Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
195-215
Author: SLEMKE@mail.aai.ar¢ ,om (Sandra D Lemke) at CC2MHS1 Date: 5/7/98 9:44 AM Priority: Normal TO: Howard Okland at DOA-AOGCC CC: MMCDERM@mail.aai.arc°.com at CC2MHS1 --~ Subject: digital core data for Neve #1 ~]~-- ~ After researching the Core Lab reports in the data center and AAI's digital tight-hole archive files and OPEN RSO I conclude that AAI did not receive a digital version of the Core Labs report for Neve 1. The only digital data AAI received other than logging and directional survey data was the pre- and post frac Halliburton data. AOGCC received this data from Arco in August of 1997. ............... Original message header: >MAIL FROM:<SLEMKE~mail.aai.arco.com> >RCPT TO:<Howard Okland@admin.state.ak.us> >DATA >Received: from popl.state.ak.us ([146.63.242.13]) by jnumaill.state.ak.us (Nets cape Messaging Server 3.5) with ESMTP id AAAA478 for <Howard Okland@admin.state .ak.us>; Thu, 7 May 1998 09:44:26 -0800 >Received: from inetgl.Arco. COM ([130.201.119.253]) by popl.state.ak.us (Post.Of fice MTA v3.1.2 release (P0205-101c) ID~ 0-44072U100L100S0) with ESMTP id AAA96 for <Howard_Okland@admin.state.ak.us>; Thu, 7 May 1998 09:44:33 -0800 >Received: from mail.aai.arco.com ([136.226.206.36]) by inetgl.Arco. COM (8.8 .5/8.8.5) with SMTP id MAA08844 for <Howard Okland@admin.state.ak.us>; Thu, 7 May 1998 12:44:12 -0500 (CDT) ,>Received: by mail.aai.arco.com(Lotus SMTP MTA SMTP MTA vl.l.04 (495.1 10-24-19 97)) id 892565FD.0060D559 ; Thu, 7 May 1998 09:37:40 -0800 >X-Lotus-FromDomain: ARCO >From: "Sandra D Lemke"<SLEMKE@mail.aai.arco.com> >To: Howard Okland@admin.state.ak.us -- >cc: "Mark M McDermott"<MMCDERM@mail.aai.arco.com> >Message-ID:<8A2565FD.0066719A.00@mail.aai.arco.'com> >Date: Thu, 7 May 1998 09:44:40 -0900 >Subject: digital core data for Neve ~1 >Mime-Version: 1.0 >Content-type: text/plain; charset=US-ASCII End of message header. ARCO ~L~SK~ CO Alaska, Inc. , - Neve #1 F'VPfP APl WL HTHP L:'~0 p~ Final Report HTHP 5O0 pli I'-Io~o Chlo~id~ r~3m ~1 % ES LG$ r~ To~l ~d FI:IX NO. : 9872656224 23-Apr-96 lb,p~ (~:,m,m 7700' L¢';~¢~ $18,783 7"@ 7679' 12-29-97 11 :lTR P.81 LDay .~ ~inco ,~ud/Ee~. Daily Drilling Report m~ 7700' $2'148'06"4 Mud wt. Dr~g rq DCL ! N/A (~F~I.~ w1 ~d r~nn g3~ ~.nd TIME 0600-0600 SUBTOTAL Operations From 0600 - 0~oo 18 sx cement to fill annulus. Weld on plate w/followin_g information, ARCO, Alaska inc. Neve #1 ADL 380075 APl #50-103-20231 2440' FWL, 465' FNL, S14-T12N-R4E, UM Back fill hole. Demob equip_ment. Scrape pad. :d Nabors c~mp at t000 hfs 4-22-96, AOGCC rep Lou Gramaldi was notified of P&A b.U.!..did not witness ..... PLUGGING ~ LOCATION CLEAR~. ~E REPORT State of Alaska .ALASKA OIL & GAS CONSERVATION COMMISSION Lease Memcrand'~_~ To File: APi No. Well Name Operator Location · Spud: ~- 14-~ , TD: '~o0' , C~npleted ~-LS-~ Nots casing size, wi, depth, cmt vol, & .mrocedurm. Review the well file, and-comment on plugging, well head s uatus, az~d location clearance - provide loc. clear, code. , T6& ~' Well head ~= off: ' ~0." ~lzs ;~ ' ' ' ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 8, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Neve #1 (Permit No. 95-215/96-081) Report of Sundry Well Operations Dear Mr. Commissioner: ARCO Alaska, Inc., as operator of the exploration well Neve #1, is sending the "Report of Sundry Well Operations" (form 404), as requested. