #1, RFT. 04/06/00 (D16) MW: 9.6 VISC: 45 PV/YP: 15/17 APIWL: 4.0 TD/TVD: 9112/8241 ( 0) TOH - L/D 5" DP SUPV:DEARL W. GLADDEN PJSM. Run #1 MSCT, Run #2 MSCT. TIH w/HO assy, fill @ shoe, 4700', 7030', Tag tight @ 9068'. Wash and ream 9068' to 9112'. Circ and condition to run 7" casing. TOH. 04/07/00 (D17) MW: 9.7 VISC: 48 PV/YP: 19/16 APIWL: 4.0 TD/TVD: 9112/8241 ( 0) CMT 7" CSG SUPV:DEARL W. GLADDEN TIH, tight ~ 9076', hard bridge, could not wash thru. Circ and condition. TOH. Flow check, OK. PJSM. Run 7" casing. JUN 2 6 2000 Date: 05/10/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 04/08/00 (D18) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 9112/8241 ( 0) R/U wirline to run CBL. SUPV:DEARL W. GLADDEN PJSM. Continue to run 7" casing. Circulate and condition, start circ slowly, after working circ up slowly hole showed to be bridging off, pressure increase. 04/09/00 (D19) MW: 9.6 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8834/8241 ( 0) R/U shooting nipple on BOPs SUPV:DEARL W. GLADDEN PJSM. Tag TOC @ 8834'. TOH. PJSM. WLL - run #1 USIT/GR/CCL CBL Log 8810' to 3960'. WOC 12 hours. WLL run #2 USIT/GR/CCL/CBL 7620' to shoe @ 2219' 04/10/00 (D20) MW: 9.6 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8834/8241 ( 0) FREEZE PROTECT WELL SUPV:DEARL W. GLADDEN PJSM. Continue to log w/USIT/GR. Gun Run #1, shot 5 hpf 20' length, 7088' thru 7108'. Gun Run #2, shot 5 hpf, 20' length, 7066' thru 7088'. Gun run #3 shot 5 hpf, 20' length, 7048' thru 7068'. RIH w/pkr assy and tail pipe. Run tubing assembly. Test annulus. 04/11/00 (D21) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8834/8241 ( 0) RIG RELEASED FROM NANUK #2 ~ 1900HRS - RIG HAS MOVER T SUPV:DEARL W. GLADDEN N/D BOPs, N/U tree and test to 5000 psi. Run #1 - pull DV from top GLM @ 2486'. Freeze protect well. Run #2 - install DV in top GLM @ 2486'. Run #3, pull ball rod. Run #4 - pull RHC plug. Secure tree, clean cellar area. Rig released 1900 hrs 4/11/00. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~' KI(NANUK-2(W4-6)) WELL JOB SCOPE JOB NUMBER NANUK-2 DRILLING SUPPORT-CAPITAL 0411000847.1 DATE DAILY WORK UNIT NUMBER 04/16/00 FRAC TREATMENT DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-YOAKU M FERG USON FIELD AFC# CC# Signed ESTI MATE AX2005 FD U N DV4N K Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DALLY SUMMARY IRU DOWELL AND PUMP PREPAD AND 500 BBL DATAFRAC AT 30 BPM. PUMP FRAC AT 30 BPM USING DESIGN PAD OF 800 BBLS. PLACE 293,550 #'S BEHIND PIPE WITH 12 PPA ON FORMATION. UNDER FLUSH BY 5 BBLS LEAVING 2450 #'S PROP IN P IPE.[Frac-Refrac] TIME LOG ENTRY 08:15 ARRIVE LOCATION. DOWELL RU PUMP EQUIPMENT. 09:15 SAFETY MEETING 10:20 PRIME UP, PT LINES, SET TREESAVER, BEGIN 200 BBL PREPAD 10:35 PUMP 201 BBLS 20# LINEAR GEL AT 35 BPM AND AVG PRESSURE OF 3700 PSI. PERFORM SDT AND ISIP @ 710 PSI, FG=0.57 PSI/FT. XS FRICTION= 934 PSI AT 35 BPM. 10:45 CHECK TEMP ON TANKS, TEMPS APPEAR TO BE LOW,(BELOW 90 DEG) NEED AROUND 105 DEG FOR X/L TIME. EVALUATE TEMPS FOR REHEAT OR BEST WAY TO DRAW WARM FLUIDS FROM EXISTING TANKS. 11:20 12:00 PLAN TO PUMP AWAY THE CURRENT VOLUME OF GEL MIXED WITH THE COLDER FLUID AND THEN BATCH UP WITH THE WARMER FLUID.(ONLY ONE TANK WAS BELOW MINIMUM TEMPS) START DATAFRAC AT 35 BPM. PUMP 500 BBL DF AND SD FOR EVALUATION. TC=7.5 MIN, PC= 960 PSI, EFF=26%, CT=0.0037. WILL PUMP FRAC WITH DESIGN PAD OF 800 BBLS 13:10 START FRAC JOB AT 30 BPM. PAD VOLUME = 800 BBLS. PLACE 293,550#'S OF 16/20 WITH MAX CONC. OF 12 PPA ON FORMATION. LEFT APPROX 2450 #'S PROP IN WELLBORE. PUMPED FLUSH OF 58 OUT OF 63 BBLS. 15:45 RDMO 1. BASIS OF HORIZONTAL LOCATION AND ELEVATION IS J,I/DR1LLslTE~ ( ~ ZONE 4, NAD 27. ~~~~~ 3. GEOGRAPHIC COORDINATES ARE NAD 27. ~ ~ ] · 4. ELEVATIONS ~HO~ A~E BRITISH PETROLEU~ ~EAN ~ 7. DATE OF SURLY: 3/14/2~, F.B. L~-~7,pAGES 58-62.~ ~9 ~ ~~'~ ~~~~L~ , - VlglNITY ~AP m.T.S. ~ J o ~ ~ 2~' cc ~ --~ t NANUK ~2 , ~ee'..-~'''-"~1 ~ 864' ~ LOCATED WITHIN PROTRACTED ~ ~, ~ ~ SEC. 25 TWP. ~1 N.. RGE. 4 E. y..' R,g Pod UMIAT MERIDIAN m ~,~ o i ~ ~ LAT. = 70'17'~4.822" m ~ 3~' ~ LONG. = 15~'59'33.878" ~ ~' Y = 5,954,678.~1 ~ . o 2~'; _ ~ NANUK ~2 i X = 377,335.~2 464' F.N.L, 864' F.E.L ~ '-- z--'~ s s TOP.OF ICE PAD = 11. z ~< GROUND ELEV. = ~ 5~' SUR~YOR'S CERTIFICA O~ ~J~j- ! HEREBY CERTIFY THAT! AM PROPERLY ~ ~... & ....~ ~ LAND SUR~YING IN THE STATE OF ~ ~' ~-~' *~ ALASKA AND THAT THIS PLAT REPRESENTS ~ ] 49th '~ ~ % ~ A SURLY DONE BY .E OR UNDER ~ ..... ~. ............................... a ..... DIRECT SUPERVISION AND THAT ALL (%~ BRIAN G. MANGOLD /~. CORRECT AS Of MARCH 15, ,,:o~_. ........... · ~%' BURY , A~ M, xxxx NANUK2 ARCO Alaska, Inc. ~ ~XPLO. ATO.~ ~ CONOUCTO. Subsidiary of Atlantic Richfield Company AS-BUILT LOCA~ON NO.I I LK6~1D34~ 3/15/e~ CEA-M1XX-6~1D34e Page 1 of 1 JUN 2 6 2000 A~a~ka Oi! a~. Gas Qx.~s, (]ommi~io~ file://C:\TEMP\VVellhead just cut.jpg 6/9/00 Page 1 of 1 JUN 2 6 2000 file://C:\TEMP\Capped and Sealed.jpg 6/9/OO Page 1 of 1 file://C:\TEMP\Channel on 7 x 9.625.jpg 6/9/00 Page 1 of 1 JUN 2 6 2000 file://C:\TEMPXJust before sealing.jpg 6~9/00 Page 1 of 1 file://C:\TEMP\Usin, g SaWsall.jpg 6/9/00 Page 1 of 1 file://C:\TEMP\Wellhead and cond.jpg 6/9/00 Page 1 of 1 JUN 2 6 2000 Alaska Oii & Gas Cons. Commission file://C:XTEMP\Wellhead before cutting.jpg 6/9/00 Page 1 of 1 dUN 2 6 2000 file://C:XTEMP\wellhead cutoff.jpg 6/9/00 Page 1 of 1 file://C:\TEMP\Before Cutting.jpg 6/9/00 Page 1 of 1 file://C:\TEMP\welll~ead portion.jpg 6/9/00 Nanuk #2 Plug & Abandon Work May 3, 2000 Personnel On Site: 3 Dowell, 3 Halliburton Slickline, 2 APC, 1 Arco, 1 Nordic, 2 Global, 3 Arctic Catering, 5 Peak Last 36 Hours Activities: 5/2/00 22:30 - 5/3/00 09:00 R/U Halliburton Slickline Pull Dummy Valve from GLM at 6707' Attempt to set PX plug in X Nipple at 6751'. Plug will not land Set dummy valves in GLM's at 6817' and 6847' Set PXN Plug in XN Nipple at 6892' Wells Group Crew Rigging Up Set 400 bbl Open Top Tank Set Choke House Run hardline from IA valve to choke house to tank Pressure test hardline 5/3/00 07:00 - 10:00 R/U Dowell and APC Trucks Run hardline to wellhead Remove blank flange from companion valve Install 1502 x flange on companion valve 5/3/00 10:00- 12:00 Hold PJSM with ARCO, Dowell and APC. Discuss Operation and Hazards Hook Dowell up to 3 ½" tubing. Prime Dowell Pumps '. 5 APC Vac Trucks Onsite. (2 Full Brine, 1 Freshwater, 1 Dirty Vac for Washup, 1 Diesel) Pressure test Dowell Lines to 2700 psi Open choke skid and begin pumping 9.8 ppg brine down tubing taking returns through open pocket GLM. Venting gas for first 40 bbls pumped. Returns slowly changed to liquid. Mostly produced wellbore fluids. No pressure on pumps for first 150 bbls of Brine pumped. Pressure slowly started rising. Pumped a total of 234 bbls 9.8 ppg brine. Good clear returns to surface. .. 5/3/00 12:00- 12:30 Tie Dowell into 3 ½" x 7" annulus. Tie choke and tank hardline into 3 Va" tubing. Pump 10 bbls diesel down 3 V2" x 7" annulus taking returns into tank. 'dUN 26 2000 5/3/00 12:30- 16:15 Run dummy valve into GLM at 6707'. Using Dowell pumps pressure test 3 Va" x 7" annulus to 1000 psi. Bleed off though choke. Pull PXN plug from XN nipple at 6892'. R/D Halliburton Slickline and release to Spark. 5/3/00 16:15 to 19:15 Rig Dowell Up to 3 Va" tubing. Begin Pumping cement plug. Pump 6 bbls water. Follow with 5 bbls Class G. Follow with 15 bbls Class G with Perfect Seal. Follow with 93 bbls Class G. Displace with 52 bbls 9.8 ppg brine and 5 bbls Diesel. No pressure on Pumps until 30 bbls into brine displacement. Slowly built pressure to 105 psi. Slow rate from 2.1 BPM to 1.1 BPM. Pressure rising. Slow rate from 1.1 BPM to 0.6 BPM. Pressure slowly rising up to 750 psi. Slow rate from 0.6 BPM to 0.33 BPM. Pressure broke over just as 52 bbls Brine displacement pumped. Shut down pumps for 15 minutes holding pressure on tubing. Pressure slowly fell to 30 psi. Bring pumps on at 0.31 BPM pumping diesel. Pump 2 bbls diesel. Pressure rising to 339 psi. Shut down pumps for 15 minutes holding pressure on tubing. Pressure slowly fell to 160 Psi. Bring pumps on at 0.31 BPM pumping diesel. PumP 1.5 bbls diesel. Pressure rising to 481 psi. Shut down pumps for 15 minutes holding pressure on tubing, pressure slowly fell to 284 psi. Bring pumps on at 0.31 BPM pumping diesel. Pump 1.5 bbls diesel. Pressure rising to 567 psi. Shut down pumps and very slowly bleed off pressure. 2na'APC Dirty Vac out.to suck Open Top Tank. Release 1 empty brine truck. Send freshwater truck back to Kuparuk for refill. Keep remainder of APC Trucks on location. RDFN Nanuk #2 Plug & Abandon Work May 4, 2000 Personnel On Site: 3 Dowell, 3 Schlumberger Wireline, 2 APC, 1 Arco, 1 Nordic, 2 Global, 3 Halliburton Contract Truck Drivers, 5 Peak, 3 Halliburton Slickliners (Dowell, Wireline and APC Staying at KCC) Last 24 Hours Activities: 07:30-08:45 Run Hardline from Dowell to 7" x 9 5/8" annulus Hold PJSM with ARCO, Dowell and APC Pressure test lines to 2200 psi Pump 50 bbls of Freshwater lead at 2 BPM and 700 psi Pump 23.8 bbls of Arctic Set 1 at 1.5 BPM and 627- 309 psi No displacement.. 08:45 - 09:30 Suck lines dry. Wash up Dowell. Begin to R/U Schlumberger Wireline R/U Dowell to 3 1/2" tubing Discuss Operation with State Inspector John Crisp 09:30 - 10:00 Pressure test Dowell lines to 2200 psi Attempt to pressure test tubing and squeeze plug Slowly bring pressure up, tubing is full At 800 psi, pressure broke over Started pumping away at 1 BPM and 500 psi Shut Down after pumping a total of 4.5 bbls away 10:00 - 10:30 R/D Schlumberger Wireline, Release Baker Hand Secure well 10:30 - 17:00 Wait on delivery of Class G cement blend and Perfect Seal from Deadhorse. 17:00- 19:00 Test Dowell lines to 2300 psi Pump 2 bbls water ahead at 1.3 BPM and 630 psi Pump 5 bbls neat Class G at 1.8 BPM and 512 psi Pump 31 bbls Class G cement with Perfect Seal at 20#/bbl. Estimate Class G plug was pumped at 1.5 BPM and 300 psi. The Perfect Seal greatly reduces the efficiency of the pumps by not allowing all the fluid that is in each cylinder to be actually pumped downhole. Therefore the computer strokecounter thinks it is pumping much faster than actual. The estimate on pump rate was from mix water leaving the tub on the Dowell unit. Once on displacement, the efficiency returns to normal. Pump 19.5 bbls of displacement Brine at 2 BPM and negligible pressure. At approximately 19.5 bbls the pressure began to rise rapidly from nearly 0 psi to 787 psi. Cut rate to 1 BPM with pressure still rising rapidly. Switched displacement fluid to diesel and cut rate to 0.5 BPM. Pressure rising rapidly. Cut rate to 0.15 BPM. Pump pressure up to 2050 psi. Shut down pump holding pressure on tubing. Hold pressure on tubing for 30 minutes. Pressure fell to 1035 psi. Open 3 ½" x 7" annulus to choke to ensure no leaks to annulus. No pressure on annulus Slowly pump an additional 0.25 bbls diesel at 0.15 BPM. Pressure rose to 2000 psi. Shut down and monitor tubing pressure. Hold tubing pressure for 30 minutes. Pressure dropped to 1373 psi. Slowly pump an additional 0.15 bbls of diesel. Pressure rose to 1996 psi. Shut down and monitor tubing pressure · Hold tubing pressure for 15 minutes. Pressure dr°pped to 1776 psi Very slowly bleed off tubing pressure Estimate diesel volume at 0.75 bbls diesel downhole Estimate top .of cement at 2500' 19:00- 19:45 Wash up Dowell. Secure well. RDFN Nuiqsut Weather at 06:00 5/5/00:2 degrees with South winds at 8 knots Nanuk #2 Plug & Abandon Work May 5, 2000 Personnel On Site: 3 Dowell, 3 Schlumberger Wireline, 2 APC, 1 Arco, 1 Nordic, 2 Global, 5 Peak, 3 Halliburton Slickliners (Dowell, Wireline and APC Staying at KCC) Last 24 Hours Activities: 08:00- 10:30 RFLI Dowell to 3 ½" tubing. Having extreme difficulty turning both master valves. Pressure test Dowell lines. Open companion valve. Pressure up tubing to 2300 psi. Pressure response was immediate. Virtually no bleed off of pressure. Suspect wellhead is frozen.. Wrap scaffolding around wellhead with plastic and put heater trunks inside plastic. Thaw out wellhead. R/U Schlumberger Wireline. Attempt to RIH with weight bars for tag. Will not go through Wellhead. Continue to run heat to wellhead 10:30- 11:45 Run wireline weight bars in hole successfully. Tag TOC at 2342' POOH Rig up Dowell on 3 ½" tubing Pressure test tubing/cement squeeze plug to 1744 psi. Pressure fell to 1653 psi in 15 minutes. 5% loss State Witness okay'd tag and pressure test Bleed off pressure 11:45- 16:00 R/U Wireline on 3 Va" tubing RIH with 2.79" drift and weight bars. Tag up at 43' and 47' RKB. (Actual about 8' and 12' below ground level) POOH. Looks like ice on drift. RIH with weight bars (1.6875" drift). Run to 400' without problem. P/U and work through tight spot about 10 times. POOH RIH with 2.79" drift. Tag up in same spots. Attempt to work through with no luck. POOH M/U and RIH with 2.50" blank firing head. No problems. Went to 350' without trouble. P/U and work through tight spots. PFLI Baker Bridge Plug (2.7" OD) Unable to get through same spots. POOH M/U 2.50" blank firing head. RIH and run through tight spots 12 times. POOH JUN 2 6 2000 Discuss options with town and State Inspector M/U and RIH with Tubing Perforator (1.6875" OD) 4 spf 8 shots total RIH and log up for collar tie in. Shoot holes at 315' RKB POOH. All shots fired. 16:00- 18:15 R/U Dowell on 3 Va" tubing taking returns off IA, through choke manifold, into tank. Pressure test lines to 1500 psi Circulate 30 bbls brine at 2.5 BPM and 77 psi Circulate 20 bbls diesel at 2.6 BPM and 27 psi. Good returns to surface. R/U Schlumberger Wireline on 3 V2" tubing. RIH with 2.79" drift. Ran to 360' without problems. M/U Baker Bridge Plug and RIH with same Log up for collar tie in. Set Bridge Plug at 334' RKB P/U off tool. RBIH and tag up Bridge Plug on depth. POOH R/D Wireline 18:15- 19:00 R/U Dowell on 3 Va" tubing. Pressure test Bridge Plug and 3 Va" x 7" annulus to 2000 psi for 5 minutes. Pump 2 bbls water with red dye marker Pump Arctic Set 1 cement until good returns to surface. Total of 12.75 bbls. Shut all wellhead valves to trap cement at surface Suck all lines dry 19:00 - 20:00 Wash up Dowell. Breakdown all hardline and replace tree and wellhead flanges R/D Schlumberger Wireline R/D Dowell Release Wireline, Dowell and APC equipment Nuiqsut Weather at 06:00 5/6/00:21 degrees with South winds at 12 knots Nanuk #2 Plug & Abandon Work May 6, 2000 Personnel On Site: 3 APC, 1 Arco, 1 Nordic, 2 Global, 5 Peak, Last 24 Hours Activities: 06:00 - 06:00 APC Wells Group Continuing to Rig Down Equipment APC Drilling Support personnel on location. Remove scaffolding, plywood and herculite from around wellhead Remove tree from lower master valve up. Cement visible in tubing. Dig out snow and ice from cellar box with jackhammer Cut out base plate RJU APC Backhoe Tear out cellar box. Dig hole around wellhead approximately 20' x 20' xl0' Prep hole for wellhead cutting Nanuk #2 Plug & Abandon Work May 7, 2000 Personnel On Site: 5 APC. 2 Arco. 1 Nordic. 2 Global. 7 Peak. 2 ACS. 1 Fwthr Last 24 Hours Activities: 06:00 - 06:00 Prep hole for wellhead cutting. Hold PJSM on operation and safety concerns RfC APC Forklift with Stinger and slings. Attach to wellhead for support. RfU GBR Welder. Cut three windows in 16" conductor pipe Drill hole with air drill into 9 5/8" x 7" annulus. Found diesel. Not' much volume coming out of hole. R/U Sawsall jig saw and begin cutting pipe through window State Inspector John Crisp on location. Discuss plan with him. He gave permission to continue without him on location and to seal it up Cut through all strings of casing/tubing with saw. Cut remaining 16" conductor with cutting torch. Remove wellhead and conductor stub with forklift stinger 3 1/2" Tubing had full cement to surface 3 V2" x 7" annulus had full cement to surface 7" x 9 5/8" annulus had cement to surface around approximate 75% of annular space Pack 'remaining annular space with cement Grind down casing strings to level with 16" conductor Take pictures with digital camera Weld on 16" diameter steel plate onto remaining casing. Backfill hole with cuttings. Leave a mound to account for subsidence. R/D P&A Operation PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 June 23, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Nanuk #2 (Permit 200-030/300-118) Completion Report Dear Mr. Christenson: Phillips Alaska, Inc., as operator of the Meltwater North #2A exploration well, submits the enclosed "Well Completion Report" (form 407). Other attachments to the completion report include the directional survey, geologic tops, report of daily well operations, memo for Abnormal Pressure, Time and mud weight chart, photos of the P&A operations and an as-built. We will send under separate cover the logs, the mud logs and other well data and reports. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolini Exploration Drilling Team Leader PAI Drilling PAM/TJB/skad North Slope Alaska Alaska State Plane 4 EXPL ORA TION_NON-PAD Nanuk tt2 Surveyed: 1 April, 2000 OR!6JNAL SURVEY REPORT 13 April, 20OO Your Ref: API-501032033200 Surface Coordinates: 5954678.01 N, 377335.02 E (70° 17' 04.8220" N, Kelly Bushing: 40.3Oft above Mean Sea Level 150° 59' 33.8784" W) Survey Ref: svy9154 North Slope Alaska Measured Depth (ft) Incl. Azim. SUb-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for Nanuk #2 Your Ref: API-501032033200 Surveyed: 1 April, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) .0.00 0.000 0.000 -40.30 0.00 108.00 0.000 0.000 67.70 108.00 124.41 0.150 228.330 84.11 124.41 217.71 0.230 290.050 177.41 217.71 316.27 0.110 286.510 275.97 316.27 409.16 0.290 209.580 368.86 409.16 499.89 0.250 198.450 459.59 499.89 588.54 0.330 218.880 548.24 588.54 677.98 0.800 232.100 637.67 677.97 731.37 1.310 246.070 691.05 731.35 768.23 2:180 245.570 727.90 768.20 799.38 3.330 249.400 759.01 799.31 827.68 4.420 249.380 787.24 827.54 860.45 5.300 250.310 819.90 860.20 951.41 8.650 254.270 910.17 950.47 1042.13 11.650 258.950 999.46 1039.76 1137.83 15.420 262.220 1092.49 1132.79 1230.04 18.100 260.260 1180.77 1221.07 1324.46 21.540 257.850 1269.59 1309.89 1415.03 24.900 256.790 1352.81 1393.11 1509.07 28.770 258.080 1436.71 1477.01 1600.51 32.330 256.000 1515.44 1555.74 1693.34 33.540 255.690 1593.35 1633.65 1786.22 35.140 255.870 1670.04 1710.34 1879.95 36.960 255.800 1745.82 1786.12 Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Vertical Rate Section (°llOOfl) (ft) 0.00 N 0.00 E 5954678.01N 377335.02 E 0.00 0.00 N 0.00 E 5954678.01N 377335.02 E 0.000 0.00 0.01S 0.02W 5954678.00 N 377335.00 E 0.914 0.02 0.03 S 0.28W 5954677.98 N 377334.74 E 0.222 0.28 0.06 N 0.56W 5954678.08 N 377334.46 E 0.122 0.53 0.12 S 0.76W 5954677.91N 377334.26 E 0.308 0.77 0.50 S 0.94W 5954677.52 N 377334.07 E 0.073 1.03 0.89 S 1.16W 5954677.14 N 377333.85 E 0.146 1.34 1.47S 1.81W 5954676.57 N 377333.18 E 0.542 2.11 1.95 $ 2.67W 5954676.11 N 377332.32 E 1.063 3.05 2.41 $ 3.69W 5954675.66 N 377331.29 E 2.361 4.15 2.97 S 5.07W 5954675.12 N 377329.90 E 3.737 5.63 3.64 S 6.86W 5954674.48 N 377328.10 E 3.852 7.53 4.60 S 9.47W 5954673.57 N 377325.47 E 2.696 10.29 7.87 S 20.01W 5954670.47 N 377314.88 E 3.719 21.31 11,47 S 35.57W 5954667.12 N 377299.26 E 3.427 37.28 15.05 $ 57.67W 5954663.90 N 377277.11E 4.018 59.60 19.13 S 83.94W 5954660.25 N 377250.78 E 2.970 86.08 25.27 S 115.35W 5954654.63 N 377219.27 E 3.744 118.05 33.12 $ 150.18W 5954647.34 N 377184.32 E 3.738 153.75 42.33 $ 191.61W 5954638.81N 377142.75 E 4.161 196.18 52.79 S 236.88W 5954629.09 N 377097.31E 4.061 242.65 65.13 S 285.82W 5954617.55 N 377048.18 E 1.316 293.11 78.00 $ 336.60W 5954605.51N 376997.19 E 1.726 345.50 91.50 S 390.08W 5954592.88 N 376943.50 E 1.942 400.66 Comment Continued... DrillQuest 1.05,05 13 April, 2000 - 9:41 - 2 - North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for Nanuk #2 Your Ref: API-501032033200 Surveyed: 1 April, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (St) (ft) 1974.24 36.820 255.970 1821.23 1861.53 2064.66 36.660 254.670 1893.69 1933.99 2159.80 36.410 255.540 1970.14 2010.44 2250.63 36.000 255.840 2043.43 2083.73 2346.03 35.270 256.580 2120.97 2161.27 2437.79 35.880 255.550 2195.60 2235.90 2531.15 38.070 256.700 2270.18 2310.48 2621.30 38.160 256.900 2341.11 2381.41 2717.10 37.990 256.680 2416.52 2456.82 2808.36 37.420 256.350 2488.72 2529.02 2902.55 37.310 256.260 2563.59 2603.89 2995.74 37.140 256.450 2637.79 2678.09 3089.84 37.190 256.870 2712.78 2753.08 3181.80 37.040 256.800 2786.11 2826.41 3274.47 36.980 256.170 2860.11 2900.41 3368.51 36.860 256.800 2935.29 2975.59 3459.87 38.220 256.900 3007.73 3048.03 3557.37 39.230 257.900 3083.80 3124.10 3645.77 38.820 255.730 3152.48 3192.78 3733.19 38.890 256.690 3220.55 3260.85 3825.83 38.700 256.250 '3292.76 3333.06 3919.00 38.540 255.860 3365.55 3405.85 4011.75 38.460 255.840 3438.14 3478.44 4104.22 38.220 255.880 3510.67 3550.97 4196.70 38.110 255.960 3583.38 3623.68 105.30 S 444.97W 119.01 $ 497.29W 133.57 S 552.03W 146.83 S 604.01W 160.08S 657.99W 172.94S 709.80W 186.39 S 764.31W 199.10 S 818.49W 212.60 S 876.00W 225.61S 930.28W 239.15 S 985.82W 252.45 S 1040.60W 265.56 $ 1095.91W 278.20 S 1149.94W 291.24S 1204.18W 304.44S 1259.11W 317.10 S 1313.31W 330.40 S 1372.84W 343.09 S 1427.03W 356.16 S 1480.29W 369.74 S 1536.72W 383.75 S 1593.16W 397.87 S 1649.14W 411.88 S 1704.77W 425.78 S 1760.20W 5954579.98 N 376888.39 E 5954567.13 N 376835.85 E 5954553.46 N 376780.89 E 5954541.05 N 376728.69 E 5954528.68 N 376674.50 E 5954516.67 N 376622.49 E 5954504.11 N 376567.77 E 5954492.29 N 376513.39 E 5954479.73 N 376455.67 E 5954467.60 N 376401.19 E 5954454.98 N 376345.43 E 5954442.57 N 376290.44 E 5954430.36 N 376234.92 E 5954418.60 N 376180.69 E 5954406.45 N 376126.25 E 5954394.15 N 376071.11 E 5954382.37 N 376016.71 E 5954370.05 N 375956.98 E 5954358.24 N 375902.59 E 5954346.04 N 375849.12 E 5954333.38 N 375792.48 E 5954320.29 N 375735.82 E 5954307.09 N 375679.61 E 5954293.99 N 375623.76 E 5954280.99 N 375568.11 E Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Vertical Rate Section (°/lOOfl) (fi) Comment 0.184 457.26 0.878 511.33 0.604 567.96 0.492 621.60 0.889 677.18 0.932 730.57 2.460 786.71 0.169 842.35 0.227 901.43 0.663 957.25 0.130 lO14.41 0.220 lO70.78 0.275 1127.63 0.169 1183.12 0.414 1238.9o 0.422 1295.39 1.490 1351.05 1.218 1412.03 1.614 1467.69 0.694 1522.53 0.361 158o.57 0.313 1638.72 0.087 1696.46 0.261 1753.82 0.130 1810.96 Continued... 