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of the well. If you have any questions regarding this matter, contact me at 265-1492 or Sharon Allsup-Drake at 263-4612. Sincerely, F. Johnson Drilling Engineer Kuparuk Development FCP/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging X Perforate Repair well Other __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2440' FWL, 465' FNL, Sec. 14, T12N, R4E, UM 6. Datum elevation (DF or KB) RKB 35' Above SL 7. Unit or Property name N/A 8. Well number Neve #1 feet At top of productive interval Same At effective depth At total depth Same 9. Permit number/approval number 95-215/96-081 10. APl number 50-103-202~1 11. Field/Pool Wildcat 12. Present well condition summary Total Depth' measured 7700' true vertical 7700' Effective depth: measured true vertical Casing Le n gt h Structural Conductor 8 0' Surface 1 8 0 6' Intermediate Production 7 6 5 2' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size feet Plugs (measured) Plug #1 inside tubing @ 7155'-7459' feet Plug #2 inside tubing @ 6672'-7046' Plug #2 inside 3.5" x 7" @ 6846'-7046' feet Junk (measured) Plug #3 @ 263' to surface feet Plug #4 surface to 1841' Cemented Measured depth True vertical depth 16" 300sxAS I 120' 120' 9-5/8" 325 sx AS III & 1841' 1841' 575 sx AS I 7" 405 sx Class G Latex 7 6 7 9' 7 6 7 9' J-4 Sand Test Perfs, 7268'-7376'; 7" Casing Squeeze Perfs, 7220'-7222' same as measure depth 3.5" 9.3# L-80 EUE 8rd Mod, to surface with tail at 7265' Baker FB-1 @ 7240' and Baker FHL @ 7145' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Productio~fll3~10~_Ot~tion Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as' Water Injector__ Oil __ Gas Suspended (EXPLORATIQN) Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed J/~ ~____~-~1,~,,-~ Title Drilling Engineer Form 10-404 Rev~65/17/89 Date SUBMIT IN DUPLICATE ORIGINAL Well Name: WELL SUMMARY ARCO Neve #1 ORIGINAL APl #: 50-103-20231-00 Location: WKE 92-02, sp. 1258 ASP: x=370,251 y=5,965,357 zone:4 Lat.: 70.313528 N Long: 151.051560 W S/T/R: 465' FNL, 2440' FWL, sec 14, T11N, R4E Lease Number: ADL 380O75 Rig: Pool 6 Elevation: G.L. = 12' K.B. = 30' Spud Date: February 14, 1996 Total Depth: 7700' MD (-7656' SS) driller TD Date: Completion Date: Completion Status: Formation @ TD: March 5, 1996 March 16, 1996 Plugged & Abandoned Jurassic Kingak Production Tests: Cased hole DST Perfed interval from 7268' to 7376' MD. Pre-frac flowed 249 BOPD at 190 psi FTP with a GOR of 616 SCF/STB. Oil gravity was 41° APl and gas gravity was 0.84. Neve was frac'd with 100 Klbs of sand. Post-frac flow was 1110 BOPD at 160 psi FTP and a GOR of 776 SCF/STB. Oil gravity was 40° APl and gas gravity was 0.81. Geological Tops: MD SS Base Permafrost 717' -687' Top West Sak 970' -940' Top Shale Wall 2396' -2366' Top Albian 4076' -4036' Top Albian B 5313' -5283' Top Albian C 5673' -5643' HRZ 6750' ~ -6720' K-1 7014' ' -6984' LCU 7002' ~ '~ '~ ~ ' -6972' Top Jurassic 7264' -7234' Total Depth (driller) 7700' -7670' page 2 Conventional Cores: Aluminum barrel 4" inner diameter Core #1 - Cut 7259'-7266' Recovered 7159'-7165.5' Core #2 - Cut 7276'-7336' Recovered 7276'-7335.0' Attempted core #3, but lost circulation prior to coring. (7'/6.5') (60'/59') Logging Runs: Two attempts were made and wireline could not make it past 2600'. Open hole logs were abandoned and the well was cased. Cased hole GR/Neuton: 6830' to TD MWD gamma ray/resistivity: surface to 7200' Mudlog: surface to TD Sidewall Cores: none J?~¢ 181996 Aia~ka Oil -': '~' '''''~'' 9 5 .... 2 ! 5 END rDF WELL RPT ,~'"~'OCH {}6 / 0 3/' 9 6 9 b ~-2 i 5 Ai'"e dr'y W a s A F"e We l I SRF:CE W !... L -rEST d~:'t-ch sampies r"equi:r'ed? Anaiysi's & descr'i'pt'Yon n o R e c e i' v e d 'P ~v ex~ ) n o r-] ARCO Exploration Company El ARCO Oil and Gas Company 4~. r-~ ARCO Alaska, Inc. 4~ Record Of Shipment Of Confidential Information District' Alaska AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 Fro m: ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Attn.: Kelli Thibodeau (907)265-6240 (X) Enclosed ( )Under separate cover ( )Via . /'Alpine 3 Well Summary Report as Displayed /Bergschrund 2 Well Summary Report as Displayed /Bergschrund 2A Well Summary Report as Displayed by ARCO by ARCO by ARCO / Sidewall Core Description Run 1 as Displayed by ARCO / Sidewall Core Description Run 2 as Displayed by ARCO -/Nanuk I Well Summary Report as Displayed by ARCO / Sidewall Core Description - Rotary as Displayed by ARCO . ,. Neve 1 Core Report as Displayed by ARCO r Well Summary Report as Displayed by ARCO ~ Core Chip Description as Displayed by ARCO ,.. Core Chip Description as Displayed by ARCO ~emptation 1 Well Summary Report as Displayed by ARCO /'"Temptation lA Well Summary Report as Displayed by ARCO eL,- oo~ c~b- Note - Plea, se verify and acknowledge receipt, by signing and returning a copy of this transmittal. Signed~0j~ Date 08/16/96 Receiv Date Remarks: Please Note that all included information is CONFIDENTIAL. R ~ C r-IV F P AUG 1 9 1996 Alaska 0il & Gas Cons. Commission Anchorage TONY KIVOWLE$, GOVERNOR ~KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 23, 1996- Land Department, ATO 1470 David Sutter, Manager ARCO Alaska, Inc. P O Box 100360 Anchorage, Alaska 99510-0360 Re: Location Clearance, Various North Slope Wells Dear Mr. Sutter: On July 9 and 10, 1996 our representative, John Spaulding, accompanied your Larry Brown on a location clearance inspection of various North Slope locations. He recommended Location Clearance for the following four North Slope exploratory wells: Well Name PTD No. Neve # 1 95-215 Alpine #3 96-007 Nanuk #1 96-057 Temptation #IA 96-074 Final Location Clearance is hereby approved for the four above listed ARCO North Slope exploratory wells. The Commission will require no additional work on subject wells; however, ARCO remains liable if problems with the wells occur in the future. David W. Jo ton cc: Blair Wondzell [car4r~ TO: AL,.,O Alaska, Inc. AtlanticRichfi¢ldCompany AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 DATE: July 22, 1996 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the foilowinq data: REPORTS as Displaye by Halliburton- Surface Well Test February-(contains 3.5" floppy with digital data) q~'--0~-~ Alpine lB ~'~3 Bergschrund 2~ If you have any questions comments Please call me at (907) 265-6240 or Email me lan kat @ expl. aaL arco. com. RETURN SIGNED COPY TO: ARCO Alaska, inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: RECEIVED JUL 2 3 1996 2of2 Approved for transmittal by: F.M. HoneYcU~ Manager, No~h Alaska ExplOration TO: aRCO Alaska, Inc. AtlanticRichfieldCompany AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 DATE: July 11, 1996 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the followinq data: Alpine 3 Please replace your current data with the following