13 April, 2000 - 9:41 - 3 - DrillQuest 1.05.05 ~' ~'~' 2 6 DO0 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for Nanuk #2 Your Ref: AP1-$01032033200 Surveyed: 1 April, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (~t) (tt) (it) (it) (ft) 4289.77 37.930 255.900 3656.70 3697.00 4382.29 37.910 256.260 3729.68 3769.98 4475.68 37.690 255.870 3803.48 3843.78 4568.03 37.200 255.980 3876.80 3917.10 4660,75 36.700 255.970 3950.89 3991.19 4753.67 36.210 256.270 4025.63 4065.93 4846.89 35.980 255.910 4100.96 4141.26 4939.19 35.360 256.140 4175.94 4216.24 5037.28 34.560 256.500 4256.33 4296.63 5131.46 34.010 256.540 4334.14 4374.44 5223.88 33.280 255.860 4411.08 4451.38 5317.79 31.590 256.140 4490.34 4530.64 5408.10 29.890 256.400 4567.96 4608.26 5503.54 27.640 255.990 4651.62 4691.92 5594.59 25.960 256.700 4732.88 4773.18 5688.14 24.160 256.000 4817.62 4857.92 5781.05 22.020 255.510 4903.09 4943.39 5872.65 21.000 255.580 4988.30 5028.60 5960.54 19.740 255.040 5070.70 5111.00 6053.51 17.480 254.500 5158.80 5199.10 6146.97 15.430 254.490 5248.43 5288.73 6239.10 14.200 251.730 5337.49 5377.79 6332.18 13.280 250.950 5427.91 5468.21 6424.43 11.580 251.590 5517.99 5558.29 6523.83 9.480 249.190 5615.72 5656.02 439.72 S 1815.80W 5954267.96 N 375512.29 E 453.40 S 1870.99W 5954255.19 N 375456.88 E 467.18 S 1926.55W 5954242.31 N 375401.11 E 480.84 S 1981.01W 5954229.55 N 375346.43 E 494.35 S 2035.08W 5954216.92 N 375292.15 E 507.59 S 2088.68W 5954204.55 N 375238.34 E 520.79 $ 2141.99W 5954192.22 N 375184.82 E 533.79 S 2194.22W 5954180.08 N 375132.39 E 547.09 S 2248.83W 5954167.68 N 375077.57 E 559.45 S 2300.42W 5954156.15 N 375025.78 E 571.66 $ 2350.14W 5954144.75 N 374975.86 E 583.85 S 2399.01W 5954133.37 N 374926.80 E 594.81 S 2443.85W 5954123.14 N 374881.79 E 605.76 S 2488.45W 5954112.92 N 374837.02 E 615.46 S 2528.34W 5954103.87 N 374796.98 E 624.80 S 2566.85W 5954095.16 N 374758.32 E 633.76 S 2602.16W 5954086.78 N 374722.87 E 642.15 S 2634.69W 5954078.92 N 374690.21 E 649.90 S 2664.28W 5954071.65 N 374660.50 E 657.68 S 2692.91W 5954064.34 N 374631.75 E 664.76 S 2718.41W 5954057.68 N 374606.12 E 671.58 S 2740.96W 5954051.22 N 374583.48 E 678.65 S 2761.90W 5954044.50 N 374562.42 E 685.03 S 2780.70W 5954038:42 N 374543.51 E 691.09 S 2797.82W 5954032.64 N 374526.30 E Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 0.197 1868.28 0.240 1925.14 0.348 1982.38 0.536 2038.53 0.539 2094.26 0.561 2149.47 0.336 2204.39 0.687 2258.21 0.842 2314.42 0.584 2367.47 0.889 2418.67 1.807 2469.04 1.888 2515.20 2.367 2561.12 1.878 2602.17 1.950 2641.79 2.313 2678.23 1.114 2711.81 1.449 2742.40 2.438 2772.05 2.193 2798.51 1.539 2822.03 1.008 2844.05 1.849 2863.83 2.158 2881.90 Cont~ued... 13 April, 2000- 9:41 -4- DrillQuest 1.05.05 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services SurveY Report for Nanuk #2 Your Ref: API-501032033200 Surveyed: 1 April, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (fi) 6618.13 7.890 249.960 5708.93 5749.23 6708.66 6.310 254.110 5798.76 5839.06 6800.73 5.420 255.700 5890.35 5930.65 6864.32 3.920 259.500 5953.73 5994.03 6924.96 2.090 270.780 6014.28 6054.58 7025.43 1.870 273.240 6114.69 6154,99 7064.62 1.900 272.730 6153.86 6194.16 7144.81 1.770 276,980 6234.01 6274.31 7234.61 1.770 270.450 6323.77 6364.07 7329.11 1.400 267.570 6418.23 6458.53 7422.94 1.250 268.600 6512.04 6552.34 7514.21 1.010 269.520 6603.29 6643.59 7606.46 0.910 257.730 6695.53 6735.83 7701.12 1.100 258.680 6790.17 6830.47 7791.60 0.680 242.750 6880.64 6920.94 7879.67 0.430 238.410 6968.71 7009.01 7973.17 0.210 208.900 7062.21 7102.51 8065.14 0.190 170.900 7154.17 7194.47 8158.89 0.380 153.270 7247.92 7288.22 8250.76 0.540 156.730 7339.79 7380.09 8343.50 0.500 159.390 ' 7432.53 7472.83 8436.61 0.410 159.730 7525.63 7565.93 8529.28 0.580 128.300 ~7618.30 7658.60 8628.39 0.520 118.150 7717.41 7757.71 8719.49 0.490 99.050 7808.50 7848.80 696.07S 2811.16W 699.56 S 2821.79W 702.02S 2830.87W 703.16 S 2835.91W 703.52 S 2839.06W 703.40 S 2842.53W 703.34S 2843.81W 703.12 $ 2846.37W 702.94 S 2849.14W 702.98 S 2851.75W 703.05 S 2853.92W 703.09 S 2855.72W 703.25 $ 2857.24W 703.59 $ 2858.87W 704.00 S 2860.20W 704.41S 2860.95W 704.75 S 2861.33W 705.05 S 2861.38W 705.48 $ 2861.22W 706.15 $ 2860.91W 706.93 S 2860.60W 707.62 $ 2860.34W 708.22 S 2859.86W 708.75 S 2859.07W 709.00 S 2858.32W 5954027.88 N 374512.88 E 5954024.57 N 374502.20 E 5954022.26 N 374493.08 E 5954021.20 N 374488.01 E 5954020.89 N 374484.86 E 5954021.06 N 374481.40 E 5954021.15 N 374480.11 E 5954021.41 N 374477.56 E 5954021.63 N 374474.80 E 5954021.64 N 374472.19 E 5954021.60 N 374470.02 E 5954021.60 N 374468.22 E 5954021.46 N 374466.69 E 5954021.15 N 374465.05 E 5954020.75 N 374463.72 E 5954020.35 N 374462.97 E 5954020.03 N 374462.58 E 5954019.73 N 374462.52 E 5954019.29 N 374462.67 E 5954018.62 N 374462.97 E 5954017.83 N 374463.27 E 5954017.14 N 374463.52 E 5954016.53 N 374463.99 E 5954015.99 N 374464.78 E 5954015.72 N 374465.52 E Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Vertical Rate Section (°/100fi) (ft) Comment 1.691 2896.03 1.834 2907.18 0.983 2916.59 2.407 2921.76 3.157 2924.90 0.235 2928.24 0.088 2929.48 0.235 2931.91 0.224 2934.55 0.400 2937.10 0.162 2939.23 0.264 2940.98 0.239 2942.51 0.201 2944.16 0.534 2945.55 0,288 2946.38 0.287 2946.83 0.143 2946.95 0.221 2946.90 0.177 2946.75 0.050 2946.63 0.097 2946.54 0.339 2946.22 0.115 2945,57 0.187 2944.91 Continued... 13 April, 2000 - 9:41 ' $ ' DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for Nanuk #2 Your Ref: AP1-501032033200 Surveyed: 1 April, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8811.89 0.610 83.360 7900.90 7941.20 709.01 S 2857.44 W 5954015.70 N 374466.40 E 8904.26 0.670 73.540 7993.26 8033.56 708.80 S 2856.43 W 5954015.90 N 374467.41 E 9000.52 0.890 58.980 8089.51 8129.81 708.25 $ 2855.25 W 5954016.42 N 374468.60 E 9026.32 0.870 69.230 8115.31 8155.61 708.08 S 2854.90 W 5954016.59 N 374468.96 E 9112.00 0.870 69.230 8200.98 8241.28 707.62 S 2853.68 W 5954017.03 N 374470.18 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.779° (23-Mar-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 256.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9112.00ft., The Bottom Hole Displacement is 2940.10ft., in the Direction of 256.073° (True). Alaska State Plane 4 EXPLORATION_NON-PAD Dogleg Vertical Rate Section (o/100fl) (ft) Comment 0.207 2944.05 0.135 2943.03 0.306 2941.75 0.614 2941.36 0.000 2940.07 Projected Survey 2000 Continued... DrillQuest 1.05.05 13 Apr~ 2000-9:41 -6- Sperry-Sun Drilling Services Survey Report for Nanuk tt2 Your Ref: AP1-501032033200 Surveyed: 1 April, 2000 North Slope Alaska Comments Measured Depth (ft) 9112.00 Station Coordinates TVD Northings Eastings (fi) (ft) (ft) 8241.28 707.62 s 2853.68 w Comment Projected Survey Alaska State Plane 4 EXPLORATION_NON-PAD Survey tool program From Measured Vertical Depth Depth (ft) (ft) o.oo o.oo To Measured Vertical Depth Depth (ft) (ft) 9112.00 8241.28 Survey Tool Description MWD Magnetic DrillQuest 1.05.05 13 April, 2000 - 9:41 - 7- corn I.~ Petroleum Services 3430 Unicorn Road Bakersfield, California 93308 Tel: 661-392-8600 Fax: 661-392-0824 www.corelab.com CORE ANALYSIS RESULTS ARCO ALASKA, INC. "NANUK" #2 KUPARUK FIELD UMIAT MERIDIAN, ALASKA CL FILE #57111-00082 Performed by: Core Laboratories 3430 Unicom Road Bakersfield, CA 93308 (805) 392-8600 Final Report Presented July 26, 2000 CLB ~Y$~ INTRODUCTION Core Laboratories was requested to perform standard Dean-Stark porosity, permeability and fluid saturation analysis upon rotary-drilled sidewall core samples from the subject well. Presented herein are the results of the analysis performed in Bakersfield with a brief description of the requested procedures and tests. In conjunction with the report, the core analysis results are supplied in Excel format on an IBM PC compatible floppy diskette. We appreciate this opportunity to be of service and hope these data prove beneficial in the development of this reservoir. DESCRIPTION OF SERVICES Sample Preparation (Dean Stark Analysis) Samples were cleaned of drilling mud, trimmed to right cylinders, and inserted into thin-walled metal jackets and fiffed with 120 mesh end-screens. The jackets were seated to the samples, under hyclrostatic loading at a pressure equal to (Depth-100) psig to a maximum pressure of 2000 psig. A mercury displacement pump was used to measure the bulk volume of the fractured or irregularly shaped samples that were unsuitable for sleeving. Fluid Extraction Samples were weighed and placed into tared extraction thimbles. Water and oil were extracted from the sample plugs by Dean Stark methods with toluene as the solvent. The plugs were held in the Dean Stark extractors for a minimum of forty-eight hours and were removed only after no additional water was recovered in the receiving tubes. Complete hydrocarbon extraction was conducted using soxhlet extractors with methylene chloride as the solvent. Cleaned samples ~vere removed from the soxhlets and dried in a convection oven at 180°F for four hours and then placed into a vacuum oven at 180°F for a minimum of twenty-four hours. Following the vacuum-oven, drying sample weights were monitored for stability. Upon weight stabilization sample plugs were cooled to laboratory temperature in a desiccator prior to analysis. Grain Density Determinations Grain volumes were determined using Boyle's Law extended range helium porosimeters. Where applicable, metal jacket and end-screen weight and volume corrections were applied. Grain density values were calculated using Equation 1. Mg 8ma = (1) vg Where: (~ma = Matrix (grain) density (g/cc) = 'Grain mass (g) = Grain volume (cc) Porosity Determination (Jacketed Samples) Direct pore volume measurements using Boyle's Law double-cell methods were performed upon jacketed samples confined at 400 psig in Hassler-type core holders. Porosity values for the jacketed samples were calculated using Equation 2. VVhere: = Porosity (%) Vp = Pore volume (cc) Vg = Grain volume (cc) Porosity Determination (Un-Jacketed Samples) Measured grain and bulk volumes were used to calculate sample pore volume and porosity values using Equation 3. Where: ~) = Porosity (%) Vg = Grain volume (cc) Vb = Bulk volume (cc) (Vb - Vg) = Pore volume (cc) Fluid Saturation Calculations Oil and water saturation results were calculated using Equations 4 and 5. I~-~l*lO0 (5) Sw = Lv~j Where: So = Oil saturation (%) Mw = Water saturation (%) Vw = Fresh sample mass (g) (~o = Dded sample mass (g) Vp = Extracted water mass (g) = Extracted water volume (cc) = Density of oil = Pore volume (cc Permeability to Air Permeability determinations were made on the jacketed samples following pore volume determinations. Permeability values for the un-jacketed samples were estimated. Permeability values of sleeved samples were calculated utilizing Darcy's Equation for compressible fluids, Equation 6. ] Ka = L L~ (6) Where: Ka = Permeability to air (md) = Atmospheric pressure = Gas viscosity (cp) = Differential pressure Pa Qa aP Vb = Mean pressure = Flow rate (cc/sec) = Length (cm) = Bulk volume (cc) Sample Disposition End-trimmings from the plug samples were "batch" cleaned using toluene followed by methylene- chloride as the solvents. The cleaned trimmings were forwarded to Geologics in Piano Texas for thin- section preparation. Upon completion of analysis all sample plugs will be packaged and held pending ARCO's final disposition instruction ARCO Alaska Nanuk f~2 Kuparuk Field Rotary Sidewall Core Dean-Stark Analysis Results CL. File No.: 57111- 00082 1 4796 NA3 9.7 15.5 76,7 0.20 92,2 2.72 Sst g~-It tan vfgr vsity It sptd sin gld flu D. Stark 2 4802 31. 25.1 17.0 69,7 0,24 86.7 2,71 Sst tan vfgr sity m stn gld flu D. Stark 3 4828 NA ~ 30.4 8,7 86.5 0.10 952. 2.75 Sst gry-tan vfgr vslty cly m sptd stn gld Itu D. Stark 4 7048 7.5 17.9 22.6 48.4 0.47 71.0 2,68 Sst tan-It bm vfgr sity m stn gld flu D. Stark 5 7049 727. 17.6 20.9 48.3 0.43 69.2 2.68 Sst tan-It bm vfgr si sity m sin gld flu D. Stark 6 7050 1.4 18.0 20.7 73.0 0.28 93.7 2.76 Sst tan-it bm vfgr slty m stn gtd flu D. Stark 7 7051 987. 17,9 12.5 51.9 0,24 64,4 2.69 Sst tan-It bm vfgr si slty m stn gld flu D. Stark 8 7052 834, 16.2 11.9 65.0 0,18 77,0 2.72 Sst tan-It bm vfgr si slty m stn gld flu D. Stark 9 7053 58. 18.0 15.3 46.5 0,33 61.9 2,69 Sst tan-It bm vfgr slty m stn gld flu D, Stark 10 7054 892. 18.3 14.1 60.4 0,23 74.6 2,70 Sst tan-It bm vfgr si slty m stn gel flu D. Stark 11 7055 2,4 16.4 11.3 61.0 0,19 72.3 2.68 Sst tan4t bm vfgr slty m sin gld flu D. Stark 12 7056 5.5 17.1 19.6 54.0 0,36 73.7 2,68 Sst tan-It bm vfgr slty m stn gid flu D. Stark 13 7057 1.4 16.0 t8,2 58.7 0,31 76.9 2.70 Sst tan-It bm vfgr stty rn stn gld flu D. Stark 14 7058 0.97 17.8 20.5 55,5 0,37 76.1 2.87 Sst tan vfgr vslty It stn dull gld flu D. Stark 15 7059 4.8 17.9 13,9 42.6 0.33 56.5 2.70 Sst tan-It bm vfgr slty rn stn gld flu D. Stark 16 7060 13. 18,6 13.8 47.0 0,29 60.8 2.70 Sst tan-it bm vfgr slty m stn gld Itu D. Stark 17 7061 4.1 18.2 23.8 39,2 0.61 63.0 2.70 Sst tan4t bm vfgr slty m stn gld flu D. Stark 18 7062 4.6 18.3 23.5 40.4 0.58 63.8 2.70 Sst tan-it bm vfgr slty m sin gld flu D. Stark 19 7063 5.5 17.9 19.1 56,3 0,34 75.4 2,69 SSt tan-It bm vfgr sity m stn gld flu D. Stark 20 7066 8,3 18.7 12.1 49,1 0,25 61.1 2,69 Sst tan-It bm vfgr slty m stn gld flu D. Stark 21 7067 11. 19,0 13.0 51.4 0.25 64.4 2.69 Sst tan-tt bm vfgr sity m sin gld flu D. Stark 22 7194 1.7 16.2 8.2 79.2 0.10 87,4 2.71 SSt tan-It bm vfgr slty m stn gld flu D. Stark 23 7215 0.71 15,8 9.8 70.9 0.14 80.7 2.70 Sst tan-It bm vfgr slty m sin gld flu D. Stark 24 7217 2,9 17,5 5.3 68.6 0,08 73.9 2,71 Sst tan-It bm vfgr slty m stn gld flu D. Stark 25 7533 0.54 15.6 7.2 67.1 0,11 74.3 2.69 SSt tan vfgr vsity rn stn gld flu D. Stark 26 7536 2.2 17.1 3.3 74,0 0.04 77.3 2.70 Sst tan vfgr vslty m stn girl flu D. Stark 27 7636 2.9 17.2 10.2 52.2 0,20 62.5 2,69 Sst tan vfgr vslty It stn yel-gld flu D, Stark 28 7645 5.9 18,4 8.5 52.8 0,16 61.4 2,70 Sst tan vfgr vslty It stn yel-gid flu D, Stark 29 7959 0.003 6.1 ~0.0 30.9 0,08 30.9 3,13 ,~dlst gry vfgr sdy calc pyr no s~ no flu D, Stark ARCO Alaska Nanuk ~2 Kuparuk Field Rotary Sidewall Core Dean-Stark Analysis Results CL File No,: 57111.00082 Sst bm vfgr si slty cht incl dk sm dull gld flu D. Stark Sst bm vfgr sl slty dk stn gid flu D. Stark Sst bm vfgr si slty dk stn gld flu D. Stark Sst bm vfgr si slty dk stn gid flu D. Stark SSt bm vfgr si slty dk stn gld flu D. Stark Sst bm vfgr si slty dk stn gld flu D. Stark Sst bm vfgr si slty dk stn gld flu D. Stark Sst bm vfgr si slty dk stn gld flu D. Stark Sst It bm vfgr vslty cht incl calc m stn dull gld flu D. Stark Sst gry-tan vfgr vslty calc m sptd stn yel-gld flu D. Stark SSt gq/vfgr vslty shly no stn no flu D. Stark Sst tan vfgr vsity cly It st~ yel-gld flu D. Stark Sst tan vfgr vslty cly It stn yel-gld flu D, Stark Sst gry vfgr vslty shly no stn no flu D, Stark Sst gry vfgr vslty shly no stn no flu D. Stark Sst gry vfgr v slty shly no sm no flu/Fractured D. Stark Sst gry vfgr vslty shly no stn no flu D,, Stark 30 7960 181. 25,3 24.8 34,4 0.72 59.3 2.71 31 7961 234. 23.2 26.8 28,6 0,94 55,4 2.77 32 7962 279. 23,6 25,3 27.3 0.93 52,6 2.77 33 7963 116. 23,0 22.1 26.6 0.83 48.7 2.82 34 7964 75. 22,1 22.0 30.4 0,72 52.5 2,77 35 7964 55. 21,7 26.3 24.2 1,09 50.5 2.83 36 7965 242, 23,4 23.0 28.3 0.81 51.3 2,71 37 7966 596. 24.7 22,2 41.0 0,54 63.2 2,66 38 7967 0.03 8,5 29,6 28,8 1.03 58.4 2.82 39 7968 0.07 7.0 24.2 35.4 0.68 59,6 2.68 40 8225 NA 3 16.2 0,0 99.7 0.00 99.7 2.68 41 8228 NA 3 13.9 0.0 95.1 0.00 95.1 2.70 42 8303 3.2 16,6 13.0 56,8 0,23 69.7 2.67 43 8309 5,4 17.8 13.5 60.8 0,22 74.2 2.68 44 8558 NA 3 10,3 0.0 982 0.00 98.2 2.70 45 8565 NA 3 10,1 0,0 93,4 0.00 93.4 2.68 46 8925 926, 7.4 0,0 77,8 0.00 77.8 2.68 47 8930 0.16 7.4 0.0 83.5 0.00 83.5 2,68 Hel. Pore volume determined using helium porosimeter BV2 - Pore volume calculated using measured grain and bulk volumes. Bulk volume determined by mercury displaF, ement. NA3 - Not Analyzed, irregu~r sample uns. uitab _le for measured permeability. CORE LABORATORIES CORE ANALYSIS RESULTS ARCO ALASKA, INC. NANUK 2 COLVILLE DELTA UMIAT MERIDIAN, ALASKA CL FILE #57111-00082 Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (805) 392-8600 Final Report Presented June 5, 2000 The analytical results, opinions or interpretations contained in this report are based upon information and material supplied by tt~e client for whose exclusive and confidential use this report has been made. The analytical results, opinions or interpretations expressed represent the best judgment of Core Laboratories, Core Laboratories, however, makes no warranty or representation, express or implied, of any type, and expressly disclaims same as to the productivity, proper operations or profitableness of any oi~, gas, coa~ 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, in whole or in part, w~thout the written approva~ of Core Laboratories. TABLE OF CONTENTS SECTION DESCRIPTION OF SERVICES CORE ANALYSIS - TABULATED RESULTS HYDRAULIC UNIT CLASSIFICATION PROFILE PERMEAMETER 4 INTRODUCTION Core Laboratories was selected by Arco Alaska Inc. to perform a core analysis study upon samples recovered from the subject well. Conventional aluminum inner barrel cores were submitted. The detailed protocol for both field and laboratory handling and analysis provided by ARCO Alaska was adhered to throughout the project. Only a condensed summary of the requested tests and procedures is included in this report. This report is divided into four sections. The first section provides a description of services. Section 2 contains tabulated results of porosity, permeability, and fluid saturation determinations. Section 3 presents the reservoir quality index (RQI), flow zone indicator (FZI), and hydraulic unit determinations for each sample. Results of pressure-decay profile permeameter measurements performed upon the slabbed core are presented in the final section. In conjunction with the report, results of analysis are supplied on diskette in Excel format. CORE PROCESSING Cores were handled in the field, and all core processing performed by Core laboratories personnel from our Anchorage office. Core Gamma Surface Log Each core was scanned for natural gamma radiation utilizing Corelab's gamma spectrometer. Total gamma radiation is reported in APl units. Core Sampling and Slabbing The core was slabbed parallel to the core axis utilizing a 1/4 - 3/4 cut. Liquid nitrogen was used as the blade coolant. For photography, viewing, description and additional sample selection by ARCO's representatives the 1/4 sections were placed into slab boxes with Styrofoam inserts. Sample Preparation Both horizontally and vertically oriented one-inch diameter plugs were drilled from each foot of core. Isopar mineral oil was used as the bit coolant and lubricant. Each plug was weighed, wrapped with Saran wrap and aluminum foil, and sealed in a sample jar as drilling was completed. Upon completion of the sampling all plugs were packaged and shipped to our Bakersfield California facility. ANALYSIS TECHNIQUES Fluid Extraction Samples taken with horizontal orientation were weighed and placed into tared extraction thimbles. Water and oil were extracted from the sample plugs by Dean Stark methods with toluene as the solvent. The plugs were held in the Dean Stark extractors for a minimum of forty-eight hours and were removed only after no additional water was recovered in the receiving tubes. Complete hydrocarbon extraction was conducted using soxhlet extractors with methylene chloride as the solvent. Cleaned samples were removed from the soxhlets, dded in a convection oven at 180°F for four hours. Samples were then dded in a vacuum oven at 180°F for a minimum of twenty-four hours. Following the vacuum-oven drying, the sample weights were monitored for stability. Upon weight stabilization sample plugs were transferred to a desiccator and cooled to laboratory temperature prior to analysis. Samples designated for vertical permeability determinations were "batch" cleaned in large Dean Stark extractors with toluene to remove water and then transferred to soxhlet extractors for batch cleaning with methylene chloride. Drying was performed as for the horizontal plugs prior to permeability measurements. Grain Density Determinations Grain volumes were determined using a Boyle's Law extended range helium porosimeter. Metal jacket and end-screen weight and volume corrections were applied to the jacketed samples. Grain density was calculated using Equation 1. 5ma = (1) Where: 5ma = Mg = Vg = Matrix / grain density (g/cc) Grain mass (g) Grain volume (cc) Confining Pressure for Porosity and Permeability Measurements Following grain volume determinations, the plug samples were placed into a Hassler-type holder and a confining pressure was applied for porosity and permeability measurements. A confining pressure of 400 psig was used, which is essentially "ambient" conditions, preventing gas by-pass but not acting to compress the sample. Porosity Determination Direct pore volume measurements were performed upon confined samples utilizing Boyle's Law double-cell methods. Porosity values were calculated using Equation 2. = Where: ~ = Porosity (%) Vp = Pore volume (cc) Vg = Grain volume (cc) Fluid Saturation Calculations Oil and water saturation results were calculated using Equations 3 and 4. SO -- (3) Sw = I]· 1 O0 (4) Where: SO = Sw = Mf = Md = Mw = Vw = (50 = Vp = Oil saturation (%) Water saturation (%) Fresh sample mass (g) Extracted and dried sample mass (g) Extracted water mass (g) Extracted water Volume (cc) Density of oil Pore volume (cc) Permeability to Air Permeability determinations were made following the pore volume determinations again with the samples confined in Hassler-type holders. Permeability values were calculated utilizing Darcy's Equation for compressible fluids, Equation 5. Ka = ] (s) Where: Ka = Permeability to air (md) Pa = Atmospheric pressure vg = Gas viscosity (cp) AP = Differential pressure P = Mean pressure Qa = Flow rate (cc/sec) L = Length (cm) Vb = Bulk volume (cc) Hydraulic Unit Analysis After rock property measurements had been completed, a hydraulic unit analysis was performed. Reservoir quality index (average pore throat size) and pore ratio values were calculated for each sample using Equations 6 and 7. RQI = 0.0314 · (6) PR = (7) Where: RQI = Reservoir quality index Ka = Permeability to air (md) (Z) = Fractional porosity PR = Pore ratio RQI and PR values determined for each sample are utilized to assign each foot of core to a hydraulic unit. Each hydraulic unit represents a unique pore geometry relationship and provides a foundation for the integration of core and electric log data. To facilitate selection of representative samples for additional testing, hydraulic unit classifications are presented both sorted by sample depth and by hydraulic unit. Pressure-decay Profile Permeameter (PDPK) The PDPK determines permeability of a sample by unsteady-state methods using a transient "blowdown" technique. A tank of known volume is first filled with nitrogen and then the gas is discharged through the core sample to atmosphere. The decaying tank pressure is monitored versus time, which allows determination of gas flow rate and pressure drop across the sample at any given time. The automated recording of flow rate versus pressure differential provides the data necessary for calculation of a Klinkenberg-corrected permeability as well as the permeability to air. The results of analysis are reported in tabular format and are presented on diskette in Excel format. Sample Disposition End-trimmings from both the horizontal and vertical plug samples were ~batch" cleaned using toluene followed by methylene-chloride as the solvents. The cleaned trimmings were forwarded to Geologics in Piano Texas for thin-section preparation. Upon completion of analysis all sample plugs will be packaged and held pending ARCO's final disposition instructions. CORE ANALYSIS RESULTS ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: $7111 - 00082 Sst bm vfgr sity rn stn yei-gld flu Sst it bm vfgr slty carb strk m stn yel-gld flu/SI Frac Sst bm vf'gr slty sh rn stn yel-gld flu Sst bm vfgr slty sh lam rn stn yel-gld flu Sst bm vfgr slty sh lam carl3 strk m stn yel-gld flu Sst bm vfgr slty sh lam m stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu Sst bm vfgr slty sh rn stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu Sst bm vfgr slty rn stn yel-gld flu Sst bm vfgr sity carl3 rn stn yel-gld flu Sst bm vfgr slty carb strk m stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu Sst bm vfgr slty sh lam rn stn yel-gld flu Sst bm vfgr slty sh strk m stn yel-gld flu Sst bm vfgr slty rn stn yel-gld flu Sst It bm vfgr vslty m stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu Sst It bm vfgr slty rn stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr sity m-dk mot stn yel-gld flu Sst It bm vfgr vslty sit strk carb m stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu 1 7072.1 4,5 5.6 17,4 29.0 49,7 0.58 78.7 2.70 2 7073,1 8.2 16.8 40.2 31.1 1.29 71.3 2.65 3 7074,1 18, 12. 18.7 44.1 25.2 1.75 69.3 2.69 4 7075.1 2.1 15.4 39.7 35.3 1,13 74.9 2,69 5 7076.1 14. 2.8 18.0 37,7 31.0 1.22 68.7 2.68 6 7077.1 8.1 17.8 42.3 28,8 1.47 71.t 2.70 7 7078.1 21. 17. 18.9 46,1 26.1 1.77 72.2 2.69 8 7079.1 5,8 16.9 44.5 28.6 1,56 73.1 2.69 9 7080,1 7.1 3,7 17.9 44,7 25.7 1,74 70.5 2,69 10 7083.8 t .8 16.5 38,3 33.5 1.14 71.8 2.70 11 7084.2 2.5 1.2 16.8 36.1 32.9 1,10 69,0 2.69 t2 7085.5 0.79 15.2 45,8 29.9 1.53 75.7 2.69 13 7087.3 14. 18,0 50.1 22.8 2.20 72.9 2,68 14 7088.2 7,7 4.3 17.6 47.5 24.2 1,96 71.7 2,69 15 7089.2 5.4 16,6 37.4 43.1 0.87 80.5 2.74 16 7090.1 2.9 1.2 15.1 37.0 42.0 0.88 79.0 2.69 17 7091.2 10. 17.5 53.3 21.4 2.50 74.7 2.69 18 7095.1 0.96 15.7 46.4 24.9 1.86 71.3 2.70 19 7096.1 2.7 1.6 16.4 51.9 21.4 2.42 73.4 2.71 20 7097.2 1.3 15.4 37.7 36.3 1.04 73.9 2.70 21 7098.1 1.2 0.42 15.2 33.8 38.7 0.87 72.6 2.69 22 7099.1 2.4 16.0 41.6 32.5 1,28 74.1 2.70 23 7100.1 7.7 4.5 17.3 42.4 27.9 1.52 70.3 2.69 24 7101.1 7.5 17.3 42.6 29.0 1.47 71.6 2.70 25 7102.1 0.66 1.2 14.4 34.5 41.9 0.82 76.5 2.67 26 7103.1 4.6 16.7 38.1 35.1 1.09 73.1 2.70 Page I Core Analysis Results ARCO ALASKA, INC, "NANUK" 2 COLVILLE DELTA FIELD CL File No,: 57111 - 00082 CORE ANALYSIS RESULTS Permeability and porosity measured using 400 pslg confining pressure. 27 7105.1 0.46 14.9 35.5 40.5 0.88 76.0 2.70 28 7106.2 0.93 0.31 14.9 31.4 46.0 0.68 77.4 2.65 29 7108.4 1.1 0.45 15.2 35.7 38.3 0.93 74.1 2.67 30 7109.1 22. 18.5 33.4 46.9 0.71 80.3 2.70 31 7110.4 0.56 0.31 15.2 34.0 38.8 0.88 72.7 2.69 32 7111.1 52. 15.9 35. t 42.9 0.82 78,1 2.70 33 7112.1 0.62 0.32 15.3 31.8 43.2 0.74 74.9 2.70 34 7113.1 3.4 16.6 31.1 46.8 0.66 77.9 2.71 35 7114.2 0.14 0.082 12.1 23.8 58.5 0.41 82.4 2.68 36 7115.2 0.20 11.6 25.5 62.6 0.41 88.1 2.68 37 7116,1 0.32 0.13 14.4 29.0 47.6 0.61 76.6 2.69 38 7117.8 0.19 13.4 29.9 50.4 0.59 80.3 2.68 39 7118.5 5.8 6.7 15.9 21.2 48.3 0.44 69.6 2.56 40 7119.2 2.1 16.2 26.8 54.6 0.49 81.4 2.69 41 7120.2 58. 0.24 15.8 28.7 43.7 0.66 72.4 2.66 42 7121.1 1.8 15.5 26.8 54.6 0.49 81.4 2.69 43 7122.3 0.59 0.16 13.9 25.3 60.1 0.42 85.4 2.70 44 7123.1 1.1 14.7 26.1 54.7 0.48 80.8 2.70 45 7124.1 2.7 1.5 15.9 24.9 57.9 0.43 82.9 2.70 46 7125.2 2.7 16.4 24.6 56.1 0.44 80.6 2.71 47 7126.1 6.6 3.9 17.6 22.8 55.7 0.41 78.5 2.70 48 7127.1 4.6 17.1 21.1 56.4 0.37 77.5 2.70 49 7128.2 0.73 0.28 14.7 49.8 35.9 1.39 85.7 2.70 50 7129.2 3.9 16.7 2! .1 56.9 0.37 78.0 2.69 51 7130.1 1.2 0.59 15.2 23.0 60.0 0.38 83.0 2.69 52 7131.3 2.1 15.9 24.4 55.8 0.44 80.1 2.69 Sst tan vfgr vslty m stn yel-gld flu Sst It bm vfgr vslty carb strk m stn yel-gld flu Sst It bm vfgr vslty carb strk m stn yel-gld flu Sst bm vfgr slty rn stn yel-gld flu Sst It bm vfgr slty carb m stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu/Fractured Sst It bm vfgr vslty carb rn stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst tan vfgr vsity carb It stn yel-gld flu Sst tan vfgr vslty carb It stn yel-gld flu Sst It bm vfgr vslty carb sh m stn yel-gld flu Sst it bm vfgr vslty carb m stn yel-gld flu Sst tan vfgr vslty carb it stn yel-gld flu Sst bm vfgr slty sh m-dk mot sin yel-gld flu Sst it bm vfgr slty carb strk m stn yel-gld flu/Fractu~ Sst It bm vfgr slty carb strk m stn yel-gld flu Sst tan vfgr vsity sh strk carb It stn yel-gld flu Sst tan vfgr vslty sh lam carb strk it stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gid flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gid flu Sst bm vfgr slty m-dk mot stn yel-gld flu Page 2 Core Analysis Results ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 - 00082 CORE ANALYSIS RESULTS Permeability and porosity m~sured usl~1400 psig ~-onfinlng pressure. 53 7132.1 1.4 0.56 15.6 20.2 59.9 0.34 80.1 2.70 54 7133.2 2.5 16.0 22.7 58.5 0.39 81.2 2.70 55 7134.6 13. 0,51 16.6 18.9 47.5 0.40 66.5 2.53 56 7135.1 2.5 16.2 22.1 56.5 0,39 78.5 2.69 57 7136.3 5.5 2.3 17.0 22,3 54.7 0.41 77.0 2.69 58 7137.3 4.9 16.6 19.6 56.7 0.35 76.3 2.69 59 7138.1 2.1 1.0 16,0 22.7 56.7 0.40 79.4 2.69 60 7139.1 3.0 16,5 22.9 53.9 0,42 76.7 2.69 61 7140.1 1.9 0.15 14.2 27.1 53.1 0.51 80.2 2.69 62 7141.1 1.1 15.4 22.0 58.4 0.38 80,4 2.68 63 7142,7 1.3 0.44 16.0 22.5 57.1 0.39 79.7 2.71 64 7143.1 2.2 16.0 25.1 51.8 0.48 77,0 2.70 65 7144,2 2.2 0.91 15.4 24,1 55.6 0.43 79.8 2,69 66 7145.2 6.8 17,8 23.9 53.5 0.45 77.4 2.70 67 7146,1 5.0 1.4 16.3 18.2 59.0 0.31 77.3 2.67 68 7147.1 6.6 17.1 19.0 59.1 0.32 78.2 2.70 69 7148,2 1.4 0.79 15.6 20.3 59.4 0.34 79.8 2.69 70 7149.2 4.5 17.4 23.9 51.3 0.47 75.2 2.70 71 7150.1 2.5 1.0 16.2 17.6 58.7 0.30 76.2 2.68 72 7151.2 2.2 12.7 18.7 70.6 0.26 89,3 2.72 73 7153.2 0.43 14,8 19.6 54.6 0.36 74.2 2.67 74 7154.1 2.2 1,1 16.3 17.3 59.3 0.29 76.7 2.70 75 7155.3 1.1 15.4 20.4 59.2 0.34 79.6 2.71 76 71 56.1 3.7 1.8 16.7 19,8 58.6 0.34 78.4 2.69 77 7157.1 0.22 13.4 21.4 59.6 0.36 81.1 2.68 78 7158,2 5.4 0.32 16.5 18.1 58.3 0.31 76.4 2.68 Sst bm vfgr sity m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst tan vfgr vslty v carb It stn yel-gld flu Sst bm vfgr slty m-dk mot stn yet-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty cart) strk m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gid flu Sst bm vfgr slty cart) strk m stn yel-gld flu Sst It bm vfgr slty carb m stn yel-gld flu Sst bm vfgr slty carb m stn yel-gld flu Sst It bm vfgr slty cart) strk rn stn yel-gld flu Sst it bm vfgr slty carb strk rn stn yel-gld flu Sst bm vfgr slty rn stn yel-gld flu Sst bm vfgr slty carb strk m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yei-gld flu Sst It bm vfgr slty carb rn stn yel-gld flu Sst tan vfgr vslty sh lam rn stn yel-gld flu Sst tan vfgr vslty sh strk carb It stn yel-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst It bm vfgr vslty carb strk rn stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst tan vfgr vslty carb m stn yel-gld flu Sst bm vfgr slty cart) strk m-dk mot stn yei-gid flu Page 3 Core Analysis Results ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 -00082 CORE ANALYSIS RESULTS Permeability and porosity measured using 400 pslg c, onflnlng pressure. 79 7159.1 13. 17.4 11.8 64.1 0.18 76.0 2.68 80 7163.7 0.79 10.3 0.0 99.6 0.00 99.6 2,75 81 7167.1 0.72 14.2 17,1 63.9 0.27 81,0 2.70 82 7168,1 5.1 0.23 17,1 21.7 56.9 0.38 78.6 2.69 83 7169,1 3.3 16.4 23,0 56.4 0.41 79.4 2.70 84 7170,2 2.6 0.81 15.6 18.2 61.1 0.30 79.4 2.70 85 7171.1 2.6 15.4 28.0 53.4 0.52 81.3 2.70 86 7172,1 3.0 1.6 15,4 17.5 62.3 0,28 79,8 2.70 87 7173.1 1.7 15.4 32,0 50,2 0.64 82,1 2.69 88 7174.1 3.1 1,6 16.0 29.2 50.4 0.58 79,6 2.70 89 7175,1 5.1 16.6 22.4 55.2 0.40 77.6 2,70 90 7176.1 0.31 0.21 13.9 22,2 57,8 0,38 80.0 2.69 91 7177.1 0.39 14.0 17,5 60.8 0,29 78.3 2.70 92 7178.2 0.039 0.010 10.0 21.2 37.6 0.56 58.9 2.74 93 7179.1 0.20 11,9 24,0 46.2 0.52 70.2 2.74 94 7180.1 0.11 0,082 11.0 21.0 47.0 0,45 68.1 2.74 95 7181.1 0.28 12.5 18.6 53.4 0.35 72.0 2.73 96 7182.1 0,004 0.004 4.9 8.6 69,7 0.12 78.3 2,71 97 7183.3 0.024 7,0 17.7 59.6 0,30 77,3 2.71 98 7184.1 1.9 0.073 13.9 17.9 55.2 0.32 73.0 2,70 99 7185,1 1.t 15.0 18,2 56,5 0.32 74.7 2.72 100 7186,1 1.5 0.72 14,9 17.5 58.3 0.30 75.8 2.70 101 7187.1 3.9 15.9 13.8 62.3 0.22 76.0 2.70 102 7188.5 0.30 0.14 13,8 16.0 66.4 0,24 82.4 2.70 103 7189.1 1.5 15.6 11.9 63.5 0, t9 75.4 2.71 104 7190.1 2.6 1,2 15.8 12.4 65.5 0.19 77,9 2.72 Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sltst gry vfgr sdy sh no stn no flu Sst tan vfgr vslty sh strk carb m stn gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yei-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst bm vfgr slty carb m-dk mot stn yel-gld flu Sst It bm vfgr vslty carb m stn yel-gld flu Sst bm vfgr slty m stn yel-gld flu Sst It tan vfgr vslty calc It stn yel-gld flu Sst it bm vfgr vslty calc m stn yel-gld flu Sst it bm vfgr vslty calc m stn yel-gld flu Sst tan vfgr vslty calc m-It stn yel-gld flu Sst gry-lt tan vfgr vslty calc It sptd stn yel-gld flu Sst It tan vfgr vsity calc It stn yel-wh flu Sst It bm vfgr sity calc m stn yel-gld flu Sst bm vfgr slty calc carb m stn yel-gld flu Sst bm vfgr slty calc carb m-dk mot stn yel-gld flu Sst bm vfgr slty calc dk stn yel-gld flu Sst bm vfgr vslty calc m-dk mot stn yel-gld flu Sst bm vfgr slty calc dk stn yel-gld flu Sst bm vfgr slty calc dk stn yel-gld flu Page 4 Core Analysis Results CORE ANALYSIS RESULTS ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 - 00082 Permeability and porosity measured using 400 psig confining pressure. 105 7191.9 1.0 15.2 t2.9 63.1 0.21 76.0 2.71 Sst bm vfgr slty calc dk stn yel-gld flu 106 7192.1 2.0 0.89 16.2 16.4 57.0 0.29 73.4 2.70 Sst bm vfgr slty calc dk stn yel-gld flu 107 7193.1 2.3 16.2 15.5 60.3 0.26 75.8 2.70 Sst bm vfgr slty calc dk stn yel-gld flu Page 5 Core Analysis Results ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 - 00082 VERTICAL PERMEABILITY I 7072.1 5.6 Sst 3 7074.1 12. Sst 5 7076.1 2.8 Sst 7 7078.1 17. Sst 9 7080.1 3.7 Sst 11 7084.2 1.2 Sst 14 7088.2 4.3 Sst 16 7090.1 1.2 Sst 19 7096.1 1.6 Sst 21 7098.1 0.42 Sst 23 7100.1 4.5 Sst 25 7102.1 1.2 Sst 28 7106.2 0.31 Sst 29 7108.4 0.45 Sst 31 7110.4 0.31 Sst 33 7112.1 0.32 Sst 35 7114.2 0.082 Sst 37 7116.1 0.13 Sst 39 7118.5 6.7 Sst 41 7120.2 0.24 Sst 43 7122.3 0.16 Sst 45 7124.1 1.5 Sst 47 7126.1 3.9 49 7128.2 0.28 51 7130.1 0.59 53 7132.1 0.56 55 7134.6 0.51 bm vfgr slty m stn yel-gid flu bm vfgr slty sh rn stn yel-gld flu bm vfgr sity sh lam carb strk m stn yel-gld flu bm vfgr slty m stn yei-gld flu bm vfgr slty shm stn yel-gld flu bm vfgr slty rn stn yel-gld flu bm vfgr sity m stn yet-gld flu bm vfgr slty sh strk m stn yel-gld flu bm vfgr slty m stn yel-gld flu It bm vfgr sity m stn yel-gld flu bm vfgr slty m-dk mot stn yel-gld flu It bm vfgr vslty sit strk carb m stn yel-gld flu It bm vfgr vslty cart) strk m stn yel-gld flu it bm vfgr vslty carb strk m stn yel-gld flu It bm vfgr slty carb m stn yel-gld flu it bm vfgr vslty carb m stn yel-gtd flu tan vfgr vslty carl:) tt stn yel-gld flu It bm vfgr vsity carb shm stn yel-gld flu tan vfgr vslty carb It stn yel~gid flu It bm vfgr slty carb strk m stn yel-gld flu tan vfgr vslty sh strk carb it stn yel-gld flu brn vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yei-gld flu Sst bm vfgr slty m-dk mot stn yet-gld flu Sst bm vfgr slty m-dk mot stn yel-gld flu Sst bm vfgr slty m-dk mot stn yei-gld flu Sst tan vfgr vsity v carb It stn yel-gld flu Page 6 VERT, PERMEABtUTY ARCO ALASKA, INC. "NANUK" 2 COLViLLE DELTA FIELD 57 59 61 63 65 67 69 71 74 76 78 82 84 86 88 90 92 94 96 98 100 102 104 106 CL File No.: 57111 - 00082 VERTICAL PERMEABILITY 7136.3 2.3 Sst 7138.1 1.0 Sst 7140.1 0.15 Sst 7142.7 0.44 Sst 7144.2 0.91 Sst 7146.1 1.4 Sst 7148.2 0.79 Sst 7150.1 1.0 Sst 7154.1 1.1 Sst 7156.1 1.8 Sst 7158.2 0.32 Sst 7168.1 0.23 Sst 7170.2 0.81 Sst 7172.1 1.6 Sst 7174.1 1.6 Sst 7176.1 0.21 Sst 7178.2 0.010 Sst 7180.1 0.082 Sst 7182.1 0.004 Sst 7184.1 0.073 Sst 7186.1 0.72 Sst 7188.5 0.14 Sst 7190.1 1.2 Sst 7192.1 0.89 Sst i, , · bm vfgr sity m-dk mot stn yel-gld flu bm vfgr slty carb strk m-dk mot stn yel-gld flu bm vfgr slty cart) strk m stn yei-gld flu bm vfgr slty carb rn stn yel-gld flu It bm vfgr slty carb strk m stn yel-gld flu brn vfgr slty carb strk m-dk mot stn yel-gld flu bm vfgr slty m-dk mot stn yel-gld flu It bm vfgr slty carb m stn yel-gld flu bm vfgr slty m-dk mot stn yel-gld flu bm vfgr sity carb m-dk mot stn yel-gld flu bm vfgr slty carb strk m-dk mot stn yel-gld flu bm vfgr sity carb m-dk mot stn yel-gid flu bm vfgr sity carb m-dk mot stn yel-gld flu bm vfgr slty carb m-dk mot stn yel-gld flu bm vfgr slty carb m-dk mot stn yel-gld flu It bm vfgr vslty carl3 rn stn yel-gld flu it tan vfgr vslty calc It stn yel-gld flu tt bm vfgr vsity calc m stn yel-gld flu gry-it tan vfgr vslty calc It sptd stn yel-gld flu It bm vfgr sity calc m stn yel-gid flu bm vfgr slty calc carb m-dk mot stn yel-gld flu bm vfgr vstty calc m-dk mot stn yel-gld flu bm vfgr slty caic dk stn yet-gld flu bm vfgr slty calc dk stn yel-gld flu Page 7 VERT. PERMEABILITY ARCO ALASKA, INC. "NANUK" 2 · i COLVILLE DELTA FIELD HYDRAULIC UNITS 7072.1 0.7582 0.160 10 7073.1 1.0809 0.219 11 7074.1 1.3367 0.308 11 7075.1 0.6329 O. 115 10 7076.1 1.2450 0.273 11 7077.1 0.9781 0.212 11 7078.1 1.4309 O. 334 11 7079.1 0.9050 0.184 10 7080.1 0.9063 0.198 10 7083,8 0.5255 O. 104 9 7084.2 0.5938 0.120 10 7085.5 0.4016 0.072 9 7087.3 1.2584 0.276 11 7088.2 0.9737 0,207 11 7089.2 0.9018 0.179 10 7090.1 0,7782 0.138 10 7091,2 1.1263 0.239 11 7095.1 0.4183 0.078 9 7096.1 0,6578 0.129 10 7097.2 0.5108 0.093 9 7098.1 0.5007 0.089 9 7099.1 0.6380 0.121 10 7100.1 0.9989 0.209 11 7101.1 0.9901 0.207 11 7102.1 0.3991 0.067 9 7103.1 0.8218 0.165 10 CL File No.: 57111 - 00082 Unit . i':;(~):i::.!- Indicator :index 7178.2 0.1769 0,020 7 7182.1 0.1755 0.009 7 7105.1 0.3178 0.055 8 7110.4 0.3381 0.060 8 7114.2 0.2417 0.033 8 7115.2 0.3172 0.041 8 7116.1 0.2778 0.047 8 71t7.8 0.2401 0.037 8 7153.2 0.3111 0.054 8 7157.1 0.2599 0.040 8 7t76.1 0.2905 0.047 8 7177.1 0.3240 0.053 8 7179.1 0.3013 0.041 8 7180.1 O. 2589 0.032 8 7181.1 0.3269 0.047 8 7183.3 0.2423 0.018 8 7188.5 0.2901 0.046 8 7083.8 0.5255 O. 104 9 7085.5 0.4016 0.072 9 7095.1 0.4t83 0.078 9 7097.2 0.5108 0.093 9 7098.1 0.5007 0.089 9 7102.1 0.3991 0.067 9 7106.2 0.4463 0.078 9 7108.4 0.4615 0.083 9 7112.1 0.3478 0.063 9 Page 8 HYDRAULIC UNITS ARCO ALASKA, INC. "NANUK" 2 COLVlLLE DELTA FIELD HYDRAULIC UNITS 7105.1 0,3178 0,055 8 7106.2 0,4463 0.078 9 7108.4 0.4615 0.083 9 7109.1 1.5215 0.346 11 7110.4 0.3381 0,060 8 7111.1 3.0141 0.569 13 7112.1 0.3478 0,063 9 7113.1 0.7187 0.143 10 7114.2 0.2417 0.033 8 7115.2 0,3172 0.041 8 7116.1 0.2778 0.047 8 7117.8 0.2401 0.037 8 7118.5 1.0084 0.190 11 7119.2 0.5812 0,113 10 7120.2 3.2228 0,603 13 7121,1 0.5802 0.107 10 7122.3 0.4009 0,065 9 7123.1 0.4910 0.085 9 7124.1 0.6851 0.130 10 7125.2 0.6558 0.128 10 7126,1 0.8996 0.192 10 7127,1 0.7847 0.162 10 7128.2 0.4067 0.070 9 7129.2 0.7559 0,151 10 7130.1 0.4993 0.089 9 7131,3 0.6060 0.114 10 CL File No.: 57111 -00082 ~QUali~ unit 7122.3 0.4009 0.065 9 7123.1 0.4910 0.085 9 7128.2 0.4067 0.070 9 7130,1 0.4993 0.089 9 7132.1 0.4995 0.092 9 7141.1 0.4560 0.083 9 7142,7 0.4793 0,091 9 7148.2 0,5131 0,095 9 7155.3 0.4583 0.083 9 7167,1 0.4260 0.071 9 7173.1 0.5744 0.105 9 7185.1 0.4812 0.085 9 7186.1 0.5635 0.099 9 7189.1 0.5368 0.099 9 7191,9 0,4491 0,081 9 7192.1 0,5662 0.109 9 7072.1 0.7582 0.160 10 7075,1 0,6329 0,115 10 7079.1 0,9050 0,184 10 7080,1 0.9063 0,198 10 7084.2 0.5938 0,120 10 7089.2 0.9018 0.179 10 7090.1 0.7782 0.138 10 7096.1 0.6578 0.129 10 7099.1 0,6380 0.121 10 7103.1 0,8218 0.165 10 Page 9 HYDRAUUC UNITS ARCO ALASKA, INC. "NANUK" 2 COLVlLLE DELTA FIELD HYDRAULIC UNITS 7132.1 0.4995 0.092 9 7133.2 0.6575 0,125 10 7134.6 1,4111 0.281 11 7135.1 0.6442 0.125 10 7136.3 0.8687 0.178 10 7137.3 0,8612 0.171 10 7138,1 0,5943 0.113 10 7139,1 0,6772 0.134 10 7140,1 0.6981 0,116 10 7141,1 0,4560 0.083 9 7142.7 0.4793 0,09t 9 7143.1 0.6063 0.116 10 7144,2 0,6578 0.120 10 7145.2 0,8984 0.194 10 7146.1 0,8923 0.174 10 7147.1 0,9461 0.195 10 7148,2 0.5131 0.095 9 7149.2 0,7566 0.159 10 7150.1 0.6304 0,122 10 7151,2 0.8920 0.130 10 7153,2 0.3111 0,054 8 7154.1 0.5854 0,114 10 7155.3 0.4583 0.083 9 7156.1 0.7415 0.149 10 7157.1 0.2599 0.040 8 7158.2 0.9059 0.179 10 CL File No.: 57111 - 00082 7113,1 0.7187 0.143 10 7119.2 0.5812 0.113 10 7121.1 0.5802 0.107 10 7124.1 0.6851 0.130 10 7125.2 0.6558 0.128 10 7126.1 0,8996 0.192 10 7127.1 0.7847 0.162 10 7129.2 0.7559 0,151 10 7131.3 0.6060 0.114 10 7133.2 0,6575 0.125 10 7135.1 0,6442 0,125 10 7136.3 0,8687 0.178 10 7137,3 0.8612 0.171 10 7138.1 0.5943 0,113 10 7139.1 0,6772 0.134 10 7140.1 0.6981 0.116 10 7143.1 0.6063 0.116 10 7144.2 0.6578 0.120 10 7145.2 0.8984 O. 194 10 7146.1 0,8923 0.174 10 7147.1 0,9461 0.195 10 7149.2 0,7566 0.159 10 7150. I 0.6304 0.122 10 7151,2 0.8920 0,130 10 7154.1 0,5854 0.114 10 7156,1 0,7415 0.149 10 Page 10 HYDRAUUC UNITS ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 - 00082 HYDRAULIC UNITS 7159.1 1.3037 0.275 11 7163.7 0.7563 0.087 10 7167.1 0.4260 0.071 9 7168.1 0.8323 0.171 10 7169.1 0.7201 0.141 10 7170.2 0.6900 0.128 10 7171.1 0.7094 0.129 10 7172.1 0.7593 0.138 10 7173.1 0,5744 0.105 9 7174.1 0.7252 0.139 t0 7175.1 0.8794 O. 175 10 7176.1 0.2905 0.047 8 7177.1 0.3240 0.053 8 7178.2 0.1769 0.020 7 7179.1 0.3013 0,041 8 7180. t 0.2589 0.032 8 7181.1 0.3269 0.047 8 7182.1 0.1755 0.009 7 7183,3 0.2423 0.018 8 7184.1 0.7313 0.118 10 7185.1 0.4812 0.085 9 7186.1 0.5635 0.099 9 7187.1 0.8244 0.156 10 7188.5 0.2901 0.046 8 7189.1 0.5368 0.099 9 7190.1 0.6848 0.128 10 7158.2 0.9059 0.179 10 7163.7 0.7563 0.087 10 7168.1 0.8323 0.171 10 7169.1 0,7201 0.141 10 7170.2 0.6900 0,128 10 7171.1 0.7094 0.129 10 7172.1 0.7593 0.138 10 7174.1 0,7252 0.139 10 7175.1 0.8794 0.175 10 7184.1 0.7313 0.118 10 7187. t 0.8244 0.156 10 7190.1 0.6848 0.128 10 7193.1 0.6151 0.119 10 7073.1 1.0809 0.219 11 7074,1 1.3367 0.308 11 7076.1 1.2450 0.273 11 7077.1 0.9781 0.212 11 7078.1 1.4309 0.334 11 7087.3 1.2584 0.276 11 7088.2 0.9737 0.207 11 7091.2 1.1263 0.239 11 7100.1 0.9989 0.209 11 7101.1 0.9901 0.207 11 7109.1 1.5215 0.346 11 7118,5 1.0084 0.190 11 7134.6 1.4111 0.281 11 Page 11 HYDRAULIC UNITS ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD HYDRAULIC UNITS ~ : ~i~ : SORTED BY SAMPLE DEPTH:~ ~i: ~" DeP;~h ~,ii~ ~Fi~W' ~ ''~ ReserV6ir ! HYdrauli~i ~ i~ zonel i~ ~ Quality~ Unitl iI i~ (fi) ,~?ndiC~Or' ; Inde; ii , 719t .9 0.4491 0.081 9 7192.1 0.5662 0.109 9 7193, t 0.6t51 0.119 10 CL File No. · 57111 - 00082 ' ~ SORTED 'BY HYD. UNIT , iDePth FlOW Reservoir Hydraulic i ~ft ~ Zone Quality Unit i: i (,) i indiC~t°r Index 7159.1 1.3037 0.275 11 7t11.1 3.0141 0.569 13 7120.2 3.2228 0.603 13 Page 12 HYDRAULIC UNITS ARCO ALASKA, INC. CL File No.: 57111 - 00082 'NANUK" 2 COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Kiinkenberg (gas slippage) corrected permeability I 7072.0 4.1 3.3 2 7072.2 5.4 4.4 3 7072.4 8.7 7.2 4 7072.6 6.4 5.2 5 7072.8 7.7 6.3 6 7073.0 3.6 2.9 7 7073.2 0.13 0.067 8 7073.4 0.89 0.62 9 7073.6 0.19 0.10 10 7073.8 1.4 1.0 11 7074.0 4.8 3.9 12 7074.2 7.1 5.8 13 7074.5 14. 