corrected data. 6" Open Hole Edit Modified LDWG Library Tape CDR CDN DSl LDT CNTG ~ I LIS Tape Verification Listing -- 3.5" Floppy Depth Adjusted Directional Survey ~ Please destroy the incorrect data: ~ ~ ~ l ~ ~ ~'~ c[ (~ ~ ~ REPORTS 3IY- I Copy Nave I Core Analysis Report as displayed by Core Laboratories v-" If you have any questions please call me at (907) 265-6240. Keili RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 RECEIVED JUL 1 2 1996 Alaska Oil & Gas Cons. Co~.mt~sion Anchorage Received by: DATE: Approved for transmittal by: - F. M0}-Ioneycutt Manager, North Alaska Exploration MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: .David J°h,g~}), DATE: July 9, 1996 Chairman THRU: Blair Wondzeli, ~ FILE NO: i991godd.doc P. I. Supervisor T/rs- '- --- ,-FROM-:-... John Spaulding,Ct~r.. -i. SUBJECT: Location Inspection; ..... ., ... ..... ..:.. Tuesday July 9, 1996: I traveled this date to ARCO's wildcat well NEVE #1 to inspect the area for a final location clearance. The AOGCC location report is attached for reference. .-. The area over the well-was wetl.mounde_d with gravel for good drainage. The rig '- ~.' _ ----~=-';~-~d--ca_n~'l°cation-was clean ~nd-left [r~ a' naturat-~%.'~_,~.' ~ -- ~' i'.- .;izJ~- -: --_: - 2:.v: :_" :'%_ '-..7:,~ .~¢.' -. ~:, ~ - _ ~. _ :-_ ~-:-~'% :..' 4_ i '~ :::'.-. ': - ~-=. ~ - --~- -- -:--. -~. l.-:~:~::~ :' 7 :.'_ .:- ~7 :.:._ .... - ~_~:. Summa~: I inspected, the N_EVE ¢1 location and recommend it for'fin~l- -location clearance. -- ; '---:'"'~,;~:'~': ..... -~--~-."~':' '- ---%'~ ,:==~'-'~"-.-' ..... 4; -" ..... .~..'c ._-:~1,52:~:;_'.~'~':., '~',-~ "-"~4:--' :X.~_-'~"'.' or.,.--?.,~ ~"- ~[4 ~'~:"' "~""::~2-%~/-~%~---~- -~' ' .r.- .'v ~: %/, ,~',..r ..... -2~.: · ' .-. ~_---,- ~: ~,~ .74,- - ,.~ ~,"~ .. ..... _;,~t.~, ~t '~'-' '~-r.-.~ =--*~-~: .~. . -.. ..... .-.:;,.~.-, .,-. -,.-..-:(.1 ..... .:: ,- - : : -.- f . . - ~ ¢....- .~.:. .. . . ,5...'. :,... . ¢. .....-.. -.......... ..- .,-. ,.,..... .~- .,-.- u nn~o"~" '.' .-'"U ' -. :" .- "-: .......' ' ' 'unclassified :;- '- X denbal (UnClassified if document removed) .. . COnfidential . · ~.. . .- ..- _ _ . I · o STATE OF I. LASKA ALASKA OIL AND GAS CONS~RVATION COMMISSION Surface Abandonment ! Lo.:afion Clearance Report ( Title 20 AAC 2.~, Article 2 ) FILE INFOR~,TION: Well Name: NEVE #1 PTD No.: 95-215 APl No. 50- Unit or Lease Name: NA Field and Pool: WILDCAT U Downhole P&A Date: Operator: ARCO ALASKA INC. Address: ANCHORAGE AK. Surface Location: F L, F L Section 14 ,T 11N ,R 4E ,M Inspection Date: I 20 AAC 25.125 -ABANDONMENT MARKER: I Approval Date: Steel Post OD: (4" rain) "Length (10' min.) ft. Height Above Final Grade Level (4' min.) Top of Marker Post Closed With: (Welded, Cmt., Cap), Set: (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: ft. Side Outlets: All valves and nipples removed ? All openings closed ? With Marker Plate Diameter: Marker Plate Attached To: Wellhead "Thickness: "Distance Below Final Grade Level: Cutoff Csg Other Information Beadwelded Directly to Marker Post or Blind Marker Plate: Operator: Unit / Lease Name: W~,,~, ~ .~3e.:_ Remarks: Surface Lo~-q:_.. F ',...