12. 14 7074.6 3.1 2.4 15 7074.8 3.3 2.5 16 7075.1 7.5 6.2 17 7075.2 0.61 0.41 18 7075.4 0.29 0.18 19 7075.6 4.6 3.7 20 7075.8 3.8 3.0 21 7076.0 6.9 5.6 22 7076.2 0.97 0.68 23 7076.4 4.7 3.8 24 7076.6 4.7 3.7 25 7076.8 3.0 2.3 26 7077.0 9.4 7.8 Page 13 Profile Permeameter ARCO ALASKA, INC. CL File No.: 57111 -00082 "NANUK" 2 · . ~ COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) corrected permea~ 27 7077.2 4.7 3,8 28 7077.4 1,7 1.3 29 7077.6 0.006 0.001 30 7077.8 0.45 0.29 31 7078,1 6.6 5.4 32 7078.2 5.4 4.3 33 7078.4 6.0 4.8 34 7078.6 6.9 5,6 35 7078.8 2,4 1.8 36 7079.0 8.2 6.8 37 7079,2 2.4 1,8 38 7079.4 1.5 1,1 39 7079.6 2.7 2.1 40 7079.8 3.3 2.5 41 7080,0 4,1 3.2 42 7080.2 2.5 1.9 43 7080.4 5.7 4.6 44 7080.6 51. 47. 45 7080.8 0.54 0.35 46 7081.0 0,017 0.004 47 7081.2 0.95 0.67 48 7081,4 0.17 0.095 49 7081.7 0.012 0,003 50 7081.8 0.18 0.097 51 7082.0 2.5 1.9 52 7082.2 0,030 0,010 Page 14 Profile Permeameter ARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUK" 2 . COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage)~ per--fy 53 7082.4 4.0 3.1 54 7082.6 0.66 0.45 55 7082.8 0.039 0.015 56 7083.0 0,80 0.55 57 7083.2 0.080 0.037 58 7083.4 0.27 0.16 59 7083.6 2.0 1.5 60 7083.8 0.97 0.69 61 7084.1 0.90 0.63 62 7084.2 1.9 1.4 63 7084.4 2.0 1.5 64 7064.6 0.99 0.70 65 7084.8 0.19 0.10 66 7085.0 1.8 1.4 67 7085.2 0.16 0.085 68 7085.4 0.33 0.20 69 7085.6 0.17 0.089 70 7085.8 0.45 0.29 71 7086,0 6.2 5.0 72 7086.2 0.52 0.34 73 7086.4 0.33 0.21 74 7086.6 1.6 1.2 75 7086.8 1.2 0.88 76 7087.1 8.7 7.2 77 7087.2 7.2 5.9 78 7087.4 2.9 2.2 Page 15 Profile Permeameter ARCO ALASKA, INC. CL File No.: 57111 - 00082 'NANUK" 2 COLVILLE DELTA FIELD PROFILE PERMEAMETER. RESULTS * Klinkenberg (gas slippage) corrected permeability 79 7087.6 2.4 1.8 80 7087.8 1.8 =1.3 81 7088.0 4.0 3.2 82 7088.2 0.69 0.47 83 7088.4 5.0 4.0 84 7088.6 4.5 3.5 85 7088.8 4.9 3.9 86 7089.0 0.008 0.002 87 7089.2 2.7 2.0 88 7089.4 2.7 2.1 89 7089,6 0,88 0.62 90 7089.8 0.34 0.21 91 7090.0 0.93 0.64 92 7090.2 4.0 3.2 93 7090.4 0.028 0.010 94 7090.6 0.74 0.51 95 7090.8 0.40 0.25 96 7091.0 5.7 4.6 97 7091.2 4.2 3.3 98 7091.4 1.3 0.92 99 7091.6 0.49 0.32 100 7091.8 3.8 3.0 101 7092.0 0.83 0.58 102 7092.2 3.5 2.7 103 7092.4 2.6 2.0 104 7092.6 3.1 2.4 Page 16 Profile Permeameter ARCO ALASKA, INC. "NANUK" 2 · . COLVILLE DELTA FIELD CL File No.: 57111 - 00082 PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) corrected permeability 105 7092.8 0.073 0,033 106 7093,0 0,020 0,006 107 7093.3 0.064 0.028 108 7093.4 0.24 0.14 109 7093.6 0.022 0,007 110 7093.8 0.13 0.068 t 11 7094.0 0.14 0.076 112 7094.2 0.013 0,003 113 7094.4 0,019 0,006 114 7094.6 0.24 0.14 115 7094.8 0.73 0.50 116 7095.0 0.27 0.16 117 7095.2 0.67 0.45 118 7095.4 20. 18. 119 7095.6 0.14 0.071 120 7095.8 1.9 1.4 121 7096.0 1.8 1.4 122 7096.2 1.4 1.0 123 7096.4 1.3 0.91 124 7096.6 0.62 0.41 125 7096.8 0.49 0.32 126 7097.0 0.74 0.51 127 7097.2 0.52 0.34 128 7097.4 2.9 2.2 129 7097.6 4.9 3.9 130 7097.8 0.78 0.53 Page 17 Profile Permeameter . ARCO ALASKA, INC. CL File No. ' 57111 - 00082 "NANUK" 2 · COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas sHppaoe) con'acted permeability 131 7098.0 0.055 0.023 132 7098.2 4.6 3.6 133 7098,4 0.14 0.071 134 7098.6 0.39 0.25 135 7098.8 0,38 0.24 136 7099,1 1.7 1.3 137 7099,2 0.88 0.61 138 7099,4 O. 79 O. 55 139 7099.6 1,7 1.3 140 7099.8 1,9 1.4 141 7100.0 3.8 3.0 142 7100.2 5.0 4.0 143 7100.4 2.3 1.7 144 7100.6 2,1 1,6 145 7100.8 2.1 1.6 146 7101,0 5,0 4.0 147 7101.2 3.9 3.0 148 7101.4 3.0 2.3 149 7101.6 1.6 1.2 150 7101.8 2,0 1.5 151 7102.0 0.97 0.68 152 7102.2 0.22 0.13 153 7102,4 2.7 2.1 154 7102.6 4.1 3.2 155 7t02.8 1.1 0.76 156 7103.0 1.3 0.97 Page 18 Profile Permeameter ARCO ALASKA, INC. CL File No. · 57111 - 00082 'NANUK" 2 . COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * ~.kenberg (gas s#ppage) corrected 157 7103.2 2.1 1.6 158 7103.4 1.5 1.1 159 7103.6 1.3 0.9t 160 7103.8 3.0 2.3 161 7104.0 0.63 0.42 162 7104.2 0.055 0.023 163 7104.4 0.48 0.31 164 7104.6 0.007 0.001 165 7104.8 0.022 0.007 166 7105.0 0.20 O. 11 167 7105.2 0.54 0.36 168 7105.4 0.10 0.051 169 7105.6 3.5 2.7 170 7105.8 0.052 0.021 171 7106.0 0.63 0.43 172 7106.2 O. 12 0.061 173 7106.4 0.94 0.66 174 7106.6 0.87 0.60 175 7106.8 0.85 0.59 176 7107.0 0.063 0.027 t77 7107.2 0.37 0.23 178 7107.4 2.5 1.9 179 7107.6 3.4 2.6 180 7107.8 0.12 0.057 181 7108.0 1.2 0.89 182 7108.2 1.3 0.98 Page 19 Profile Permeameter ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No. · 57111 - 00082 PROFILE PERMEAMETER RESULTS * Klinkeflberg (gas slippage) corrected permeability 183 7108.4 0.23 0.14 184 7108.6 42. 38. 185 7108.8 9.8 8.2 186 7109.0 9.1 7.5 187 7109.2 4.6 3.7 188 7109.4 3.6 2.8 189 7109.6 1.7 1.2 190 7109.8 3.9 3.1 191 7110.0 0.049 0.020 192 7110.2 0.76 0.52 193 7110.4 0.28 0.17 194 7110.6 0.25 0.15 195 7110.8 0.74 0.51 196 7111.0 0.84 0.59 197 7111.2 1.0 0.73 198 7111.4 0.49 0.32 199 7111.6 0.12 0.062 200 711t .8 0.15 0.082 201 7112.0 0.43 0.27 202 7112.2 0.35 0.22 203 7112.4 0.47 0.30 204 7112.6 0.51 0.34 205 71 t2.8 1.1 0.76 206 7113.0 1.3 0.94 207 7113.2 1.1 0.78 208 7113.4 0.32 0.19 Page 20 Profile Permeameter ARCO ALASKA, INC. "NANUK" 2 · COLVILLE DELTA FIELD CL File No. · 57111 - 00082 PROFILE PERMEAMETER RESULTS * Klinkenberg {gas slippage) corrected permeability 209 7113.6 0.24 0.14 210 7113.8 0.10 0.051 211 71t4.0 0.15 0.082 212 7114.2 1.8 1.4 213 7114.4 0.24 0.14 214 7114.6 0.20 0.11 215 7114.8 0.16 0.087 216 7115.0 0.14 0.071 217 7115.2 0.20 0.12 218 7115.4 0.27 0.16 219 7115.6 0.34 0.21 220 7115.8 0.075 0.034 221 7116.0 0.14 0.073 222 7116.2 0.019 0.006 223 7116.4 0.35 0.21 224 7116.6 0.18 0.10 225 7116.8 0.11 0.052 226 7117.0 0.13 0.066 227 7117.2 0.029 0.010 228 7117.4 0.24 0.14 229 7117.6 0.23 0.14 230 7117.8 0.10 0.050 231 7118.0 0.007 0.002 232 7118.2 1.0 0.71 233 7118.4 0.18 0.10 234 7118.6 0.26 0.15 Page 21 Profile Permearneter ARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUK" 2 .... COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas s#ppage) corrected permeability 235 7118.8 0.76 0.52 236 7119.0 0.79 0.54 237 7119.2 1.5 1.1 238 7119.4 0.010 0.002 239 7119.6 0.066 0.029 240 7119.8 0.11 0.054 241 7120.0 1.5 1.1 242 7120.2 0.19 0.10 243 7120.4 O. 15 0.082 244 7120.6 0.062 0.027 245 7120.8 1.5 1.1 246 7121.0 0.29 0.18 247 7121.2 1.8 1.4 248 7121.4 0.91 0.64 249 7121.6 1.1 0.76 250 7121.8 0.029 0.010 251 7122.1 0.45 0.29 252 7122.2 0.38 0.24 253 7122.4 0.18 0.098 254 7122.6 1.4 0.99 255 7122.8 0.27 0.16 256 7123.0 1.2 0.86 257 7123.2 0.77 0.53 258 7123.4 1.2 0.85 259 7123.6 0.58 0.39 260 7123.8 0.66 0.45 Page 22 Profile Pemteameter ARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUK" 2 COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Kl~nkenberg (gas slippage) corrected permeability 261 7124.0 1.5 1,1 262 7124.2 2.1 t.6 263 7124,4 4.6 3.7 264 7124,6 4.5 3.6 265 7124.8 5.5 4.4 266 7125.0 3.3 2.6 267 7125.2 3.8 3.0 268 7125.4 4.7 3.7 269 7125.6 3.1 2.4 270 7125.8 2.9 2.3 271 7126.0 2,0 1.5 272 7126.2 4.3 3.4 273 7126.4 3.3 2.6 274 7126.6 4.4 3.5 275 7126.8 0,79 0.54 276 7127.0 1.1 0,77 277 7127,2 2.0 1.5 278 7127.4 2,8 2.2 279 7127,6 5.0 4.0 280 7127.8 0.33 0.21 281 7128.0 0.58 0.38 282 7128.2 0.25 0.15 283 7128.4 0.097 0,047 284 7128.7 0,65 0.44 285 7128.8 1.0 0.74 286 7129,0 2.5 1.9 Page 23 Profile Permeameter ARCO ALASKA, INC, "NANUK" 2 COLVlLLE DELTA FIELD CL File No.: 57111 - 00082 PROFILE PERMEAMETER RESULTS * Klinkenberg (~as slippage) corrected I~,¢meabllity 287 7129.2 1.2 0.83 288 7129.4 2.0 1.5 289 7129.6 0.16 0.087 290 7129.8 0.74 0.51 291 7130.0 0.95 0.67 292 7130.2 0.82 0.57 293 7130.4 0.038 0.014 294 7130.6 0.61 0.41 295 7130.8 0.37 0.23 296 7131.0 0.59 0.39 297 7131.2 1.1 0.81 298 7131.4 1.1 0.82 299 7131.6 0.86 0.60 300 7131.8 0.47 0.31 301 7132.0 1.1 0.77 302 7132.2 2.3 1,7 303 7132,4 2.0 1.5 304 7132.6 2,1 1.6 305 7132.8 0.56 0.37 306 7133.0 1.1 0.76 307 7133.2 2.0 1.5 308 7133.4 0.33 0.20 309 7133.6 0.51 0.34 310 7133.8 3.5 2.7 311 7134.0 9.6 8.0 312 7134.2 0.22 0.12 Page 24 Profile Permeameter . ARCO ALASKA, INC. CL File No. ' 57111 - 00082 "NANUK" 2 · ~ · COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) con'ected permeability 313 7134.4 0.85 0.59 314 7134.6 1.7 1.3 315 71 34.8 O. 14 0.072 316 7135.1 2.3 1.8 317 7135.2 2.3 1.7 318 7135.4 0.12 0.061 319 7135.8 0.16 0.089 320 7136.0 O. 15 0.083 321 7136.2 0.60 0.40 322 7136.4 3.1 2.4 323 7136.6 3.3 2.6 324 7136.8 4.4 3.5 325 7137.0 4.2 3.3 326 7137.2 2.7 2.1 327 7137.4 3.0 2.4 328 7137.6 2.5 1.9 329 7137.8 2.8 2.1 330 7138.0 3.7 2.9 331 7138.2 2.4 1.8 332 7138.4 1.4 1.0 333 7138.6 1.7 1.3 334 7138.8 2.5 1.9 335 7139.0 1.1 0.80 336 7139.2 1.3 0.92 337 7139.4 0.65 0.43 338 7139.6 21. 18. Page 26 Profile Permeameter ARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUtC' 2 COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) corrected permeability 339 7139.8 0.43 0.27. 340 7140.0 1.8 1.4 341 7140.2 6.6 5.3 342 7140.4 0.49 0.32 343 7t40.6 0.007 0.002 344 7140.8 0.73 0.50 345 7141.1 1.4 1.0 346 7141.2 0.92 0.65 347 7141.4 0.23 0.13 348 7141.6 0.14 0.071 349 7141.8 0.43 0.27 350 7'I42.1 0.022 0.007 351 7142.2 1.7 1.3 352 7142.4 0.98 0.69 353 7142.6 0.63 0.42 354 7142.8 0.40 0.25 355 7143.0 0.54 0.35 356 7143.2 0.70 0.48 357 7143.4 0.17 0.090 358 7143.6 3.0 2.3 359 7143.8 2.5 1.9 360 7144.0 1.6 1.2 361 7144.2 0.35 0.22 362 7144.4 1.3 0.95 363 7144.6 4.2 3.3 364 7144.8 1.2 0.85 Page 26 Profile Permeameter ARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUK" 2 COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) corrected permeability 365 7145.0 3.9 3.1 366 7145.2 5.6 4.5 367 7145.4 5.7 4.5 368 7145.6 3.9 3.0 369 7145.8 2.9 2.2 370 7146.0 5.1 4.1 371 7146.2 0.33 0.20 372 7146.4 1.4 1.1 373 7146.6 0.91 0.64 374 7146.8 6.8 5.5 375: 7147.0 3.0 2.3 376 7147.2 4.1 3.2 377 7147.4 9.9 8.2 378 7147.6 2.5 1.9 379 7147.8 1.3 0.94 380 7148.0 7.3 5.9 381 7148.2 0.81 0.56 382 7148.4 0.47 0.30 383 7148.6 0.49 0.32 384 7148.8 2.0 1.5 385 7149.0 1.7 1.3 386 7149.2 3.2 2.5 387 7149.4 5.4 4.3 388 7149.6 3.8 3.0 389 7149.8 1.9 1.4 390 7150.1 1.3 0.90 Page 27 Profile Permeameter ARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUK' 2 COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) con'acted permeability 391 7150.2 1.7 1.3 392 7150.4 0.40 0.25 393 7150.6 0.71 0.48 394 7150.8 0.44 0.28 395 7151.0 0.024 0.008 396 7151.2 2.3 1.7 397 7151.4 0.23 0.13 398 7151.6 0.27 0.16 399 7151.8 0.044 0.017 400 7152.0 1.4 1.1 401 7152.2 0.046 0.018 402 7152.4 0.064 0.028 403 7152.6 0.027 0.009 404 7152.8 0.019 0.005 405 7153.0 0.015 0.004 406 7153.2 O. 18 0.096 407 7153.4 1.1 0.76 408 7153.6 0.72 0.49 409 7153.8 2.2 1.7 410 7154.0 0.59 0.39 411 7154.2 0.62 0.42 412 7154.4 0.41 0.26 413 7154.6 0.26 0.15 414 7154.8 1.5 1.1 415 7155.0 1.5 1.1 416 7155.2 O. 13 0.068 Page 28 Profile Permeameter ARCO ALASKA, INC, "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 -00082 PROFILE PERMEAMETER RESULTS * Klinkeflberg (gas slippage) correct~ permeabii~ 417 7155,4 0,15 0,081 418 7155.6 2.5 1.9 419 7155.8 1.4 1.0 420 7156.1 3.3 2.6 421 7156.2 7.9 6.5 422 7156.4 0.52 0.34 423 71 56.6 0,11 0.057 424 71 56.8 0.37 0.23 425 7157,0 0.91 0.64 426 7157.2 0,065 0.028 427 7157.4 0.16 0,086 428 7157.6 1.4 1,0 429 7157.8 1.1 0.75 430 7158,0 0.005 0.001 431 7158,2 0,13 0.066 432 7158.4 0.43 0.27 433 7158.6 0.083 0.039 434 7158.8 0.46 0.30 435 7159.0 15. 12. 436 7159.3 0.50 0.33 437 7159.4 0.40 0.25 438 7159.7 0,026 0.009 439 7159.8 0.054 0.022 440 7160.0 0.074 0.033 441 7160,2 0.067 0,030 442 7160.4 0.51 0.33 Page 29 Profile Permeameter ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 - 00082 PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) corrected permeability 443 7160.6 0.37 0.23 444 7160.8 0.47 0.31 445 7161.3 1,7 1.2 446 7162.5 1.2 0.83 447 7162.6 0.023 0.007 448 7162.8 1,0 0.73 449 7163.0 0.19 0.11 450 7163.3 2.8 2.1 451 7163.5 3.5 2.7 452 7163.6 0.080 0.037 453 7163.8 0.67 0.46 454 7164.0 0.16 0.084 455 7164,3 0.11 0,057 456 7164.4 0.53 0,35 457 7164.6 0.12 0.061 458 7164.8 0.85 0,59 459 7165.0 0.026 0.009 460 7165.2 0.19 0.10 461 7165.4 0.087 0.041 462 7165.7 0.023 0.007 463 7165.8 0.33 0.20 464 7166.0 0.038 0.014 465 7166.2 0.052 0.022 466 7166.4 0.31 0.19 467 7166.6 0.019 0.006 468 7166.8 3,1 2.4 Page 30 Profile Permeameter AARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUK" 2 · COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) corrected permeability 469 7167.0 0.37 0.23 470 7167.3 0.087 0.041 471 7167.4 0.024 0,008 472 7167.6 1.4 1.0 473 7167.8 0.050 0.021 474 7168.1 2.1 1.6 475 7168,2 5.2 4,1 476 7168.4 4.2 3,3 477 7168.6 3,8 3.0 478 7t68,8 1.6 1,2 479 7169.0 2.1 1.5 480 7169.2 2.8 2.1 481 7169.4 1.6 1.2 482 7169.6 1.2 0.84 483 7169.8 0.17 0.095 484 7170.0 0.78 0.53 485 7170.2 1.6 1.2 486 7170,4 3.8 3.0 487 7170.6 1.3 0.95 488 7170.8 4.3 3.4 489 7171.0 1.8 1.4 490 7171.2 1.9 1.5 491 7171.4 2.8 2,1 492 7171.6 4.5 3.5 493 7171.8 1,4 0.99 494 7172.0 2.9 2,3 Page 31 Profile Permeameter . ARCO ALASKA, INC. "NANUK" 2 · COLVlLLE DELTA FIELD CL File No. · 57111 -00082 PROFILE PERMEAMETER RESULTS * Klinkenberg (gas slippage) co~'ected permeability 495 7172.2 0.62 0.42 496 7172.4 1.4 1.0 497 7172.6 2.8 2.2 498 7172.8 3.7 2.9 499 7173.0 1.5 1.1 500 7173.2 1.1 0.79 501 7173.4 2.2 1.7 502 7173.6 1.7 1.3 503 7173.8 1.7 1.3 504 7174.0 3.4 2.6 505 7174.2 2.6 2.0 506 7174.4 1.5 1.1 507 7174.6 1.7 1.3 508 7174.8 1.2 0.87 509 7175.0 2.8 2.1 510 7175.2 1.2 0.84 511 7175.4 1.4 1.0 512 7175.6 1.2 0.82 513 7175.8 1.8 1.3 514 7176.1 0.12 0.057 515 7176.2 0.26 0.15 516 7176.4 0.063 0.027 517 7176.6 0.32 0.20 518 7176.8 0.29 0.17 519 7177.0 0.064 0.028 520 7177.3 0.78 0.54 Page 32 Profile Permeameter . ARCO ALASKA, INC. "NANUK" 2 COLVILLE DELTA FIELD CL File No.: 57111 - 00082 PROFILE PERMEAMETER RESULTS * K#nkenberg (gas slippage) corrected permeability 521 7178.0 0.021 0.006 522 7178.2 0.035 0.013 523 7178.4 0.13 0.064 524 7178.6 0.088 0.041 525 7178.8 0.13 0.064 526 7179.0 0.13 0.067 527 7179.2 0.10 0.050 528 7179.4 0.16 0.084 529 7179.6 0.29 0.17 530 7179.8 0.10 0.051 531 7180.1 0.12 0.055 532 7180.2 0.13 0.069 533 7180.4 0.11 0.055 534 7180.6 0.19 0.11 535 7180.8 0.26 0.15 536 7181.0 0.46 0.30 537 7181.2 0.21 0.12 538 7181.4 0.22 O. 12 539 7181.6 0.092 0.044 540 7181.8 0.010 0.002 541 7182.0 0.009 0.002 542 7182.2 0.017 0.005 543 7182.4 O.011 0.002 544 7182.6 0.009 0.002 545 7182.8 0.025 0.008 546 7183.0 0.11 0.056 Page 33 Profile Permeameter ARCO ALASKA, INC. CL File No.: 57111 - 00082 "NANUK" 2 COLVILLE DELTA FIELD PROFILE PERMEAMETER RESULTS ' Klinkenb~g (gas slipl;g~) corr~:t~ i~rmeabtli~ 547 7183.2 0.050 0.020 548 7183.4 0.032 0.011 549 7183.6 0.064 0.028 550 7183.8 0.088 0.042 551 7184.0 0.059 0.025 552 7184.2 0.34 0.21 553 7184.4 2.0 1.5 554 7184.7 1.4 0.99 555 7184.8 0.96 0.68 556 7185.0 1.4 0.98 557 7185.2 0.76 0.52 558 7185.4 1.0 0.73 559 7185.6 1.2 0.83 560 7185.8 1.9 1.5 561 7186.1 t.7 1.3 562 7186.2 1.3 0.97 563 7186.4 1.5 1.1 564 7186.6 1.9 1.5 565 7186.8 2.8 2.2 566 7187.0 3.0 2.3 567 7187.2 2.5 1.9 568 7187.4 0.063 0.027 569 7188.0 0.29 O. 18 570 7188.2 4.1 3.3 571 7188.4 0.42 0.27 572 7188.6 2.2 1.7 Page 34 Profile Permeameter ARCO ALASKA, INC. CL File No. · 57111 - 00082 "NANUK" 2 · . COLVlLLE DELTA FIELD PROFILE PERMEAMETER RESULTS * KtJnkenberg (gas slippage) co~ected permeability 573 7188.8 0.077 0.035 574 7189.0 1.3 0.94 575 7189.2 0.052 0.021 576 7189.4 0.014 0.004 577 7189.8 0.99 0.70 578 7190.0 2.5 1.9 579 7190.2 2.0 1.5 580 7190.4 0.77 0.53 581 7190.6 0.89 0.62 582 7190.8 0.66 0.45 583 7191.0 1.5 1.1 584 7191.4 0.39 0.25 585 7191.6 0.099 0.048 586 7191.8 1.5 1.1 587 7192.0 0.62 0.42 588 7192.2 1.8 1.3 589 7192.4 0.29 0.17 590 7192.6 0.099 0.048 591 7192.8 0.28 0.17 592 7193.0 0.39 0.25 593 7193.2 1.9 1.4 594 7193.4 1.6 1.2 595 7193.6 2.1 1.6 596 7193.8 0.10 0.050 597 7194.0 0.37 0.23 Page 3S Profile Permearneter TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1354 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 JUN 01 2000 Alast~a 0ii & Gas Cons. Commission Anch0mge AOGCC ATI~: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: Nanuk #2 well data DATE: 0512612000 Transmitted herewith is the following: Nanuk 2 (501032033200) o~:~ · ~"50 CD ROM Digital data: · Schlumberger Open Hole Edits PEX/A1T&DSI/FMI w/CMR+FMI raw customer Waveform DLIS files , Sperry Sun MWD Logging Run 51-9059'md; log date 04/01/2000 + LIS log verification paperwork 1 Sepia paper and 1 Blueline each: · Sperry MWD ROP/DGR/EWR (MD) · Sperry MWD DGR/EWR (TVD) · Sperry MWD DGR/CNP/SLD (MD) · Sperry MWD DGR/CNP/SLD (TVD) · , Schlumberger UltraSonic Imager Tool US1T/GR (~ ~q~ .. ~ ~ · Schlumberger Formation Micro Imager · Schlumberger Repeat Formation Tester SP/GR , Schlumberger Repeat Formation Tester - GR (Run 2) · Schlumberger Combinable Magnetic Resonance-CMR · Schlumberger PEX: Array Induction -MCFL · Schlumberger Dipole Sonic Imager . Schlumberger Mechanical Sidewall Core Tool · Schlumberger PEX: Density-CNL Porosity · Schlumberger Chronological Sample Taker · Schlumberger Production Packer Setting Record · Schlumberger Pefforatin~ Record 4.5" HSD Guns CC: Mark McDermott Approved fo~~~rs _~'~-'~/~ Receipt: . Date: Return receipt to: (,.~hi~ps ~laska, Inc. ATTN: S. Lemke, ATO-1354 700 G. Street Anchorage, AK 99501 RECEIVED JUN 0 1 2000 Alaska Oil & G~.s C0~,& ~mmi~ion Anchorzge Prepared by: Sandra D. Lemke Phillips Alaska IT Geoscience Group ARCO ALASKA INC. 700 G STREET ANCHORAGE, AK 99510 90%276-1215 To' AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 Attn: Lori Taylor Date: April 26, 2000 From: Mark Myers ATO 1446 ARCO Alaska Inc. P.O.Box 100360 Anchorage, Alaska 99510-0360 Enclosed is the final data for Nanuk #2 (API# 501032033200) as listed below. 1 pre-fold color print and sepia: Epoch mudlog 108 -9112' Upon receipt, please sign and return to: Thank You Catherine Worley ATO 1355 P.O. Box 100360 Anchorage, AK 99510. RECEIVED MAY 04 2000 AMek~ Oil & Gas COns. Oommi~sion Anchorage EPOCH Houston, TX (281) 874-9166 Bakersfield, CA (661) 328.1595 Lafayette, LA ($3~) 837-~46s Anchorage, AK (907) 561-2465 LOG INTERVAL DEPTHS: 108' TO 9112' DATES: 3124/2000 TO 411/2000 SCALE: 2"= 100' MUD TYPES Spud Mud TO 2228' LSND TO 9112' CONFIDENTIA NB NEWBIT PV RRB RERUN BIT YP CB CORE BIT FL WOB WEIGHT ON BIT CL RPM ROTARY REVlMIN Rm PP PUMP PRESSURE SPM STROKESlMIN MW MUD WEIGHT VIS FUNNEL VISCOSITY PR R CASING DATA 16" AT 108' 9 5/8" AT 2219' AT AT HOLE SIZE 12 1/4" TO 2228' 8 1/2" TO !CEIVED ,o 04 2000 Alaska 0il ABBREVIA~~ PLASTIC VISCOSITY YIELD POINT FLUID LOSS PPM CLORIDE ION MUD RESISTIVITY Rrnf FILTRATE RESISTIVITY /_AT LOGGED AFTER TRIP TO, 9112' LC LOST CIRCULATION CO CIRCULATE OUT NR NO RETURNS TG TRIP GAS SG SURVEY GAS WG WIPER GAS CG CONNECTION GAS LAS LOGGED AFTER SURVEY POOR RETURNS Formation Lo; COMPANY: ARCO WELL: Nanuk #2 FIELD: Colville River Unit REGION: North Slope Alaska COORDINATES: 465' FNL, 864' FEL Sec.25, T11N, R4E, UM ELEVATION: County, State: APl Index: Spud Date: Contractor: Co. Rep.; RIg/Type: Logging Unit: Geologists: Add. Persons Co. Geologist: RKB 40' amsl Pad 12' amsl N. Slope Borough, AK 50-103-20332-00 3/24~2000 Doyon Drilling Inc. M.Whiteley/D. Gladden #141 A1 (Built-in room) John Morris Artem Ratchkovski Isaac Stotts/Mark Lyndloff Scott Hodges D. Bannon/M. Myers ALTERED ZONE ANDESITE ANHYDRITE BASALT BIOTITIZATION BRECC~^ CALCARENITE CALCAREOUS TUFF CALClLUTITE C*,BO.*TES CARBONACEOUS MAT c,.eo~c~ous s. CEMENT CONTAM. C.,L~ CHERT - ARGILL ~ DACITE CHERT-GLASSY ~ OIATOMITE CHERT- PORCEL ~ DIORITE CHERT-TIGER STRIPE ~ DOLOSTONE CHERT- UNDIFF ~ FELSIC SILIC DIKE CLAY ~i~ GABBRO CLAY-MUDSTONE ~ GRANITE CLYST-TUFFACEOUS ~ G~NITE WASH CHLORITI~TION ~ G~NODIORITE COAL ~ GYPSUM CONGLOME~TE ~ HALITE CONGL SAND ~ HORNBL-QTZ-DIO CONGL SANDSTONE ~ INTRUSIVES COQUINA ~ ~OLINITIC LIMESTONE , MARL - DOLO · . MARL- CALC METAMORPHICS OBSIDIAN PORCELANITE PORCELANEOUS CLYST PYRITE PYROCLASTICS QUARTZ DIORITE QUARTZ LATITE QUARTZ MONZONITE RECRYSTALLIZED CALCITE RHYOLITE SAND SANDSTONE SERICITIZTION SERPENTINE SHALE SHALE TUFFACEOUS SHELL FRAGMENTS SlLIClFICATION SILTSTONE SILTST-TUFFACEOUS TUFF VOLCANICLASTICS SEDS VOLCANICS [F. wd: Nanu. k P&A pictures] (,. Subject: [Fwd: Nanuk P&A pictures] Date: Mon, 08 May 2000 14:29:13 -0800 From: John Crisp <john_crisp~admin. state.ak.us> Internal Organization: State of Alaska, Dept of Admin, AOGCC To: Blair E Wondzell <blair_wondzell~admin. state.ak.us> Mr. Blair. I will send in final report on this well. Just wanted you to know how it turned out. Scott Goldberg said it took 1/2 sack of cement to finish. Bet those Roustabouts were glad!! Subject: Nanuk P&A pictures Date: Mon, 8 May 2000 14:04:38 -0900 From: "Overstreet&Winfree" <N 1335~ppco.com> To: John_Crisp~admin. state.ak.us (See attached file: Just before sealing.jpg) (See attached file: Capped and Sealed.jpg) (See attached file: Wellhead just cut.jpg) .................................................................................. ~N;-me :--o~5~t~-v b e~.~e-- sealing.j p~-~-'-=-:==1 Type: JPEG Image (image/jpeg)] ~Just before sealing.jpg Encoding: base64 ] ..................................................................... Description: JPEG File Interchange,.~.,~ ~ ....... ~ Type: JPEG Image (image/jpeg)] tzappeo ann ~emea lPg ~ ' '- ] Encoding: base64 -'1 ........................ ]Descrip. ~_~~tio~n:?~Q~.~i,~e ~?rch~ge .... ~ .................. ~ ........ Na-~e :~W~~d just cu~~-Jp-~ ......~ ~ .......... . ~ Type: ~EG ~age (image/jpeg) weuneaa just cut lPg ~ ' ] Encoding: base64 ~Description: JPEG File ~terch~ge 1 of 1 5/8/00 2:31 PM J,PEG image 640x480 pixels 1 of 1 5/8/00 2:30 PM EEO imag,e 640x480 pixels 1 of 1 5/8/00 2:30 PM J]~EG imag,e 640x480 pixels 1 of 1 5/8/00 2:30 PM MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~(~ DATE' May 7, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM: John Crisp,~~C-'· SUBJECT: Petroleum Ir~spector Plug & Abandon AAI EXP. Nanuk #2 PTD 200-030 · May 7, 2000: I traveled to Arco Alaska's Exploratory well Nanuk #2 to witness the surface cement plugs & cut off depth of all casing strings. I witnessed the area surrounding the conductor casing dug down to approximately 6' below tundra level. A window was cut in conductor casing allowing the initial cut on the 9 5/8" surface casing @ approximately 4' below tundra level. The decision was made to cold cut casing strings due to Diesel traces between the 9 5/8" & 7" casing. I requested AAI Rep. Scott Goldberg to photo cement to surface on all casing strings. Photos were also taken of outer casing information cap after it was welded on conductOr SUMMARY: I witnessed the cut off depth of casing for P & A of Nanuk #2, Arco Alaska's Exploratory well. Attachments: Nanuk #2 P & A photos. cc; NON-CON FIDE NTIAL JpEG image 640x480 pixels 1 of 1 5/9/00 1:02 PM JPEG image 640x480 pixels 1 of I .5/9/00 1:02 PM .I'PEG image 640x480 pixels 1 of 1 5/9/00 1:02 PM MEMORANDUM TO: Robert Christenson,~F-" Chairman THRU: State of Alaska Oil and Gas Conservation Commission DATE: May 5, 2000 Blair Wondzell, ~ P. I. Supervisor 5'/e leo FROM: John Crisp,~~ ~. SUBJECT: Petroleum I~spector Perforation Plug Test 2 AAI EXP. Nanuk #2 PTD 200-030 May 5, 2000: I traveled to Arco Alaska's Exploratory well Nanuk #2 to witness the pressure test of perforations below production packer after Re-Squeeze. A successful pressure test was performed on Nanuk #2 to verify the plugging of perforations below production packer. Starting pressure of 1744 psi. with final pressure of 1684 psi. after 15 minutes was witnessed. The plugging of this well was designed to have TOC inside 3 ½" tbg. @ 6700'. After Re-Squeeze was performed I witnessed SWS tag cement inside 3 ¼" tbg. @ 2342'. SUMMARY: I witnessed the successful pressure test of cemented perforations on AAI's Nanuk #2. TOC was witnessed tagged @ 2342'. Attachments: NONE cc; CONFIDENTIAL P&ANanuk MEMORANDUM TO: State of Alaska Ale~ska Oil and Gas Conservation Commission Robert Christenson~ DATE: May 4, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM' John Cnsp, ~ C_~, SUBJECT: Petroleum INspector Perforation Plug Test AAI EXP. Nanuk #2 PTD 200-030 May 4, 2000: I traveled to Arco Alaska's Exploratory well Nanuk #2 to witness the pressure test of cemented perforations below the production packer. Pressure test of cemented perforations below production packer was attempted. This test was not successful. The perfs, were pumped into @ 1 BPM. 550 psi. A total of 4.5 BBL's. were pumped away. Immediate decision to Re-Squeeze perfs, was made. SUMMARY: I witnessed the unsuccessful pressure test of cemented perforations on AAI's Exploratory well Nanuk #2. Attachments: NONE cc.; CONFIDENTIAL P & A Nanuk R~: Nanuk #2 P&A- CONFIDENTIAL Subject: Re: Nanuk #2 P&A-CONFIDENTIAL Date: Wed, 03 May 2000 10:04:16 -0800 From: Blair Wondzell <blair_wondzell@admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tom J Brassfield <TB~SS@mail.~i.~co.com> CC: Paul Mazzolini <PMAZZOL@mail.aai.arco.com> ¢. oo -- o '30 Tom, The program looks good. Request that in Step 6 you pressure test before the tag and that you pressure test to 1700 psi (0.25 psi/foot.). This confirms the verbal approval from yesterday, May 2, 2000. Good Luck, Blair Wondzell, 5/3/2000> Tom J Brassfield wrote: Blair, please find enclosed a proposed procedure for the final P&A of the Naunk #2 wellbore. Our Geologists have looked at the logs and determined that there is no evidence of a freshwater zone in the surface casing shoe vicinity. We can have them discuss with Bob Crandall if required. This well is also within the Alpine CRU. The testing folks were rigging down today and we would like to start the P&A work tomorrow if we get your approval. Will fax the schematic. Thanks, Tom (See attached file: Nanuk 2 AOGCC P&A Proc by TJB 5 2 O0.doc) TJB 5 2 O0.doc Nanuk 2 AOGCC P&A Proc by TJB 5 2 O0.doc (appl i ca tion/rtf) __ Name: Nanuk 2 AOGCC P&A Proc by Type: Ri ch Text Format Encoding: base64 Description: Rich Text Format 1 of 1 5/3/00 10:22 AM Phillips Alaska, Inc.il,"" · Post Office Box 100360 Anchorage, Alaska 99510-0360 ,ak May 3,2000 Mr. Robert Christenson Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 CONFIDENTIAL Re' Sundry Notice for P&A of Nanuk #2 Exploration Well- Surface Location: ASP NAD 27 Coordinates X=337,335 & Y=5,954,678 464' FNL 864' FEL Sec 25 T11N R4E, UM Target Location: 1172' FNL, 3718' FEL Sec. 25, T11N, R4E, UM Bottom Hole Location: 1172' FNL, 3718' FEL Sec. 25, T4N, R4E, UM Dear Mr. Commissioner: Phillips Alaska, Inc. hereby files this sundry for the plug and abandonment of the Nanuk #2 exploration well. The well has been completed, perforated, and flow tested in both the Nanuk and the Kuparuk sand intervals. This program is in agreement with the procedures discussed between Blair Wondzell and Tom Brassfield on 5/2/00. If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn / Tabasco Development Group Attachments cc: Nanuk #2 Well File RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Alaska 0il & Gas Cms. Commission ~ch0ra~e STATE OF ALASKA f' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon X Suspend_ Alter casing _ Repair well _ Change approved program __ Operation Shutdown __ Re-enter suspended well _ Plugging__ Time extension _ Stimulate_ Pull tubing _ Vadance __ Perforate I Other 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory X Stratigraphic __ Service 4. Location of well at surface: ASP NAD27 Coordinates X=377,335 & Y=5,954,678 464' FNL, 864' FEL, Sec. 25, T11 N, R4E, UM At top of productive interval 1172' FNL, 3718' FEL, Sec. 25, T11N, R4E, UM At effective depth At total depth 1172' FNL, 3718' FEL, Sec. 25, T11 N, R4E, UM 6. Datum elevation (DF or KB) 28' RKB, Pad 11' 7. Unit or Property name Colville River Unit 8. Well number Nanuk #2 9. Permit number 200-030 10. APl number 50-103-20332-00 11. Field/Pool Colville River Unit feet 12. Present well condition summary Total Depth: measured 9112 feet (approx) true vertical 8241 feet Effective depth: measured 9024 feet (approx) true vertical 8154 feet Casing Length Size Structural Conductor 80' 16" Surface 2191' 9.625" Intermediate na Production 9077' 7" Cemented Measured depth 200 cu. Ft. 108' 398 Sx AS III LW & 2219' 350 sx Class G 198 sx Class G Lead 9105' plus 245 sx Class G Tail True verticaldepth 108' 2056' 8234' Perforation depth: measured Nanuk Interval from 7048' to 7108' MD Kuparuk Interval from 7948' to 7962' MD true vertical Nanuk Interval from 6178' to 6238' TVD Kuparuk Interval from 7077' to 7091' TVD Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 6906' MD or 6035' TVD Packers and SSSV (type and measured depth) Baker FB1 Pkr @ 6791' MD or 5921' TVD ORIGINAL t!:,IAY 0 ;5 2000 Alaska 0il & Gas Coos. Commission 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch _ Contact Paul Mazzolini at 263-4603 with any questions. LOT test, surface cement details and casing detail sheets _ 14. Estimated date for commencing operation 5/3/OO 16. If proposal was verbally approved Name of approver Blair Wondzell Date approved 5/2/00 15. Status of well classification as: Oil__ Gas__ Suspended X Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed¢---~ ,.,F~Paul Mazz~" '"/~ ~'~ ' Title Exploration/Tarn/Tabasco Team Leader ,.% Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test _ Location clearance Mechanical Integrity Test_ Subsequent form require 10-/,(,O' ~' ~..~GINAL SIGNED. BY Robert N. Christenson Approved by the order of the Commission Form 10-403 Rev 06/15/88 IApproval No. Date SUBMIT IN TRIPLICATE ( Nanuk #2 Final P&A {f CONFIDENTIAL Revised 5/2/00 Approved by Blair Wondzell Current Status: Nanuk #2 was completed by Doyon 141 on 4/11/00. The Nanuk interval was perforated (7048' to 7108' MD), stimulated, and tested from 4/16 to 4/29. The Kuparuk interval (7948' to 7962' MD) was then perforated and flowed simultaneously with the Nanuk interval. Phillips Alaska, Inc proposes to perform a final P&A to this wellbore before the Ice roads prevent any further activities. The following P&A procedure assumes that there are no freshwater zones close to the surface casing. . Notify AOGCC Slope Inspector 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Rig up slickline unit and set dummy valves in GLM's at 6847', 6817', and 2493'. Pull the dummy from the GLM above the packer at 6707'. RD slickline. 3. Mobilize and rig up D/S for well P&A operation. . Bullhead 9.6 ppg fluid to the tubing tail- note injection pressures. Displace 3-1/2" x 7" annulus to 9.6 ppg fluid. Confirm that the annulus is full. RU wireline and set dummy Valve in GLM at 6707'. RD wireline unit. . Rig up D/S to tree and establish injection rates into perforations. Mix approx. 85 bbls. cement (Class G with additives) and pump down tubing into the peforations. Pump enough slurry (78 bbl) to cover PBTD to tubing tail, leaving remaining slurry in tubing. Hesitate squeeze cement into perfs as required- do not displace top of cement past 6700' MD. Dipslace cement with 9.6 ppg fluid. . Pressure test tubing to 1700 psi. Rig up SWS "eline" unit and RIH to tag top of cement plug to verify placement. Record and report results. AOGCC may want to witness tag of cement and pressure test. . RU cementing unit to 7" x 9-5/8" annulus. Establish injection rate down annulus with fresh water followed by approx. 23 bbls of Arctic Set cement slurry to fill annulus to 1000' MD. . RIH with 2.795 gauge ring to 350'. Set Baker 3-1/2" bridge plug at approx. 310'. Make up SWS tubing puncher and perforate tubing at approx. 300'. POOH and RD SWS "eline" unit. . RU D/S and circulate surface cement plug (approx. 10.5 bbls. Arctic Set 1) down tubing into tubing/casing annulus to surface. NOTE: Notify Slope AOGCC Inspector before setting surface plug. 10. Clear lines and shut down pumps. Rig down cementing unit and clean up. 11. Cut off wellhead and all casing strings at 3 feet below original ground level. Send casing head with stub to Materials for repair / re-dressing. TJB 5/2/00 RECEIVED [ IAY 2000 Alaska Oil & Gas Cons. Commission Anchorage Nanuk #2 Final P&A( ~' CONFIDENTIAL Revised 5/2/00 Approved by Blair Wondzell 12. Weld cover plate over all casing strings with the following information bead welded into the top: ARCO ALASKA, INC Nanuk #2 PTD # 200-030 APl # 50-103-20332-00 13. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 5/1/00 FILE: Nanuk #2 Paul Mazzol~l Date Exploration/Tarn/Tabasco Team Leader Blair Wondzell w/AOGCC Date RECEIVED ,'~r' 0,3:2000 AJa~ka Oi~ & Gas Cons, Commission Anchorage TJB 5/2/00 To: Tom J Brassfield/AAI/ARCO cc: Paul Mazzolini/AAI/ARCO Subject: Re: Nanuk ~2 P&A- CONFIDENTIAL Tom, The program looks good. Request that in Step 6 you pressure test before the tag and that you pressure test to 1700 psi (0.25 psi/foot.). This confirms the verbal approval from yesterday, May 2, 2000. Good Luck, Blair Wondzell, 5/3/2000> Tom J Brassfield wrote: > Blair, please find enclosed a proposed procedure for the final P&A of the Naunk > #2 wellbore. Our Geologists have looked at the logs and determined that there is > no evidence of a freshwater zone in the surface casing shoe vicinity. We can > have them discuss with Bob Crandall if required. This well is also within the > Alpine CRU. The testing folks were rigging down today and we would like to start > the P&A work tomorrow if we get your approval. Will fax the schematic. > Thanks, Tom > > (See attached file: Nanuk 2 AOGCC P&A Proc by TJB 5 2 00.doc) > > P&A Proc by TJB 5 2 00.doc > Nanuk 2 AOGCC P&A Proc by TJB 5 2 00.doc (application/rtf) > > Name: Nanuk 2 AOGCC Type: Rich Text Format Encoding: base64 Description: Rich Text Format RECEIVED 08 2000 AJaska Oil & Gas Cons. Commission An~orage ARCO 'v' . Calculations Char . I ~ ~1 t~, ~ , II!~ ' ~ ,. ... . >.% , ~ ~: ,.., ~ :-' .. ~ ," ~ ':,'~ . , ~ Z~o .............. . ,. · ,.... ~ ..... . · . ~ . . ~ . '".~..:~ '~ ..... '.~. : Nanuk #2 P&A- CONFIDENTIAL Subject: Nanuk #2 P&A- CONFIDENTIAL Date: Tue, 2 May 2000 11:53:04 -0900 From: "Tom J Brassfield" <TBRASS~mail.aai.arco.com> To: Blair Wondzell <blair_wondzell@admin.state.ak.us> CC: "Paul Mazzolini" <PMAZZOL@mail.aai.arco.com> Blair, please find enclosed a proposed procedure for the final P&A of the Naunk #2 wellbore. Our Geologists have looked at the logs and determined that there is no evidence of a freshwater zone in the surface casing shoe vicinity. We can have them discuss with Bob Crandall if required. This well is also within the Alpine CRU. The testing folks were rigging down today and we would like to start the P&A work tomorrow if we get your approval. Will fax the schematic. Thanks, Tom (See attached file: Nanuk 2 AOGCC P&A Proc by TJB 5 2 00.doc) ~Nanuk 2 AOGCC P&A Proc by TJB 5 2 00.doc Name: Nanuk 2 AOGCC P&A Proc by TJB 5 2 00.doc Type: Rich Text Format (application/rtf) Encoding: base64 Description: Rich Text Format 1 of 1 5/2/00 1:11 PM t( Nanuk #2 Final P&A o -.o ~ o CONFIDENTIAL Revised 5/2/00 Current Status: Nanuk #2 was completed by Doyon 141 on 4/11/00. The Nanuk interval was perforated (7048' to 7108' MD), stimulated, and tested from 4/16 to 4/29. The Kuparuk interval (7948' to 7962' MD) was then perforated and flowed simultaneously with the Nanuk interval. Phillips Alaska, Inc proposes to perform a final P&A to this wellbore before the Ice roads prevent any further activities. The following P&A procedure assumes that there are no freshwater zones close to the surface casing. Notify AOG~.~.~.~_..~4 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Rig up slickline unit and set dummy valves in GLM's at 6847', 6817', and 2493'. Pull the dummy from the GLM above the packer at $707'. RD slickline. 3. Mobilize and rig up D/S for well P&A operation. . . . Bullhead 9.6 ppg fluid to the tubing tail- note injection pressures. Displace 3-1/2" x 7" annulus to 9.6 ppg fluid. Confirm that the annulus is full. RU wireline and set dummy Valve in GLM at 6707'. RD wireline unit. Rig up DIS to tree and establish injection rates into perforations. Mix approx. 85 bbls. cement (Class G with additives) and pump down tubing into the perorations. Pump enough slurry (78 bbl) to cover PBTD to tubing tail, leaving remaining slurry in tubing. Hesitate squeeze cement into perfs as required- do not displace top of cement past 6700' MD. Dipslace cement with 9.6 ppg fluid. Rig up SWS "eline" unit and RIH to tag top of cement plug to verify placement. Record and report resultst Pressure test casing to 1500 psi. AOGCC may want to witness tag of cement and pressure test. j ,./,~ RU cementing unit to 7"x 9-5/8" annulus. Establish injection rate down annulus with fresh water followed by approx. 23 bbls of Arctic Set cement slurry to fill annulus to 1000' MD. . RIH with 2.795 gauge ring to 350'. Set Baker 3-1/2" bridge plug at approx. 310'. Make up SWS tubing puncher and perforate tubing at approx. 300'. POOH and RD SWS "eline" unit. "' , RU DIS and circulate surface cement plug (approx. 10.5 bbls. Arctic Set 1) down tubing into tubing/casing annulus to surface. NOTE: Notify Slope AOGCC Inspector before setting surface plug. 10. Clear lines and shut down pumps. Rig down cementing unit and clean up. 11. Cut off wellhead and all casing strings at 3 feet below original ground level. Send casing head with stub to Materials for repair / re-dressing. 5/2/00 ( ' Nanuk #2 Final P&A ( CONFIDENTIAL Revised 5/2/00 12. Weld cover plate over all casing strings with the following information bead welded into the top: ARCO ALASKA, INC Nanuk #2 PTD # 200-030 APl # 50-103-20332-00 13. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. TJB 5/1/00 FILE: Nanuk #2 Paul Mazzolini Date Exploration/Tarn/Tabasco Team Leader Blair Wondzell w/AOGCC Date TJB 5/2/00 ^RCO Alaska, !nc. Number of Pages (Cove~ +) ARCO ALASKA'~ 907 276 7542:# 1/ 2 :ur .... ~ ~ ~ ' . Phone: "Ku~aruk Development... -. P. O. BOX .100360 ., ANCHORAGE. AK 99510-0360 '. .. FAX .~ 907 265-6224 _._ · · Location. · ,~ : ........ ATO4{MI~ 1'41) q~'~',. ',.?: - - FAX,~ - :-' ' /LOcatiOn: ' ~ " '-' 'Phone,: -' '/- .i';_ i ' ,~ Copie~ To: ._ ' ~ I I 2 Il j ..... jlllllm ;._J Il . ,- _ IL J ., . · ,. · _ iiiii SENT BY: 5- 2- 0 ' 8:55PM ' ARCO ALASKA~ 907 276 7542'# 2/ 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~ DATE: April 5, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM' John Crisp,~/~ SUBJECT: Petroleum ~spector BOP Test Doyon 141 AAI Nanuk #2 April 5, 2000: I traveled to Arco Alaska's Nanuk #2 Exploratory well to witness the weekly BOP test on Doyon Rig 141. BOP test went very well with no failures. Rig & location are in good shape. All personnel were familiar with test procedures & BOP Equipment. Tool Pusher was requested to have Electrician test gas detector sensors @ Rig Floor when Elect. Arrived on tour @ 0600 hrs. T.P. called w/results of test. SUMMARY: I witnessed the weekly BOP test on Nanuk #2. Tested BOPs Doyon 141 4-5-00, test time 3 hours, no failures. Attachments: BOP Doyon 141 Nanuk #2 4-5-00jc cc; CONFIDENTIAL - BOP Doyon 141 Nanuk 2 4-5-00jc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Doyon Drilling Rig No. 141 PTD # 200030 Arco Alaska Inc. Rep.: Nanuk #2 Rig Rep.: Set @ 2290' Location: Sec. Weekly X Other DATE: 4/5/00 Rig Ph.# 907 263-3100 Dead Gladden James Willingham 25 T. 11N R. 4E Meridian UM Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: OK Well Sign Yes Upper Kelly/IBOP Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly/IBOP PTD On Location Yes Hazard Sec. Yes" Ball Type Standing Order Posted Yes ,, Inside BOP Quan Pressure P/F 1 250/5, OO0 P 250/5,000 P 25O/5, OOO P 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Quan. Test Press. P/F 250/2500 ~ 250/5,000 250/5,000 250/5,000 250/5,000 250/5,000 250/5,000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 13 250/5, 000 P 28 250/5,000 P 1 Yes Functioned Functioned ~s ACCUMULATOR SYSTEM: System Pressure 2,900 P Pressure After Closure 1,600 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 32 Trip Tank OK OK System Pressure Attained 3 minutes 9 Pit Level Indicators OK OK Blind Switch Covers: Master: X Remote: Flow Indicator OK OK Nitgn. Btl's: 5 Btls. @ 2250 psi. Meth Gas Detector Tested by T.P. Tested by T.P. - Psig. H2S Gas Detector Tested by T.P. Tested by T.P. sec. sec. X Equipment will be made within ~_.da~s. Notify the Inspector and follow with ~n or Faxed verification to Ithe 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: Rig & Location in very good condition. Crew change occurred during BOP test, went very well El all personnel familiar w/ test procedures & BOP equipment. Tool Pusher James Willingham witnessed gas detector test performed by Electrician. The Rig Floor gas detector sensors tested. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspe~;t.(~,lL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John Crisp 11 Nanuk 2 4-5-00jc3 MEMORANDUM State of Alaska Maska Oil and Gas Conservation Commission TO: Robert Christenson,¥ ][J~'" DATE: Chairman March 26, 2000 THRU: Blair Wondzell, ~ ~ SUBJECT: P. I. Supervisor 3{~(~ FROM: John H Spauldin~/~~ Petroleum Inspec~r BOPE Test ARCO / Doyon 141 ~L~p~.-,u~ # 2 / ~.~il~cat D: 200-030_~ on March 26th I traveled to ARCO's wildcat well Nanuk # 2 to witness the BOPE test on Doyon Drlling's rig 141. The AOGCC BOPE Test Report is attached fro reference. As noted on the report form, no failures were observed and testing went quiute smooth. SUMMARY: I witnessed the BOPE test on; Doyon 141, 0 failures, 3.5 hours Attachment: bop doyon 141 3-26-00js Confidential ~z,~.~t~,t'{- On~.~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Ddg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Doyon Rig No. 14'1 ~ PTD # ARCO Rep.: Nanuk # 2 Rig Rep.: Set @ 2,228 Location: Sec. Weekly Other 200-030 DATE: 3/26/00 Rig Ph.# 1-907-263-31 Jim Willingham Mike Whitely 25 T. 1'1N R. 4E Meridian Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes FLOOR SAFETY VALVES: Well Sign yes Upper Kelly/IBOP Drl. Rig ok Lower Kelly/IBOP Hazard Sec. yes - Ball Type .. Inside BOP Test Quan Pressure P/F `1 25O/5, OOO P 250/5, 000 P 250/5,000 P 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan, Test Press. P/F 25O/2500 P '1 250/5,000 P `1 250/5,000 P '1 250/5,000 P `1 25O/5, OOO P 2 25O/5, OOO P `1 250/5,000 P n/a 250/5, 000 MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok, H2S Gas Detector ok ok CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 250/5,000 33 250/5,000 Functioned Functioned PIF P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 5 @ 2`100AVG 3,000 P '!,850 - P minutes 49 sec. minutes `1 sec. X Remote: X Psig. IEquipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c-Inspe~t.~lL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: 141 3-26-00 js John H. Spaulding MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~ DATE: Chairman March 23, 2000 THRU: Blair Wondzell, ~~ SUBJECT: P. I. Supervisor 7(a,~/oc~ FROM: John H Spauldin~~4,~ ~ Petroleum InspectOr Diverter Function Test ARCO / DOYON141 N-~2, u k~-~j~cat o o-o On March 23, 2000 I traveled to ARCO's wildcat well Nanuk # 2 to witness the Diverter Function test on Doyon Drilling's rig 141. The AOGCC diverter function test report form is attached for reference. As noted on the report form,no failures were obsrerved. I also witnessed the calibration of the methane and h2s gas detectors. SUMMARY: I witnessed the BopeTest on: Doyon 141, no failures, 2 hour test time Attachment: diverter doyon 141 3-23-00js CONFIDENTIAL ALAS OIL AND GAS CONSERVATION COM ~ION Diverter Systems Inspection Report Operation: Drlg Contractor: Doyon ~' Rig No. Operator: ARCO Oper. Rep.: Well Name: Nanuk #2 Rig Rep.: Location: Sec. 25 T. 11N R. 4E Development 141 PTD # Date: 3/23/00 Exploratory: X 200-030 Rig Ph. # 263-3110 Mike Whitely Jim Willingham Merdian Umiat MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: ok Well Sign: yes Systems Pressure: 3000 psig Housekeeping: ok (Gen,) Drlg. Rig: ok Pressure After Closure: 1 650 psig Reserve Pit: na Flare Pit: na 200 psi Attained After Closure: min. 59 sec. Systems Pressure Attained: 3 min. 49 sec. Nitrogen Bottles: 5 @ 2350 avg. DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: yes Valve(s) Auto & Simultaneous: yes Vent Line(s) Size: 16 Vent Line(s) Length: 75 Line(s) Bifurcated: na Line(s) Down Wind: yes Line(s) Anchored: yes Turns Targeted / Long Radius: na in. psig MUD SYSTEM INSPECTION: Light Alarm in. Trip Tank: ok ok ft. ' Mud Pits: ok ok Flow Monitor: ok ok GAS DETECTORS: Light Alarm Methane ok ok Hydrogen Sulfide: ok ok 6" vent line 75' from rig IPipe Shed Wind Direction Shop Camp Non Compliance Items Remarks: Repair Items Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c- Oper/Rep c- Database c - Trip Rpt File c- Inspector AOGCC REP.: OPERATOR REP.' Diverter Doyon 141 3-23-00 js John H. Spaulding Mike Whitely DVTRINSP.XLT (REV. 1/94) TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS Paul Mazzolini CONSi~RYA~ION COI~IISSION Exploration/Tam Drilling Tcam Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Nanuk #2 ARCO Alaska, Inc. Permit No: 200-030 Sur. Loc. 465'FNL, 864'FEL? Sec. 25, TI IN, R4E, UM Btmholc Loc. 1160'FNL. 3718'FEL, Sec. 25, T11N, R4E. UM Dear Mr. Mazzolini: Encloscd is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes xx'ill not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must bc submitted to the Commission on form 10- 403 prior to the start of disposal operations. The Commission will not authorize annular disposal into another well not located on the same pad or platform unless the operator demonstrates that compliance with the limitation established in 20 AAC 25.080(d) is imprudent. Therefore, injection into another "Kuparuk Well Open Annulus" as described in your application can not be approved at this time. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc 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 week's activities and is exclusively for the Commission's intcmal use. All db' ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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. Chair BY ORDER OF TH~OMMISSION DATED this/"/'~- day of March, 2000 dlf/Enclosures CC; Department of Fish & Game. Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. A ,,,A OIL AND GAS CONSERVATION COM ,~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory X Stratigraphic Test [] Development Oil Re-Entry r-~ Deepen r-~ Service r'~ Development Gas E] single Zone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 12' feet 3. Address 6. Property Designation Colville River Unit P. O. Box 100360, Anchorage, AK 99510-0360 ADL .38e07'7 ALK ~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) ASP4, NAD27 coordinates X=377,335 & Y=5,954,678 or N/A ~t) ~ '5~~-~ Statewide 465' FNL, 864' FEL, Sec. 25, T11 N, R4E, UM L~,.~/,,. At top of productive interval (@ TARGET ) 8. Well number ~ Number 1160' FNL, 3718' FEL, Sec. 25, T11 N, R4E, UM Nanuk #2 '~1~ #U-630610 At total depth ~'~"/(.. ~.)~) 9. Approximate spud date Amount 1160' FNL, 3718' F/WL, Sec. 25 , T11N, R4E, UM 3/10/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) property line Nanuk #1 MD 9513' 4120' @ TD feet 1.0 Miles feet 4000 TVD 8640' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 650 feet Maximum hole angle 37.5° Maximum surface 1217 psig At total depth (TVD) 4493 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 118' 118' +/- 200cf 121A'' 9-5/8" 53.5 L-80 BTC 2297' 28' 28' 2325' 2150' 450 sx AS3 plus 340 sx CIG PPf 8Y2" 7" 29 ppf L-80 BTC-M 9485' 28' 28' 9513' 8640' 525 sx CIG 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth:, measured feet Junk (measured) true vertical feet EECEIVEEt Casing Length Size Cemented Meas I depth Structural Conductor Surface '~ 0 2 2000 Intermediate Production Perforatio~idneerpth:0 RIG INA L 20. Attachments Filing fee X Property plat [-] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot X Refraction analysis X Seabed report ri 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ' /I Signed ~ C[.m,,N.~ ~,t,~ r~ ( '"~CL~,,-~ J~ ~,~-~,~,¢~t Title Exploration/Tarn Drilling Team Date Leader Commission Use Only Permit Number I APl number__ I Approval date ] See cover letter for '~-~::~:~-- ~ ~:) 50- /~;)~-,~'"~,~.~:~Z--~ ~.,~ '-'/"~"' ~ other requirements Conditions of approval Samples required ~ Yes BI No Mud log required ~ Yes [~ No O1~ E] survey required ~;~ ~'"~' Hydrogen sulfide measures Yes No Directional ,--, Yes E] No Required working pressure for B r'~ 2M E] 3M ~ 5M FI 10M E] 15M Other: ORIGINAL SIGNED' BY Robert N. Christenson by order of Approved by Commissioner the commission Date..._ Form 10-401 Rev. 7-24-89 Submit in triplicate 1200 1600 2000' _ 2400 - _ 2600- _ 3200- ~$00 4000 ~200 5600 6000 7200 7600 ARCO Alaska, Inc. l FJt. RKB Devotion: 40' KOP 6.00 B/ Permefr~t ~000 9.00 12.00 T/West Sok , i 15.00 18.00 DLS: 3.00 deg per 100 ft 21.00 24.00 27.00 30.00 35.00 EOC 5/6 c~g F~ C-30 Sfrucfure: Nanuk ~2D Field: Alpine Field C-20 Well: Nan2D Location: North Slope, Alaska <- West (feet) 2700 2400 2100 1600 1500 1200 go0 600 500 0 I I I I m I I ~ I I I I I I I I I I I I ,% Seq 100 Seq 99 Seq 98 Begin N~gle Drop 36.00 52.00 30.00 26,00 26.00 2.00 20.00 DLS= 2.00 deg per 100 ft 18.00 16.00 14.00 12,00 10.00 8.00 §.00 4.00 2.00 TGT - Seq 96 B/ Seq 96 Seq 95 LCU J4 Nuiqsut Nechelik J3 TD - 7 Cs§ Pt Seq 97 End Angle Drop m i i I i i i ! i i i i ! i ! i i 0 400 BOO 1200 1600 2000 2400 2800 3200 Vertical Section (feet) -> Azimuth 2,58.24 with reference 0.00 N, 0.00 £ from slot #2D ~00 I 60o v 900 Gas Cons. Commission Anchorage ARCO Alaska, Inc. Structure: Nanuk #2D Field: Alpine Field Well : Nan2D Location: North Slope, Alaska PROFILE COMMENT DA- Point KOP B/ Permafrost T/ West Sa k EOC 9 5/8 Csg Pt C-30 C-20 Seq 1 O0 Seq 99 Seq 98 Begin Angle Drop Seq 97 End Angle Drop TGT - Seq 96 B/ Seq 96 Seq 95 LCU J4 Nuiqsut Nechelik d3 TD - 7 Csq Pt MD 650.00 840.31 1012.17 1898.75 2325.00 2576.97 3043.11 4437.73 4721.20 4949.22 5075.89 6672.55 6948.98 7048.96 7275.98 7591.98 7926.98 8267.98 8489.98 8755.98 9260.98 9512.98 Inc Dir TVD North 0.00 258.24 650.00 0.00 5.71 258.24 840.00 - 1.93 10.86 258.24 1010.00 -6.98 57.46 258.24 1811.64 -80.26 57.46 258.24 2150.00 - 155.08 57.46 258.24 2550.00 -164.51 57.46 258.24 2720.00 -222.08 37.46 258.24 3827.00 -394.91 57.46 258.24 4052.00 -450.04 37.46 258.24 4233.00 -458.30 37.46 258.24 4333.54 -473.99 5.53 258.24 5800.00 -591.66 0.00 258.24 6076.00 -594.38 0.00 258.24 6175.98 -594.58 0.00 258.24 6401.00 -594.38 0.00 258.24 6719.00 -594.38 0.00 258.24 7054.00 -594.58 0.00 258.24 7595.00 -594.58 0.00 258.24 7617.00 -594.38 0.00 258.24 7885.00 -594.58 0.00 258.24 8588.00 -594.58 0.00 258.24 8640.00 -594.38 -A East 0.00 -9.28 -33.52 -585.65 -659.47 -789.50 -1067.08 - 1897.54 -2066.55 -2202.12 -2277.54 -2842.94 -2855.99 -2855.99 -2855.99 -2855.99 -2855.99 -2855.99 -2855.99 -2855.99 -2855.99 -2855.99 V. Sect 0.00 9.47 34.24 393.89 653.17 806.42 1089.94 1938.20 2110.61 2249.30 2326.34 2903.85 2917.18 2917.18 2917.18 2917.18 2917.18 2917.18 2917.18 2917.18 2917.18 2917.18 Deg/1 O0 0.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 GENERAL DRILLING PROCEDURE ARCO Nanuk #2 1. Move in and rig up Doyon #141 over pre-installed 16" conductor casing. 2. Install divertersystem. 3. Drill 12-1/4" hole to 9-5/8" surface casing point (2325' MD/2150' TVD) according to directional plan. . Run and cement 9-5/8" 53.5 ppf L-80 BTC Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 9-5~8" casing at approx. 1000' TMD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. 5. Install and test BOPE to 5,000 psi. Test casing to 2,500 psi. , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. These test results must demonstrate that the integrity of the casing shoe will be sufficient to contain the anticipated wellbore pressures. 7. Drill 8-1/2" hole to TD (9513' MD/8640' TVD), coring as necessary, according to directional plan (if applicable). 8. Run open hole evaluation logs. 9. If the well is to be tested, run 7", 29 ppf L-80, BTC-M production casing. Go to step 10. Pressure test casing to 3500 psi. If the well will not be tested, P&A it per AOGCC regulations. Go to step 14 10. Complete the well with 3-1/2", 9.3#, L-80, EUE 8rd tubing. ND BOPE. NU upper tree and test 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 Nanuk #2 wellbore. 13. Test zones as appropriate. When complete, plug and abandon the well as per AOGCC regulations. 14. Thoroughly clean location and block off access ice road. RECEIVED TJB 2/28/00 Anchorage , LEAK OFF TEST PROCEDURE Nanuk #2 After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2500 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the AAI LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. , Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. , On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in l-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. TJB 2/28/00 Anchorage ARCO Nanuk #2 PRESSURE INFORMATION AND CASING DESIGN (Per 20 AAC 25.005 (c) (4) DISCUSSION The following presents the data used for calculation of the anticipated surface pressures (ASP) used for the design and drilling of Meltwater North #2..~.\~,, o,t-'¥~:~,_-~- ~.~'~- ' % ........................................................................ C'~i§ii;i~i"S'~fi~'~"D'~"~tl~ ..................... [ .............................................................................. PS'i~ ................................................................................................................................................................. Casing ~ Fracture Pressure Pore ASP Drilling Size i ..¢.... i Gradient Gradient Pressure ! ................. "f6"'"~ ........... 'i ............ '~"-"T~IS'"'TVDT"T18'""~D ........................... i ............ T~f":0'"i515g ............. i ............... 8/5'"'pi5~ ............... i .................. 5'2'"'15§i ................... ~ ...................... N1A .......... i ............ g::5~,_8...' ........... i ............ ~,"'2'~'SO""TVDT"2'3'25,'"MD ..................... i ............ ~I"3':'0'"'i5'i5'~i ........... i ............... g':0'"'1515'~ ............... ! ............. ~1"0'0¥"15§i ............. [ .................... 7 ................... i ........... ~'"'8'6:{0'"TVDT'"95T3'"MD ..................... i ........ ~16:0 15'15~ ............ i ............. ~1'0':0"'15'15'~ ............ ! ............ ~]'g3'"'15§i ............. ....................... ..................................................................................................... " Expected Maximum Mud Weights: 12-1/4" Surface Hole to 2150' TVD / 2325' MD: 10.0 ppg 8-1/2" Production Hole to 8640' TVD / 9513' MD: 11.2 ppg Procedure for calculating Anticipated Surface 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 = FG = 0.052 - 0.11 = D= Anticipated Surface Pressure in psi Fracture Gradient at the casing seat in lb/gal Conversion factor from lb/gal to psi/ft Gas gradient in psi/ft True vertical depth of casing seat in ft. RKB OR 2) ASP = FPP- (0.11 xD) Where: FPP = Formation Pore Pressure at the next casing point -1- Anchorage Nanuk #2 PRESSURE INFORMATION AND CASING DESIGN ASP Calculations: 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11] D = [(11 x 0.052) - 0.11] x 118 = 54 psi OR ASP = FPP - (0.11 x D) = 1006- (0.11 x 2150) - 770 psi 2. Drilling below surface casing (9-5~8") ASP = [(FG x 0.052)- 0.11]D = [(13.0 x 0.052) - 0.11] x 2150; = 1217 psi OR ASP = FPP - (0.11 x D) = 4493 - (0.11 x 8640) = 3543 psi Casing Performance Properties i ~ Internal Size Weight i Grade i Connection Yield Collapse ..................... ~I'6"' ................... i .......... 62"15'8""i~"~'f .......... i ..................... B ...................... ' ............................. P'EB ............................................................... :: .................................... C~5"~'t'5'i'"C'~§"ifi~ ........................ ............... 9'"'-5~8 '"' .................................................................................................................................................................................................. 53.5 ppf i E-80 BTC i 7930 ps~ 6820 ps~ ...................... 7' .............................................................................. ~ 29 ppf ' ...................................... E-80 ~ BTC-U ........................... ' ................... 8,~60 ps~' .............................. 7,020 ps~' .................................... Casing Setting Depth Rationale 16"-118' RKB 9-5/8"-2150' TVD RKB 7"-8640' TVD RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. 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. Annular Pumping Operations' Incidental fluids developed from drilling operations will be either injected into the Nanuk #2 approved annulus or hauled to the nearest permitted Class II disposal well. The cement rinsate will not be injected down the dedicated disposal well but will be recycled or held for the Nanuk #2 open annulus or injected down another Kuparuk well open annulus. The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr)in pumping operations. The Nanuk #2 surface/production casing annulus wiJl be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. -2- Nanuk #2 PRESSURE INFORMATION AND CASING DESIGN We request that Nanuk #2 be permitted for annular pumping of fluids (if production casing is set) occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 50' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2150') + 1,500 psi Max Pressure - 2842 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the casing performance properties above. Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). RECEIVED -3- ARCO Nanuk #2 PRESSURE ANALYSIS AND PREDICTION (Per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of overpressured strata was performed for the ARCO Nanuk #2 well as required by AOGCC regulations. ARCO does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells Nanuk #1, Neve #1, Alpine #1/1N1B, and Bergschrund #2/2A. Attached are the following: · Mud weight versus depth graph for these wells. · Seismic analysis for Nanuk #2. Pore pressure, frac pressure and anticipated mud weight graph. · As discussed in Ray Wydrinski's report dated 12/17/99, there appears to be no shallow hazard at the seismic line 92-03 or Nanuk #2. The change at 3000' is probably due to a lithology change and surface casing will be set above thiS depth. · A discussion of the potential for shallow gas hazards will be included in the well,plan, Also, as required by our internal SOP's a pre:spud meeting with the crews will be held prior to spudding and the shallow gas hazard potential discussed. · The 10 ppg planned drilling mud weight for this interval will also exceed the predicted pore pressure prediction of approxiamtely 9.0 ppg. TJB 3/1/00 aas oons, C.o~m"-atssior., Anchorage DRILLING FLUIDS PROGRAM(' ARCO Nanuk #2 ...................................................................................... S~ii'd-f6-9-:$18-" ....... i ........ 7""Pi;-6d"/i~fi6-~i- ?D6-~-~i~- .............................................................................................. -1"0 ...................... ~ ....................... 8;'6:'~'-172 ..................... ~--PV ................................................................................................................................ 20:26 ................................................................... 1'6:20 ............................... ~-'~ ............................................................................................. f~:25 ........................................ 1'5:20 ....................................................................................................... 5O:70 .............................................................. ~'-'l'h]fi~l"G-~] ........................................................................................ 5:15 ........................................................................ '4' :6 ...................................... ~'""']"O:Mi'~"TG~'! .................................................................................................................... -]"5:'~'0 .................................................................................... 6:8 ........................................... ?'"'A'Pl""Fil'ff~t6' ...................................................................................................................... '~"0':']'2 ............................................................................ 8':']"0 ..................................... ~'"'"~'R .................................................................................................................................................................. 9":5¥]"0 ....................................................................... g';'5¥]'0' .................................. ~"%"S6'IiB'~' ....................................................................................................................................... '~1'0% ............................................................................ ~':7% ..................................... Drilling Fluid System: 3 - Derrick FIo-Line Cleaners Pioneer Model S2-12 Desander Tri-FIo 'Low Profile' Desilter Alpha-Laval Model DMNX 418 Centrifuge Pit Level Indicator (wi visual and audible alarms) Trip Tank Fluid Flow Sensor 8 - Brandt pit stirrers Drilling Area Risks: Examination of the nearest offset wells, Nanuk #1, Neve #1, Alpine l/lA/lB, and Bergschrund #2/2A reveal no subsurface hazards such as abnormal pressure or lost circulation zones. Nanuk #2 seismic analysis is plotted and pore pressure and fracture gradient curves derived. Again, no indications of abnormal pressure or weak formations were seen particularly at shallow/depths. The mud weights planned for Nanuk #2 are conservatively based on those used during drilling of the offsets. Prudent and precautionary drilling/tripping techniques will be emphasized while drilling this well. No shallow gas hazards have been detected while drilling the Alpine development wells to the North. The 9-5~8" surface casing shoe will be tested to a maximum 16 ppg EMW formation integrity test or leak-off (whichever is least) after drilling 20 feet of new formation. MAR 02 2000 Anchorage ' ' · ' i i i 15~ olQ(~ w REC !V B 0il,.& Cas ~no. Co;.,,.os[on DRILLING TIME AND MUD WEIGHT CURVE -e--- Depth o Nanuk #1 -'-'Mud Weight: --]'-',\[~Hol-~e' . ....'__;._'__'___i._'___'__'_. ;, ..................... .... '_.'__'__.' .... _'__'_.l._' ..... ' ............ '._'..'._'_-- 1000............................. "':-~:' ' -:' -:' -~ ' ':' ' ~', ' ':' ' ," ' 'i' ':' - '," ':- ' ', .... ~' ':- - :- ' -: .... :,' -:' - ~', ' ':' ' ,' -:- ':' ' ':' ': ..... :' ' ~ ' ':' ' :'" 3O00 sooo 6000............................ :: ::::::::::::::::::::: ::: ====================== :.: :::::::::::::::::::::::::::::::::::::::::: :: :i: :i: : :i: :i: : : : :1 ::::i: :,i::i::!:::: :::::-:::--: ..... :--:---:--:--: 7000................. .,- ...... ,- . -, .... ,- .... ,- . -,- . ~- . -, . -,- . -,.. -, ..... ,- -,- . -,- -, ..... ,- . ,.. -,- . ,- . _ , . .'. . ~. . .' . .' ..... ~.- & . .~. . '., .... *. . J . .'. . .'. . .i. . !. . .,_ _ '. . .' . . . . J . .'. . ;. - .' ..... '. . '. - .' - .J ..... '- - ,'- - -'- - '.- - ~ . . _'. _'...'_ .' ..... '.. '...'.. L .... '...' . .'_ _ -' ..... , _ _'_ _ , . .'..,. - , . -'- - ' - -' ..... '- - '- - -' - -' ..... '.. , . .'.. L . . · ' ', - - ,' - ', ' ' , ..... ,' ' ? ' ', ' ' ,' .... ,' ' ', ' ' ,' - '; .... T - -, - ' ,' ' ', .... -, - - ,' ' '; ' ', ..... , - - ,- - ', ' ' , ..... , ' ' ? ' -, ' - " ' ' 0 5 10 15 20 25 30 35 Spud 3/12_/96 TIME TO DRILL (DAYS) Rig Release 3/23/96 10.8 10.6 10.4 10.2 10 9.8 9.6 ~: I&l 9.4 ~ 9.2 8.8 8.6 8.4 8.2 prepared by TJB 2/11/00 1000 2000 30OO 4000 50OO 6000 7000 8O0O MIRU Pool 6 12345678 DRILLING TIME AND MUD WEIGHT CURVE NEVE #1 Ran 9-5/8" Casing Depth -'~ Mud Weight .! Cored f/7410 t/7480 squeeze RD&MO lost returns run completion 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 TIME TO DRILL (DAYS) 12.0 11.8 11.6 11.4 11.2 11.0 10.8 10.6 10.4 10.2 10.0 9.8 ~ 9.6 9.4 9.2 9.0 8.8 8.6 8.4 8.2 jt 02/00 DRILLING TIME AND MUD WEIGHT CURVE = Depth Alnin~_ ~ !1 Ail R "~'Mud Weight O~2o. set @80,I ............ :-yr;-- 7 --:--:-~ ................ :::: :::: :::: .......... -,F-,' .... ....... ;.:_..;.' .:_~'...:..:.;.:...;.L_:.~' "~'-'~-:---;':":';'' "':":';'":'":'':"';':'~"i'- :: : ::,: :'::: :::, :,,~_;:, :: _:_;..:'_~_,'__:_\_~.:..:_:, :.;.:..:.._':.:_.:.':. '"'"' '"' ;';-' ;'":'-";"i: : : :i~! ..... '; - ' ]: .... '"'"'""':'"-"'':'""':- ~" '':' ':- ' ':- ' ;,':''; .... ,- I SidetraCk ;''',''. ,' Sidetrack "' ;'; '"' ' ;" .......... -- ' ' l* 'l -- I ' l' -- I -- l' '1 ' I ' -- l-- 'i ' I ' l' -- . I ' l' 'l ' [ i ' . --1 -- ~l'I' I i I I I I il I , I I I I I I I I I I I l ~ ":-':'~ :'"~'~':-~'", "'i":'"~':'" :,"-:'-:'~':'~ '-:--:-i t1-1-;-:--:-i-.-:--:-i-:--- i-:--:--:---:-i-i-:--- i-:--:-~-~-:-i-I~TO ~: ~o'u.9?;n~' C~'l- :--:---i-:--:-i- 10000 ;--,'---,'--~--~--,'---:--,'--: :---,'---,'--: ; ; : : Ii11 ...... I: "t, ]__,,___~.. t.o8.747. MD . .~: ; :.___,,_._,,____~__ } ~:=~ '"'-":"I-I-:'"-""''"--":'"":'"" ; .... ........... : ' ; ' I ~_ ~,~ .-:--ii!i?ili!i!--:-:-;--:--:-:-:---:-:--:-:---:-~,-:-:---:-:--:-:- ':':',~':''-:-:--:-,''l:',':''i'l':'!-'i':' ~r~.~ ~ ' ':- -:' ; -,'- 'l' ; -:' -:' ;- ' -:- -;- : -:' - - ; -;- -:- ;- ' -:- ;-,~ -:- - - : -:- -;- ;- -:-;-,~-;-'-;';'':-:--';-;';'','' ', ','',', ' <::~ 0 5 10 15 20 25 30 35 40 45 50 !;,~;~ TIME TO DRILL (DAYS) Sp~ 1/28/95 Rig Release 3/12/95 10.8 10.6 10.4 10.2 10 9.8 9.6 ~_ 9.4 [ 9.2 8.8 8.6 8.4 8.2 prepared by TJB 2/29/00 DRILLING TIME AND MUD WEIGHT CURVE --e-Depth Bergschrund ~2 "--'-Mud Weight ~ set @ 107'~. ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ---.¥'"~'-~~o~,- -; - -,- -, ..... ,-' i! : ::::;: ::: :::::: ::::;: ::: :::::: ::::;: :,: :;::: :::::: ::::;: :~: :::: :: ::::;::: :;: .:..::: ;.: 1°'5/8"sete.'~.'.Tj_:_. _,'. _:._ ..~.:_.,'__ .:_ .: ..... :'' [' ':--:--'-':--;' '::'-"' .... !--i--!--[ .... i'' i-'!" i .... !'' '! .... i" --'~'-;--~ -; ..... "-- ;--"--" ..... "- -;--"-;' .... ;'' ;' '"'' ;'-r--;-- ';-';''; .... ;' ' '"' ';" ;': .-.,' ~.- ;~¢:i; ................................... , ..................... I ................ : ' ';' '; ..... A 4000 . . _'. _'_ . .'_ _'_ LU -]- -; ..... ;- - '; ' Suspension - ~ ~ -;- -',- .... ;- -; - -;- - ',- .... :- - -;' ';- - ~ .... ," ' {- ';- ' { ' ' · . -,- -,- - ~'~ ' ' -~- - ~- ooo ,,, ......................... ~ ......... ................................. :--:--~-- ~ 6000 · - -! - - i- - : ::_': ~ ::: ::_'~ 7000 : : : :. _:_ _ ,,_ _ _,, _ . :_ _% :: ::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: i:::i :,.!,:: :i::::: i:: :i: :i:: :i: :- · - -i- - i- - - -:- - ;- -: - -;I TD ~8600 MDI-:--' , ..... ================================================== 9000 ............................ · . _'..'_ _ 2 . .' ..... '_ _ L _ .'..' ..... '.. '. _ _'..' ..... '. _ .'. _ _'_ . L .... '_ . .' . .'.. '. .... '_ . 2 . .'_ . .'. .... L . .'..'...' . -_ ~ ~---',--',---:--', ..... ',__,:__,,__,, ..... ',__':__',._', ..... ',__~__',__:_ .... ',..~._',_.;. ..... ',___',..',_.'~ .... ,:., , , 0 ?~'~1 r,o .... 0 5 10 15 20 25 30 <> "~*-,~ TIME TO DRILL (DAYS) c;~ Sp~~00 hfs ~8/~ 10.8 10.6 10.4 10.2 10 9.8 9.6 _~ LU 9.4 ~ 9.2 9 8.6 8.4 8.2 35 Rig Release 1300 hrs 2/26/96 prepared by TJB 2/29/00 lOOO 2000 3OOO 4000 5000 6000 7000 DRILLING TIME AND MUD WEIGHT CURVE + Depth Bergschrund t,t~A ---"Mud Weight 5 10 15 20 25 30 35 10.8 10.6 10.4 10.2 10 9.8 9.6 ~ 9.4 ~ 9.2 8.8 8.6 8.4 8.2 TIME TO DRILL (DAYS) Rig Release 2000 hrs 415196 prepared by TJB 3/1/00 ARCO Exploration and Production Technology Date: December 17, 1999 Internal Corr~pondence Subject: From: Telephone: Pore Pressure Prediction for the Nanuk area Seismic Lines: 86-05, 92-03 and 95-19 Proposed Wells: Nanuk #1, Nanuk g2 and Nanuk ~2C R. Wydrinski PRC-Dl139 509-4325 To: Jeff Zawila ATO-1464 J. Trantham ATO-1204 This memo is to review the pore pressure prediction for above Nanuk wells. The models used to calculate the pore pressure was based on information from Alpine, Tarn and NPR projects. Three seismic lines were interpreted each having a proposed well location. Nanuk #1 and Nanuk #2 have normal pressure with no apparent shallow hazard problems and line 95-19 had questionable data that causes Nanuk #2C to appear to have some shallow hazards. Seismic Processing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velodty field that is used as input. This velocity field is generated by picking velocities at every fourth CDP location with an automated high resolution velocity analysis program (UHCI process developed by AEPT). This process produces a very accurate and densely sampled velocity field to cover each CDP location. The RMS velocities that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instability 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 pore pressures. The compaction trend looked very similar to what had been observed in Alpine, Tarn and NPR, giving reason to use the same models for Nanuk. 1) A Normal Compaction Trend Line (NCTL) was determined for each seismic line. The slope of this line was 4.0~ to 4.5.5 with an intercept of about 165 to 180.. Anchorage 2) From the Alpine and Tam study, a Translational Trend model was developed to convert the A^T to equivalent mud weight (PP). This equation is: PP = C2 * A^T2 + C1 * AAT + C0 where C2 = -2.5769 e-04; C1 = .119231; CO = 8.94231 4) The fracture gradient was determined using the Eaton Method where the inputs are the bulk density (using Gardner's equation and the seismic DT) and Poisson's Ratio (using the West Cameron model). Seismic Line WKE 86-05 (No Shallow Hazard) Figure #1 is the pore pressure prediction across seismic line WKE 86-05 with depth. The warmer the color the higher the mud weight (pore pressure). There are no shallow hazard intervals over this seismic interval. The source rock or increase in pressure will begin at the 6,000' to 7,000' range. Figure ~2 is the pore pressure prediction with time. Figure #3 is the pore pressure prediction for Nanuk #1. The left portion of the figure is the seismic travel time (black curve) and the NCTL (red line). The right portion of the plot is the pore pressure prediction (blue curve), fracture gradient (red curve) and the overburden gradient (black curve). There is no shallow hazard for this well. Seismic Line WKE 92-05. (No Shallow Hazard) Figure #4 is the pore pressure prediction across seismic line ~ 92-03 with depth. The warmer the color the higher the mud weight(pore pressure). There are no shallow hazard intervals over ~s seismic interval.. There appears to be a lithology change at 3,000 but there is a possibility of an increase in mud weight. The source rock or inCrease' in pressure will begin at the 6,000' to 7,000' range. Figure #5 is the pore pressure prediction with time. Figure #6 is the pore pressure prediction for Nanuk #2. The left portion of the figure is the seismic travel time (black curve) and the NCTL (red line). The right portion of the plot is the pore pressure prediction (blue curve), fracture gradient (red curve) and the overburden gradient (black curve). There is no shallow hazard for this well. Seismic Line NPR 95-19 (Possible Shallow Hazard with Questionable Data) Figure ~ is the pore pressure prediction across seismic line N-PR 95-19 with depth. The warmer the color the higher the mud weight (pore pressure). The data from CDP 2031 to 3900 appears to have much noise below 1,000' where potential shallow hazards may exist. This questionable data indicates shallow hazards may exist. Further inspection of the seismic velocity is necessary. Figure #8 is the pore pressure prediction with time. Figure #3 is the pore pressure prediction for Nanuk g2C. The left portion of the figure is the seismic travel time (black curve) and the NCTL (red line). The right portion of the plot is the pore pressure prediction (blue curve), fracture gradient (red curve) and the overburden gradient (black curve). The potential shallow hazard from 1,500' to 1,700' is probably due to poor data rather than pressure. A review of the velocity computation is necessary. Conclusions: 1) Review the seismic velocity for Nanuk #2C to determine if the shallow hazard exists or if it due to noisy seismic data. 2) Nanuk #1 and Nanuk ~ have no indications of shallow hazards.. 3) The slope and intercept for the Normal Compaction Trend Line from the Alpine, Tarn and NPR study is the same as this Nanuk study. 4) There are some lithological effects due to kerogen that give indications of an increase in pore pressure between 6,000' and 7,000'. If there are any further questions, please call me at the above number. ydrinski Anchorage ~o~t: NANUK I~~ARCO Technology and Operations Services Cross Section:WKE92-3 !~~ Pore Pressure and Fracture Gradient System ePDataSct: 180_4SPLE_PPG Seismic Datasct: WKE92-3_STK_Z 12/16/99 Ray Wydrinski Scale: Vertical lin=2104ft, Horizontal lin=394cdp NANUK2 2 2222222222 2 2222223333333333333333333344444444444444444444555 5 CDPo 1 122334455 6 778899001 12233445566778899001 12233445566778899001 1 0 0505050505 4 0505050505050505050505050505050505050505050505050 6 000000 000000000000 00000 MSL 0.0. 1000.0 3000.0 4000.0. D E 5000.0 P T H (ft) 6000.0 7000.0 8000.0 ~.0 "~1000.0 Method: Trend Curve NCTL: 180_4S Model: PLIESTOCENE ppg 8.00 8.50 9.00 9.50 10.00 10.50 1.00 1.50 2.00 12.50 13.00 13.50 14.00 14.50 15.00 15.50 16.00 -- 16.50 17.00 17.50 18.00 18.50 19.00 12000.0 I~~ARCO Technology and Operations Services ~~' Pore Pressure and Fracture Gradient System Project: NANUK Cross Section: WKE92-3 PP DataSet: 180_4SPLE_PPG_T Seismic Dataset: WKE92-3_STK Method: Trend Curve NCTL: 180_4S Mode]: PLIESTOCENE T I M E (ms) 12/16/99 2 CDP o o o.o2 R~ Wydfins~ S~e: Veffi~ 1 ~ = ~8 ~ec, Ho~n~ 1 in = 3~ ~ NA~ 2222222222 222222233333333333333333333444444444444444444445555 1122334455 677889900112233445566778899001122334455667788990011 0505050505 405050505050505050505050505050505050505050505050506 0000 0000 0000 200.0 400.0 600.0 800.0 1000.0 1200.0 1400.0 1600.0 ppg 8.50 9.00 9.50 10.00 10.50 ll.00 [ 1.50 2.00 2.50 13.00 13.50 14.00 14.50 15.00 15.50 16.00 16.50 17.00 17.50 18.00 18.50 19.00 ARCO Exploration and Productio.n Technology Pore Pressure and Fracture Gradient System 12/16/99 Ray Wydrinski Project: NANUK Well: NANUK2 NCTL: 180_4S DEPTH (Datum set to MSL) -11 ...... ~ ..... ~---+---~ ..... H--i-$ :1-4-}-4-N,-[~!4. ...... i ..... M----[ ...... *--*--~-~ .... H-i--i-' -f-i, =, 'Ht[' -ii-H ,:,:-[ '!itl ...... ] ..... ["--['-'-[-'- [ [ J i [ i ~ i Jill ...... l ..... b---L---b--~--+--+-+--} .... +-+++- -.-~++- -H+~. ~ ...... i ..... ['"T'"["'[-'T'-~--O .... ~'~-ri' 'i'-['~-~' -~-~-j7 ... '-'"T--T--T---[ ......T-T'!'-'[ ..... T-i--!-T' -r'[TT' Ti-i. I .... : ..... i ..... [---4--4 ...... $--,-q--4 .... ~--$-~--i-. q-4-1-~-. ,i-i-14l ++H. : ..... J ..... [----[----[ ...... ~--H---J .... H-J--4-H-JJ.-j-IJU}]-j-[~t~J-H-[ .~ ~JJ ~11~ ...... i ..... L----L--4 ...... ;--;-L-4 ....$-~--Lq-. q-4 ~- - ~ ..... J----f---N---:H--f--J .... H--H~. :~- ~'f-Nh HJ~J' J-H- ......j ..... ,"--,-'--,---,--,--,--,---,-' ~-'~-~--~-4-' -f -Jr -N-['[' '~tN' J-H~ ...... i ..... ~----L-L--'.--g--H--4--i--4--H--L -* [-Lg. 4-H4. -Bg~-[. ..._._?____~.__.~___?_ ...... ~.~ .... , ..... .?~, .... ...... , ..... i-J- -~ ,...H.~i _~_~_~_~. _[~_~. ...... ,____.~_.._,_.._~ ...... ,_.,__~___~__,__,,__,_. _,_,.,..,_, _,_, 8~ ~ i [ [ FiT] f T-T-i"N -rTFT' TF['N TNT tH7 T!T[ ...... i.---&---L--~--~ ...... ~ ..... ~----,----~--- h-+--+-+ .-$-$q--4- -L-H-C- 4444. -Hq4. ...... ~ ..... ~----,----, ...... .--. .... ,-- ~-H--J-.-N-~.-J-J4-h4~J-J. ...... k---N----k-H--+-.-+ H--H-'-t-H-f-H{h ttH-!rte ...... J ..... k-"[-'"h'-'--+-- k- ~+-+++' +-~+*' -,-,-H~ ++~+ ~-,-~ - r ............ Ifil: 40 ~ 80 I~ 120 1~ NCTL Intercept at GL = 189.43 Logarithmic Slope = -4.5e-05 Nanuk #1 (Line 92-03 CDP 2643) FEET -11 10000 8 9 10 11 12 13 14 15 16 17 18 19 20 PPG 180_4SPLE_PPG 180 40GEA (Sonic NCTL: 180__4S, Poisson Model: WEST_CAMERON) 180_4WC_FGEA (Sonic NCTL: 180_4S, Poisson Model: WEST_CAMERON) ARCO Alaska, Inc. Doyon 141 Diverter Schematic 21%" 2,000 psi WP DRILLING SPOOL wi 16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) RECEIVED ARCO Alaska, Inc. DOYON 141 13-518" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE /1 w/hydraulic actuator DSA 13-5/8" 5,000 psi WP .......~1 / x 11" 5,000 psi WP ~-~ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE i0N ;/hydraulic actuator CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL L._l~' w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP wi pipe rams NAN U K #2 Rev. 2 Depth vs Time Rev. 11/8/99 -1000 -2000 -3000 MIRU Drill 12-1/4" I Set 9-5/8" csgl -4000 -5000 -8000 -9000 -10000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Days Fiord 5 Time-Depth Graph.xls, jt 2/28/00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-12'15 March 1, 2000 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill ARCO Nanuk #2 Surface Location: 465' FNL, 864' FEL, Sec. 25, T'1'1N, R4E, UM or ASP4, NAD 27 coordinates of X=377,335 & Y=5,954,678 Target & BHL: '1160' FNL, 37'18' FEL, Sec. 25, T'11N, R4E, UM CONFIDENTIAL Dear Commissioner Christenson: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the Nanuk #2, located approximately 4 miles south of the Alpine Development. This well will be accessed via ice road originating at Kuparuk's 3H Pad, drilled using Doyon Rig #141, tested and permanently abandoned prior to spring breakup. Attached is the information required by 20 ACC 25.005 (c) for your review. There are no shallow hazards expected at Nanuk #2 (see attached graphs). The nearest offset wells indicate no overpressured intervals or lost circulation zones. There will be no reserve pit for this well. Waste drilling mud will be hauled to a KRU Class II disposal well. If a production casing string is set in this well ARCO requests that Nanuk #2 be permitted for annular disposal of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As in the past ARCO would submit a 10-403 Form to the Commission with the appropriate technical information. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. If this well is tested, the produced fluids will either be hauled to Kuparuk for recycling or injected into an appropriate disposal well or the produced fluids will be reinjected into the Nanuk #2 wellbore. Please note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating, as is the usual case while drilling wells in and near the Kuparuk River Field or the Alpine Development area. If you have any questions or require any further information, please contact me at 263-4603 or Tom Brassfield at 265-6377. Sincerely, Paul Mazzolini Drilling Team Leader Exploration/Tarn Team Leader Attachments cc: Nanuk #2 Well File RECEIVED NaSa 0il & Gas Cons. C0mm'mst0n ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company Nanuk #2 Lease Designa~on Subject: Nanuk ~2 Lease Designation Date: Mon, 6 Mar 2000 10:19:45 -1000 From: "Tom J Bmssfield" <TBRASS@mail.aai.arco.com> To: tom_maunder@admin.state.ak, us CC: steve_davies@admin.state.ak, us, "Paul Mazzolini" <PMAZZOL@mail.aai.arco.com> Tom, we had an incorrect lease designation on the Nanuk #2 permit to drill. The correct lease designation is ADL 354209 ALK 4700. Any questions, please call. Thanks, Tom @ 265-6377 1 of I 3/7/00 8:07 AM ARCO Alaska, Inc. ~ AAi::':'PAY~B~Es · P~:.O. BoX :.-:,10277:6 Anchorage~ 'AK'::.'99510-277'6 PAY TO THE ORDER OF: STAT~E.:OF ~ALASKA ,. ,: ALASKA OIL. &;::'GAS CONSERVATION COMM! 3.001 PORCUPINE DRIVE 20509 3593 FEBRUARY 23, 2000 . . $'~, ~VOID'.AFTER' 90 {DAYS EXACTLY *******~***..1~00 DOL~S AND O0 CENTS $******* Th~¥'F:'i~$t National Bank .of Chicago-0710 Chicago, Illinois Payable Thro. ugh..Republic Bank · She lbyv ii,[ !;e; 'Kent ucky:' TRACE NUMBER:, :?:205093593 j,-' DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS January 26, 2000 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Attention: .James R. Winegamer Senior Landman Subject: Request to Commingle Colville River Unit Production, Nanuk #2, With Kuparuk River Unit Production Dear Mr. Winegamer: ( '~' WYKNOWLES, GOVERNOR 550 WEST 7TM AVENUE, SUITE 800 ANCHORAGE, ALASKA 99501-3560 PHONE: (907) 269-8800 .- FAX: (907) 269-8938 SR E/S ENG "' SR ENG ,.~ ENO_ .. ~N~o ,,, _ go_ASST STAT TECH ~TAI: TECH , , , _ , , , ,, By letter, dated January 17, 2000, ARCO Alaska, Inc. (ARCO) applied for approval to commingle test production generated from the Nanuk #2 well in the Colville River Unit (CRU) with production from the Kuparuk River Unit (KRU). Nanuk #2 will have a bottomhole location in ADL 380077 (CRU Tract 73). I approve the commingling of the test fluids from the Nanuk #2 well with KRU production. Since the well is being drilled and tested from an ice pad, this approval is only until June 15, 2000 or the conclusion of Tundra Travel, whichever is later. A status report of the testing operations must be provided to the Division of Oil and Gas on or before August 15, 2000 unless the Division grants an extension. The status report should list the spud date of the well, the start and stop dates of each testing period, and state whether the well(s) are capable of producing or contributing to production of hydrocarbons in paying quantities. 11 production fron~anuk~shall be allocated to ADL 380077. The lessees, ARCO, Union Texas AAlaska, and Anadark"6'?~troieum, shall individually account for the production allocated to the lease and commingled with KRU production on their monthly royalty reports. The monthly KRU Operator's Report provided to the Division should separately account for the CRU production, by individual lease, commingled with the KRU production. Sincerely, Director KRU.CRU Nanuk#2Ops.doc RECEIVED "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10- 403 prior to the start of disposal operations. The Commission will not authorize annular disposal into another well not located on the same pad or platform unless the operator dcmonstrates that compliance'"~ with thc limitation established in 20 AAC 25.080(d) is imprudent. Therefore, injection into another "Kuparuk Well Open Annulus" as described in your application can not be approved at this time. // WELL PERMIT CHECKLIST . COMPANY ~~~ WELL NAME/~/4~JdK FIELD & POOL" ~ .,~/. INIT CLASS EX/::)/_,.- ~/~-z:>f-~l~::~/~) GEOL AREA . ADMINISTRATION 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 .... (.