__L, ~ .... L Section ,T' '"~ "---'- ,R~ ,M ~ ( Note when different from file information) inspection Date: 7/9/96 I 20 AAC 25.170. LOCATION CLEANUP: I Approval Date: 7/9/96 =ITS: Filled In: NA Liners Removed or Buriecl: NA Debris Removed: YES SURFACE CONDITION OF PAD AND / OR LOCATION: CONTURED ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: YES Type &Quan. of Debris if anyremaining on pad and / or location: NONE TYPE AND CONDITION OF SURROUNDING AREA · TUNDRA ( Wooded,Tundra, Grass, Brush, Dirt,Gravel,Sand) Clean: YES Type &Quan. of Debris if any remaining on surrounding area · NONE TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: ICE ROAD ( Dirt, Gravel, Ice, Other) Clean: YES Type &Quan. of Debris if any remaining on access road or surrounding area · NONE CLEANUP WORK REMAINING TO BE DONE · NONE, THE AREA IS VERY CLEAN RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes X No ( If "No" See Reason ) Distribution: Reason: odg - Well file c- Operator FINAL INSPECTION:~ Yes X No c- Database c-Inspector INSPECTED BY: ~ John H. Spaulding DATE: 7/9/96 FI-000 (Rev. 3/93) 199LG~DD.XLS TO: AOGCC Attn.: Mr, Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ARCO Alaska, Inc. AtlanticRichfieldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Keili A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: June 2; 1996 Transmitted herwith is the followinq data- Enclosed is the following data: LOGS: I Sepia Copy Displayed by Schlumberger: Bergschrund 2A CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH MECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 1 Sepia Copy Displayed by Schlumberqer: Temptation lA CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH 1 Blueline Copy Displayed by Schlumberger: Bergschrund 2A CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH MECHANICAL SIDEWALL CORING RECORD 13 MARCH 1996 I Blueline Copy Displayed by Schlumberger: Temptation 1A CDN FINAL PRINT CDN FINAL PRINT TRUE VERTICLE DEPTH CDR FINAL PRINT CDR FINAL PRINT TRUE VERTICLE DEPTH '~'N 05 199Po Oil & '''~' ..... r ..... ~ !-:,"-~:,m;--'--~: j''~ 05 i996 ~s~ka 0il & Gas Cor~s. Com:nissio~ Anchorage TO: DATE: ARCO Alaska, Inc. AtlanticRichfieldCompany AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 June 2, 1996 Transmitted herwith is the followinq data: DIGITAL DATA Displayed by Schlumberger: Bergschrund 2A 6" Open Reel Tape -LDWG Format -"LOGGING WHILE DRILLING" CDR & CDN with paper file listing 3.5 Floppy -ASCII Format-Depth-adjusted Directional Survey Temptation lA 6" Open Reel Tape -LDWG Format -"LOGGING WHILE DRILLING" CDR & CDN with paper file listing 3.5 Floppy-ASCIi Format-Depth-adjusted Directional Survey END OF WELL REPORTS Displayed By EPOCH WELL LOGGING INC.: Bergschrund 2A Nanuk 1 Neve 1 CC ~"-~ Temptation 1 Temptation lA If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: A~pproved for transmittal by: M. !Tf'oceycutt JUt4 0 3 i996 Manager, North Alas a~Exploration Oil & Gas ~ns. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,us of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-215 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-103-20231 4 Location of well at surface '~.:,:';i~/. ~'ii~!~ 9 Unit or Lease Name 465' FNL, 2440' FWL, SEC. 14, T11N, R4E, UM ? '~~r ;: N/A At Top Producing Inte~al ~ ................. ~ ~ -v.