~ ~ N 6. Well located proper distance from other wells .......... ~ ? N 7. Sufficient acreage available in ddlling unit ............ ~ ~ N 8. If deviated, is wellbore plat included ............... (,~ ~ N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. ~ l N 11. Permit can be issued without conservation order ........ (,3 ~. N AP~ DATE 12. Permit can be issued without administrative approval ...... ~.~ ~ N ~ 7,- ~, ~/::~ 13. Can permit be approved before 15-day wait ........... ~) N ENGINEERING GEOLOGY 30. 31. 32. ~,/~R DATE 33. __ ~ -~ 34. ANNULAR DISPOSAL35. APPR DATE u~ 31qloo / dev __ redfll ~ serv __ wellbore seg __ U. T# /r/:',,¢. 14. Conductor string provided ................... ann. disposal para req ~ ON/OFF SHORE 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... Y N 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~(~L%,.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N Permit can be issued w/o hydrogen sulfide measures ..... Da resented on otential over ress e nes~'~ _ ~a ~ . . ~. p ~ ...... ~e~smlc analysis o~ snallow gas zones ............. Seabed cond~bon su~ey 0f off-shore) .............. ~ Contact name/phone for weekly progress repods [explorato~ o.ly]~U (B) will not contaminate freshwater; or cause drilling waste... to su~ace; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recove~ from a pool; and (E) will not circumvent 20 ~C 25.252 or 20 ~C 25.412. GEOLOGY: ENGINEERING: UlClAnnular COMMISSION: Comments/Instructions: · CO O Z c:~nsoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify'finding information, information of this nature is accumulated at the end of the file under APPEN. DIX~ ., No special'effort has been made to chronologically organize this category of information. · : . .. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu May 11 09:55:24 2000 CONFID[NTiAL Reel Header Service name ............. LISTPE Date ..................... 00/05/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/05/11 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 EXPLORATION MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-00002 D. LABRECQUE M. WHITLEY RECEIVED Nanuk 92 501032033200 Arco Alaska, Inc. Sperry Sun 05-MAY-00 JUN 01 ?.000 Alaska 011 & Gas Cons. Commission AnchOrage MWD RUN 2 AK-MM-00002 B. HENNINGSE M. WHITLEY MWD RUN 3 AK-MM-00002 B. HENNINGSE M. WHITLEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 5 AK-MM-00002 B. HENNINGSE M. WHITLEY 25 liN 4E 464 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 864 40.30 38.80 9.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 118.0 8.500 9.625 2219.0 8.500 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD.RUNS 2,3, AND 5 ARE DIRECTIONAL WITH DGR, EWR4, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). RUN 4 IS ROP ONLY OVER THE CORED INTERVAL 7072'MD, 6200'TVD TO 7193'MD, 6322'TVD. MWD DATA IN THIS INTERVAL WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE RUNNING. IN THE HOLE FOR MWD RUN 5, AND IS PRESENTED WITH RUN 5 MWD DATA. ROP DATA FROM RUN 4 IS ALSO PRESENTED IN THE MAD PASS INTERVAL. 4. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GAMMA RAY LOG OF 04/02/00 '(SWS AIT GR). LOG DATA AND HEADERS RETAIN THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1-3, AND 5 REPRESENT WELL NANUK #2 WITH API#: 50-103-20332-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9112'MD, 8242'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. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX FIXED HOLE SIZE). SNFA = SMOOTHED FAR DETECTOR'S AVERAGE COUNT RATE. SNNA = SMOOTHED NEAR DETECTOR'S AVERAGE COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). CURVES WITH A "M" SUFFIX DENOTE MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" MUD WEIGHT: 9.6-9.9 PPG MUD FILTRATE SALINITY: 250-350 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; ~11 bit runs merged. .5000 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 51.5 9059.5 ROP 91.5 9113.5 RPX 103.0 9069.0 RPS 103.0 9069.0 RPM 103.0 9069.0 RPD 103.0 9069.0 FET 103.0 9069.0 NCNT 2203.0 9016.5 FCNT 2203.0 9016.5 PEF 2203.0 9053.0 NPHI 2203.0 9016.5 RHOB 2216.5 9053.0 DRHO 2216.5 9053.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR EQUIVALENT UNSHIFTED DEPTH 51.5 2083.5 2097.0 2100.0 2102.5 2111.0 2117.0 2129.0 2138.5 2142.5 2147.0 2165.5 2171.0 2175.0 2211.5 2215.5 2219.0 2226.0 2232.0 2238.5 2253.0 2256.0 2263.0 2278.0 2285.5 2288.0 2295.0 2306.0 2313.5 2315.0 2317.5 2320.0 2338.0 2341.5 2344.0 2346.0 2366.5 2370.5 2374.5 2380.5 2384.5 2386.0 2387.0 2392.5 2394.5 2396.0 2397.5 2399.0 2401.0 2406.0 2410.0 2411.5 2415.0 2416.0 2421.5 2433.0 2436.0 2441.0 2444.5 2449.0 2452.0 56.5 2088.5 2102.0 2105.5 2107.5 2116.0 2124.0 2135.0 2145.5 2148.0 2152.0 2170.0 2177.0 2180.5 2217.5 2221.5 2226.5 2233.0 2239.0 2245.5 2260.0 2262.5 2270.0 2285.0 2292.5 2295.0 2302.0 2313.0 2322.0 2323.0 2324.5 2327.0 2345.0 2348.0 2352.0 2353.5 2374.0 2378.0 2382.0 2388.0 2392.0 2394.0 2395.0 2400.0 2402.0 2404.0 2405.5 2406.5 2409.5 2413.0 2417.5 2420.0 2423.5 2424.5 2428.5 2440.5 2443.5 2448.5 2452.0 2456.0 2459.5 2455.0 2461.0 2462.0 2465.5 2471.5 2472.5 2503.5 2506.0 2508.0 2510.5 2513.0 2531.0 2538.0 2553.0 2557.5 2559.5 2572.5 2580.5 2584.5 2599.0 2601.5 2617.0 2622.0 2625.5 2628.0 2630.5 2632.5 2633.5 2645.0 2651.5 2655.5 2657.5 2661.0 2662.5 2667.5 2687.5 2691.0 2705.0 2707.5 2713.0 2718.0 2722.5 2738.5 2746.0 2748.5 2764.0 2767.0 2768.5 2773.5 2777.5 2779.5 2794.5 2876.5 2888.0 2895.5 2899.0 2904.5 2919.5 2926.0 2930.0 2944.0 2462.0 2468.5 2469.5 2473.0 2478.0 2479.0 2509.5 2512.5 2514.5 2517.5 2519.5 2536.0 2543.5 2559.5 2564.5 2567.0 2578.5 2587.5 2590.5 2606.0 2609.0 2625.0 2629.5 2632.5 2635.5 2638.0 2640.5 2642.0 2653.0 2659.5 2663.5 2665.5 2669.0 2670.5 2673.5 2695.0 2698.5 2713.5 2716.0 2720.5 2726.0 2730.5 2746.0 2754.0 2756.0 2770.5 2775.0 2777.0 2781.5 2786.0 2787.5 2802.0 2884.5 2894.5 2902.0 2906.0 2911.5 2925.0 2932.0 2936.5 2952.5 2946.5 2957.5 2962.0 2975.0 2977.0 2982.5 2985.5 2994.5 2996.5 3003.0 3025.0 3039.5 3047.0 3049.5 3051.5 3058.0 3059.5 3065.0 3069.5 3072.5 3094.0 3096.0 3106.0 3116.0 3120.0 3127.0 3132.0 3133.5 3137.5 3140.0 3147.5 3150.5 3157.0 3162.0 3165.0 3169.5 3177.5 3198.5 3207.0 3209.5 3211.0 3227.5 '3235.0 3241.0 3247.5 3261.5 3262.5 3264.5 3267.5 3269.0 3271.0 3272.5 3284.5 3288.5 3290.5 3302.5 3310.0 3317.0 3319.5 3330.5 3333.5 2954.0 2964.0 2969.0 2981.5 2983.0 2989.5 2992.5 3001.0 3004.5 3011.0 3034.0 3048.0 3055.5 3059.0 3061.5 3068.5 3070.5 3074.0 3076.5 3079.5 3101.0 3103.5 3113.5 3125.0 3128.5 3135.5 3140.5 3142.5 3145.5 3148.0 3155.5 3158.0 3163.5 3170.5 3172.0 3176.5 3184.5 3206.5 3214.0 3216.5 3218.0 3234.0 3241.5 3247.5 3254.0 3268.0 3269.5 3271.5 3274.0 3276.0 3278.0 3280.0 3290.5 3295.0 3297.0 3310.0 3317.0 3323.5 3326.0 3337.0 3340.5 3340.0 3343.0 3348.5 3352.0 3356.5 3362.0 3364.0 3365.5 3371.0 3372.0 3389.5 3391.5 3398.0 3405.5 3407.5 3409.5 3412.0 3414.5 3420.0 3423.5 3428.5 3444.0 3452.0 3455.5 3463.0 3467.0 3472.0 3479.5 3484.5 3490.0 3496.5 3498.5 3504.0 35O5.0 3508.0 3515.5 3519.5 3521.0 3522.0 3524.5 3527.5 3539.0 '3542.5 3544.5 3547.0 3548.0 3549.5 3551.5 3555.5 3556.5 3562.0 3567.0 3568.5 3569.5 3582.5 3585.5 3616.5 3618.5 3624.5 3650.5 3654.0 3347.0 3350.0 3355.5 3358.5 3363.0 3368.5 3372.0 3373.5 3379.5 3380.5 3398.0 3399.5 3404.5 3412.5 3414.0 3416.0 3419.0 3421.5 3426.0 3429.0 3433.5 3449.0 3457.5 3461.0 3466.5 3471.5 3478.0 3485.0 3489.5 3494.0 3502.0 3503.5 3508.5 3511.0 3513.5 3520.5 3524.5 3526.0 3527.5 3529.0 3532.0 3543.0 3546.5 3548.0 3551.0 3552.5 3554.0 3556.0 3560.0 3561.5 3568.5 3572.5 3574.0 3575.0 3587.5 3590.0 3623.0 3624.5 3630.5 3657.0 3660.5 3656.0 3664.0 3669.5 3678.0 3683.5 3710.5 3715.5 3719.0 3728.5 3739.5 3741.0 3743.0 3751.0 3774.0 3779.5 3782.0 3787.5 3794.0 3801.0 3802.5 3809.5 3811.5 3822.5 3824.0 3827.5 3831.5 3835.0 3836.5 3842.5 3847.5 3869.5 3873.5 3879.5 3881.5 3883.0 3890.0 3919.5 3921.5 3925.5 3927.5 3931.5 3942.5 3943.5 4079.5 4082.5 4085.0 4087.5 4093.5 4097.0 4100.0 4103.5 4110.0 4119.5 4125.0 4136.0 4137.5 4140.5 4145.5 4168.5 4171.0 4172.5 3662.5 3670.5 3675.5 3684.5 3690.0 3716.5 3722.5 3726.0 3734.0 3745.0 3747.0 3749.0 3757.0 3780.0 3785.0 3787.5 3793.0 3800.5 3808.0 3809.5 3813.0 3817.5 3827.0 3828.5 3830.5 3837.0 3840.5 3841.5 3847.5 3852.0 3874.5 3879.0 3885.5 3887.5 3889.0 3895.5 3925.0 3927.0 3930.5 3932.5 3936.5 3948.0 3949.0 4085.0 4087.5 4090.5 4093.0 4099.5 4103.5 4105.5 4109.0 4115.0 4123.5 4129.5 4140.0 4142.5 4145.5 4151.5 4173.5 4176.0 4177.5 4177.5 4180.5 4193.0 4197.5 4199.5 4207.5 4214.0 4217.5 4218.5 4220.0 4229.0 4230.0 4232.0 4240.5 4243.0 4247.0 4256.5 4266.0 4274.0 4277.5 4290.5 4295.0 4297.5 4303.5 4313.0 4336.0 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5161.5 5165.0 5173.5 5178.0 5197.5 5227.5 5233.5 5235.0 5244.0 5251.0 5253.0 5259.5 5269.0 5277.0 4561.0 4565.5 4569.0 4572.0 4598.5 4615.5 4618.0 4627.5 4631.5 4637.5 4717.0 4751.0 4761.0 4762.5 4770.0 4793.0 4799.5 4801.0 4805.0 4815.5 4825.0 4831.5 4835.5 4860.5 4872.5 4877.0 4887.0 4890.5 4891.5 4925.5 4956.5 4960.5 4965.5 4982.0 4986.0 4991.5 5000.5 5049.0 5052.0 5054.5 5072.0 5091.0 5093.0 5110.0 5113.0 5123.0 5126.5 5166.5 5170.0 5178.5 5183.5 5203.5 5234.0 5240.5 5242.0 5251.0 5257.0 5258.5 5264.5 5273.5 5281.0 5297.0 5301.0 5325.5 5333.0 5336.5 5338.0 5341.0 5346.0 5349.0 5372.0 5407.5 5417.0 5420.0 5422.5 5425.5 5465.5 5468.0 5475.0 5480.5 5491.0 5495.0 5496.0 5503.0 5520.5 5535.0 5544.0 5546.5 5554.5 5559.5 5562.0 5565.5 5570.0 5598.0 5599.0 5602.5 5623.5 5627.0 5634.0 5646.0 5647.5 5674.5 5688.0 5690.5 5696.0 5705.5 5708.0 5709.5 5716.0 5721.0 5725.0 5744.5 575O.0 5764.0 5768.0 5781.5 5786.5 5788.5 5794.5 5797.5 5802.5 5821.5 5300.5 5303.5 5329.5 5337.0 5340.5 5342.0 5344.0 5350.5 5353.5 5376.5 5411.0 5420.5 5424.0 5426.5 5429.5 5470.0 5472.5 5479.5 5483.0 5493.5 5499.5 5500.5 5508.0 5524.5 5540.0 5549.5 5552.5 5560.0 5563.5 5566.5 5570.5 5574.0 5601.5 5602.5 5606.5 5627.0 5631.0 5638.0 5650.0 5651.5 5678.5 5692.0 5694.5 5700.0 5709.5 5712.0 5713.5 5720.5 5725.5 5729.0 5749.0 5754.5 5768.5 5772.5 5786.0 5791.0 5793.5 5799.5 5802.5 5806.5 5825.0 5825.5 5830.0 5832.0 5843.5 5847.5 5860.5 5890.0 5892.5 5900.0 5907.0 5920.0 5936.5 5944.5 5956.5 5965.5 6033.5 6045.0 6047.0 6057.0 6068.0 6139.0 6159.5 6162.0 6179.0 6188.5 6195.5 6202.5 6206.0 6207.5 6213.0 6217.5 6222.5 6232.0 6238.0 6239.5 6245.5 6250.5 6255.5 6259.0 6264.0 6266.0 6270.5 ~6275.0 6279.0 6280.5 6293.5 6301.0 6306.0 6308.0 6312.0 6313.5 6316.0 6318.0 6324.5 6340.0 6345.5 6348.5 6351.5 6353.0 6367.5 6371.0 5829.0 5833.0 5835.5 5847.0 5850.5 5862.5 5892.5 5894.5 5900.0 5907.0 5920.0 5936.0 5944.0 5956.0 5966.5 6035.0 6045.5 6048.0 6058.0 6069.0 6141.0 6163.5 6166.0 6182.0 6191.5 6198.5 6205.5 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7843.0 7849.0 7858.5 7861.5 7865.5 7870.0 7871.5 7874.0 788O.5 7882.5 7915.0 7916.5 7922.0 7924.5 7930.5 7934.0 '7940.5 7956.0 7969.5 7971.0 7973.0 8003.5 8013.0 8019.0 8021.5 8024.0 8048.5 8070.O 8102.0 8108.5 8116.5 8118.0 8120.0 8143.0 8151.0 7730.0 7734.0 7743.5 7746.0 7748.5 7753.5 7756.0 7758.0 7769.5 7771.0 7772.5 7774.0 7776.5 7778.0 7784.0 7787.5 7791.5 7802.5 7809.0 7812.0 7815.5 7820.5 7824.0 7829.5 7831.5 7842.5 7844.5 7850.5 78.60.0 7863.0 7867.0 7872.0 7873.0 7875.0 7882.0 7883.5 7916.5 7918.0 7922.5 7925.0 7931.5 7935.0 7940.5 7956.5 7969.5 7971.0 7973.0 8004.0 8012.5 8018.5 8021.0 8023.5 8O48.5 8069.5 8100.0 8105.5 8116.5 8118.0 8120.0 8142.5 8151.0 8156.5 8156.5 8159.0 8159.0 8181.5 8181.0 8187.0 8186.0 8195.5 8195.0 8201.5 8201.0 8203.5 8203.0 8206.0 8205.5 8221.0 8220.0 8224.0 8223.0 8243.5 8242.5 8252.0 8251.0 8259.5 8258.0 8280.0 8278.5 8282.5 8281.0 8296.5 8295.0 8301.0 8299.5 8304.0 8302.5 8308.0 8306.0 8328.0 8326.0 8347.5 8346.0 8350.0 8348.5 8362.0 8360.5 8365.0 8363.0 8368.0 8366.5 8370.5 8368.0 8390.5 8388.5 8412.0 8410.5 8418.5 8416.5 8424.0 8421.5 8436.0 8434.0 8443.0 8441.5 8452.5 8451.0 8467.5 8466.5 8469.5 8468.5 8477.0 8475.5 8482.0 8481.0 8500.0 8498.5 8508.0 8506.0 8517.5 8515.0 8522.0 8519.5 8524.5 8522.0 8526.0 8524.5 8528.5 8527.0 8543.5 8541.5 8547.0 8545.0 8554.5 8553.0 8560.5 8559.0 8564.0 8562.5 8574.0 8573.0 8578.0' 8576.5 8580.5 8579.5 8585.5 8584.0 8601.0 8599.5 8603.0 8601.5 8613.0 8611.5 8614.5 8613.0 8625.0 8623.0 8627.5 8625.0 8630.0 8627.5 8632.5 8631.5 8640.5 8655.0 8656.5 8659.5 8662.0 8665.0 8666.0 8678.5 8682.5 8691.5 8700.0 8701.5 8707.0 8710.0 8712.0 8714.0 8720.5 8722.5 8726.0 8728.0 8734.5 8744.5 8761.5 8762.5 8787.5 8795.0 8796.0 8800.5 8807.0 8812.0 8813.0 8816.0 8823.0 8825.5 8827.5 8830.0 8834.0 8840.0 8841.5 8847.0 8848.5 8855.0 8856.5 8861.0 8864.0 8867.5 8871.5 8878.5 8881.5 8882.5 8885.5 8887.0 8891.0 8893.5 8896.0 8906.5 8910.0 8919.5 8920.5 8925.0 8934.0 8639.0 8653.0 8654.5 8658.0 8660.0 8663.0 8664.0 8676.0 8680.0 8689.5 8698.0 8699.5 8705.0 8708.O 8710.0 8712.0 8718.5 8720.5 8724.0 8726.5 8733.0 8743.0 8760.0 8762.0 8786.0 8793.0 8794.0 8798.0 8804.5 8809.0 8810.0 8812.5 8820.0 8822.5 8824.5 8827.5 8831.0 8837.0 8838.5 8843.5 8845.0 8852.5 8854.0 8858.5 8861.0 8864.0 8869.0 8875.5 8879.0 8880.0 8883.0 8885.0 8889.0 8892.0 8894.5 8905 0 8908 5 8918 0 8919 0 8923 0 8932 0 8942.5 8940.5 8945.5 8943.5 8960.0 8957.5 8972.5 8970.5 8974.5 8972.5 8992.5 8990.5 8995.0 8993.0 8998.5 8996.5 9000.0 8998.5 9009.0 9007.5 9011.0 9009.5 9113.5 9112.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 5 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 56.5 2228.0 6947.0 7072.0 Data Format Specification Record Data Record Type .................. 0 Data SpeCification BloCk Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 , MERGE BASE 2228.0 6947.0 7072.0 9112.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 51.5 9113.5 ROP MWD FT/H 0 2242.65 GR MWD API 18.12 381.16 RPX MWD OHMM 0.61 1708.24 Mean Nsam 4582.5 18125 174.32 18045 104.419 18017 6.09502 17933 First Reading 51.5 91.5 51.5 103 Last Reading 9113.5 9113.5 9059.5 9069 RPS MWD OHMM 0.52 651.33 RPM MWD OHMM 0.19 2000 RPD MWD OHMM 0.59 2000 FET MWD HOUR 0.11 43.17 NPHI MWD PU-S 19.22 70.52 FCNT MWD CNTS 426 1227 NCNT MWD CNTS 2153 3607 RHOB MWD G/CM 1.721 2.956 DRHO MWD G/CM -0.106 0.572 PEF MWD BARN 0.71 18.03 7.78611 17933 13.4999 17933 33.2416 17933 1.15049 17933 38.9749 13628 691.292 13628 2701.15 13628 2.41533 13674 0.0393545 13674 2.44583 13701 103 103 103 103 2203 2203 2203 2216.5 2216.5 2203 9069 9069 9069 9069 9016.5 9016.5 9016.5 9053 9053 9053 First Reading For Entire File .......... 51.5 Last Reading For Entire File ........... 9113.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name... .......... STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001' Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 56.5 2187.5 ROP 96.5 2227.5 RPX 108.0 2180.0 RPS 108.0 2180.0 RPD 108.0 2180.0 FET 108.0 2180.0 RPM 108.0 2180.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 25-MAR-00 Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type .... .0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 5.46 MEMORY 2228.0 .1 37.0 TOOL NUMBER PB01462CRG8 PB01462CRG8 12.250 118.0 Water Based 10.00 92.0 8.9 450 10.0 3.500 2.852 2.350 3.950 68.0 85.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 t 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 56.5 2227.5 ROP MWD010 FT/H 0 1733.39 GR MWD010 API 18.12 213 RPX MWD010 OHMM 1.1 64.05 RPS MWD010 OHMM 1.04 264.11 RPM MWD010 OHMM 1.01 1982.86 RPD MWD010 OHMM 1.23 2000 FET MWD010 HOUR 0.19 6.51 First Mean Nsam Reading 1142 4343 56.5 199.153 4263 96.5 73.4743 4263 56.5 9.37289 4145 108 17.1778 4145 108 39.5898 4145 108 94.422 4145 108 0.706738 4145 108 Last Reading 2227.5 2227.5 2187.5 2180 2180 2180 2180 2180 First Reading For Entire File .......... 56.5 Last Reading For Entire File ........... 2227.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Previous~File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2180.5 6902.0 RPD 2180.5 6902.0 RPM 2180.5 6902.0 RPS 2180.5 6902.0 RPX 2180.5 6902.0 GR 2188.0 6892.5 NCNT 2209.0 PEF 2209.0 FCNT 2209.0 NPHI 2209.0 DRHO 2222.5 RHOB 2222.5 ROP 2230.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6850.0 6886.0 6850.0 6850.0 6886.0 6886.0 6946.5 BOREHOLE coNDITIONS MUDTYPE: ' MUD DENSITY (LB/G): , MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 29-MAR-00 Insite 65.31 MEMORY 6964.0 3.9 39.2 TOOL NUMBER PB01467HLGR6 PB01467HLGR6 PB01467HLGR6 PB01467HLGR6 8.500 2219.0 Water Based 9.60 42.0 8.9 350 5.6 4.000 2.799 5.200 3.500 72.0 105.8 72.0 72.0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR NPHI MWD020 PU-S FCNT MWD020 CNTS NCNT MWD020 CNTS RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN Min Max Mean Nsam 2180.5 6946.5 4563.5 9533 0 2058.99 180.052 9434 54.35 209.27 113.764 9410 0.61 1708.24 5.25872. 9444 0.52 651.33 5.08713 9444 0.19 2000 6.14478 9444 0.59 2000 19.8287 9444 0.26 43~17 1.04011 9444 20.41 59.27 38.995 9283 426 928.5 683.488 9283 2153 3607 2698.97 9283 1.721 2.653 2.36843 9328 -0.087 0.572 0.0384617 9328 0.56 18.03 2.58056 9355 First Reading 2180.5 2230 2188 2180.5 2180.5 2180.5 2180.5 2180.5 2209 2209 2209 2222.5 2222.5 2209 ,Last Reading 6946.5 6946.5 6892.5 6902 6902 6902 6902 6902 6850 6850 6850 6886 6886 6886 First Reading For Entire File .......... 2180.5 Last Reading For Entire File ........... 6946.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 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 ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 6838.5 7010.0 NPHI 6850.5 7010.0 FCNT 6850.5 7010.0 PEF 6886.5 7046.0 DRHO 6886.5 7046.0 RHOB 6886.5 7046.0 GR 6893.0 7052.5 RPD 6902.5 7062.0 RPX 6902.5 7062.0 RPS 6902.5 7062.0 RPM 6902.5 7062.0 FET 6902.5 7062.0 ROP 6947.0 7071.5 $ # LOG HEADER DATA DATE LOGGED: 30-MAR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.31 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 7072.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 1.9 MAXIMUM ANGLE: 2.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD $ STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER PB01467HLGR6 PB01467HLGR6 PB01467HLGR6 PB01467HLGR6 8.500 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 , Water Based 9.60 44.0 8.6 300 5.6 1.600 1.186 2.000 2.500 78.0 107.6 78.0 78.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 G/CM 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 6838.5 7071.5 6955 467 ROP MWD030 FT/H 0 97.29 46.1891 250 GR MWD030 API 60.36 129.52 100.764 320 RPX MWD030 OHMM 3.65 30.89 7.19131 320 First Reading 6838.5 6947 6893 6902.5 Last Reading 7071.5 7071.5 7052.5 7062 RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR NPHI MWD030 PU-S FCNT MWD030 CNTS NCNT MWD030 CNTS RHOB MWD030 G/CM DRHO MWD030 G/CM PEF MWD030 G/CM 3.66 30.89 7.07144 3.7 30.83 6.95141 3.92 34.7 7.31091 0.11 13.47 3.90212 24.85 51.59 35.4121 578.28 842.44 713.91 2328 3095.15 2715.36 2.343 2.59 2.51395 0.003 0.231 0.0783187 1.96 4.08 2.86509 320 320 320 320 320 320 344 320 320 320 6902.5 6902.5 6902.5 6902.5 6850.5 6850.5 6838.5 6886.5 6886.5 6886.5 7062 7062 7062 7062 7010 7010 7010 7046 7046 7046 First Reading For Entire File .......... 6838.5 Last Reading For Entire File ........... 7071.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub.-Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004' Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 6964.0 9015.0 NPHI 7011.0 9015.0 FCNT 7011.0 9015.0 PEF 7046.5 9051.5 RHOB 7046.5 9051.5 DRHO 7046.5 9051.5 GR 7053.0 9058.0 RPM 7062.5 9067.5 RPS 7062.5 9067.5 RPD 7062.5 9067.5 FET 7062.5 9067.5 RPX 7062.5 9067.5 ROP 7072.0 9112.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 (~T): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 01-APR-00 Insite 65.31 MEMORY 9112.0 .2 1.8 TOOL NUMBER PB01467HLGR6 PB01467HLGR6 PB01467HLGR6 PB01467HLGR6 8.500 Water Based 9.60 43.0 9.4 250 3.9 1.900 1.033 1.800 2.100 75.0 143.6 75.0 75.0 Depth Units ....................... Datum Specification Block sub-type.. Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD050 FT/H 4 1 68 MWD050 API 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 OHMM 4 1 68 MWD050 HOUR 4 1 68 MWD050 PU-S 4 1 68 MWD050 CNTS 4 1 68 MWD050 CNTS 4 1 68 MWD050 G/CM 4 1 68 MWD050 G/CM 4 1 68 MWD050 BARN 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 6964 9112 ROP MWD050 FT/H 11.58 414.35 GR MWD050 API 43.38 381.16 RPX MWD050 OHMM 1.22 149.33 RPS MWD050 OHMM 1.17 149.04 RPM MWD050 OHMM 1.14 135.26 RPD MWD050 OHMM 1.24 108.55 FET MWD050 HOUR 0.27 27.48 NPHI MWD050 PU-S 19.22 70.52 FCNT MWD050 CNTS 504.26 1227 NCNT MWD050 CNTS 2160 3584 RHOB MWD050 G/CM 2.258 2.956 DRHO MWD050 G/CM -0.106 0.295 PEF MWD050 BARN 0.74 6.38 First Reading For Entire File .......... 6964 Last Reading For Entire File ........... 9112 Mean Nsam 8038 4297 141.393 4081 115.75 4011 4.54835 4011 4.45809 4011 4.36368 4011 4.44219 4011 1.69528 4011 39.2116 4009 707.565 4009 2704.03 4102 2.51637 4011 0.0379481 4011 2.10045 4011 First Reading 6964 7072 7053 7062.5 7062.5 7062.5 7062.5 7062.5 7011 7011 6964 7046.5 7046.5 7046.5 Last Reading 9112 9112 9058 9067.5 9067.5 9067.5 9067.5 9067.5 9015 9015 9015 9051.5 9051.5 9051.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 00/05/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