-'~. ~ ,10 Well Numar SAME SAMEi ~~ ~~~..r~.,., ~ WILDCAT 5 Elevation in feet (indi~te KB, DF, etc.) ~ ~~ea~¢signation and Serial No. RKB 35' ABOVE SL ~ ADL 380075 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or A~nd. 15 Water Depth, if offshore ~16 No. of Completions 14-Feb-96 04-Mar-96 4-23-96 Abandoned NA feet MSLJ NA 17 Total Depth7700, ~D(MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional~Su~ey~ 20 Depth where SSSV set 21 Thickness of ~rma~ost 7700'MD, YES ~ NO ~ NA feetMD NA 22 Ty~ Electric or Other Logs Run TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE ~ME~ ~RD 16" 62.58¢ B SURF 120' 20" 300 sx AS I 9.625" 53.5¢ L-80 SURF 1~1' 12.25" 325 SX AS III & 575 SX AS I 7" 26~ L-80 SURF. 7679' 8.5" 405 SX C~SS G 24 Pedorations o~n to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 7268-7376' ~D J-4 SAND TEST PERFS 3.5" 7265' 7240' 7220-7222' TVD 7" CASING SQUEEZE PERFS 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) ~ AMOUNT & KIND OF MATERIAL USED See a~ach~ operations summary 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas li~, etc.) MARCH 25, 1996 DIESEUNITR~EN ASSIST WITH CTU Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I TEST PERIOD E Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE E 28 CORE DATA Brief description of lithology, ~rosity, ~actures, apparent dips and presence of oil, gas or water. TO BE SENT UNDER SEPARATE COVER BY EXPLORATION GEOLOGY Submit core chips. ~6~ ~9 Anchorage Form 10-407 Submit in duplicate 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. TO BE SENT BY EXPLORATION GEOLOGY 31. LIST OF A-I-I'ACHMENTS AS-BUILT SURVEYS, P&A DIAGRAM, AND DAILY DRIllING REPORTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~II- I~IT gl~ AI~ I ~ llgl~l 11~¥ UAlI- I,~ ~ I I N~ ~1 ~~.oo'~ 19.5'~ ~T~ ,~ ,, ~QNI~ M~ ~'= ~ ~ ~ NO SCA~ "LOCA~ON ~ L~A~ ~IN PRO~C~ ~ ~C. 1~, T. 11 N., R. ~ E UMIAT M~IDI~ ~T. - 70' 18' ~.671' L~G. - 151' ~' 05.593' ~' F.N.L, ~' F.W.~ Y - 5,~~.76 X - ~0251.~7 ~ND ~.= 1~ I~ P~ ~.= 16.6' NO~S 1. B~S ~ H~IZONT~ L~A~ AND ~~~~~ IS U.&G.& M~UM~T B~. ~ ~DINA~ ~0~ ~E ~~ STA~ P~E Z~E 6, N.~D. 27. ~ ~ P~ ~S ~~ ~ ~O N~. · . DA~ ~ ~R~: 1/26/96. '~ ~ 5. ~ ~A~S ~0~ ~E B.P.M.S.L j,~ ~ SUR~OR'S CER~CA~ ~~~~~~~ I~ I ~Y ~~ ~AT I ~ PR~Y RE~S~ ~A~ ~ ~A ~D ~AT ~IS P~T R~R~~ A ~R~ D~E BY ME ~ UND~ MY DIRECT ~P~ON ~D ~AT ~ DIM~ONS AND 0~ ~N~ ~E C~RECT ~ ~ ~. 01, 1996. sLOUNSBURY Ino. ---- ~L~ATmY ~ C~DUC~ Subsidiary of Atlantic Richfield Company ~ ICE P~ AS-BUILT ~601196 2/2/96 CEA-MI~-601D196 OOl ~ 1 1 FINAL NEVE #1 P&A SCHEMATIC CONFIDENTIAL PLUG #3 TUBING PERFS 260-263' PLUGS #3 & #4 ARE ARCTICSET CEMENTS 11.0 ppg MUD IN 7" X OPEN HOLE ANNULUS KILL WEIGHT BRINE BETWEEN ALL PLUGS AND IN 3-1/2" X 7" ANNULUS, 10.6 ppg ~ P&A CEMENT FILL TOP OF PLUG #1 INSIDE TUBING AT 7155' (COILED TBG REF DEPTH) 9-5/8" CSA 1841' RKB CEMENTED TO SURFACE WITH ARCTICSET CEMENTS 3-1/2" 9.3# LD0 EUE 8RD MOD TBG PLUG #2 CEMENT TOPS: INSIDE TUBING, 6672' INSIDE 3-1/2" X 7", 6846' GAS LIFT MANDREL @ 7046' BLANKING PLUG IN XN NIPPLE @ 7092' UPPER PACKER @ 7145' SQUEEZE PERFS @ 7220' (SQUEEZED 3/12/96) LOWER PACKER @ 7240' TUBING TAIL @ 7265' (7259' WLM) J-4 SAND TEST PERFS 7268-7376' TOp OF PREVIOUS FILL @ 7459' (COILED TBG REF DEPTH) EXPENDED TCP PERF GUNS @ 7458' ORIGINAL PBTD = 7576' 7" CSA 7679' RKB TWM, 5/6/96 Date: 4/22/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:NEVE %1 RIG:NO RIG WELL ID: AX9337 AFC' AX9337 -- STATE:ALASKA AREA/CNTY' NORTH SLOPE WEST FIELD: WILDCAT SPUD: START COMP: BLOCK: FINAL: TIGHT HOLE API NUMBER: 50-103-20231-00 03/21/96 (46) TD' 7700'(0) SUPV:MEE 03/22/96 ( 47) TD' 7700' (0) SUPV: MEE 03/23/96 (48) TD: 7700'(0) SUPV:MEE 03/24/96 (49) TD' 7700' (0) SUPV:MEE 03/25/96 (50) TD: 7700'(0) SUPV:MEE 03/26/96 (51) TD: 7700'(0) SUPV:MEE 03/27/96 ( 52) TD' 7700' (0) SUPV:SDB 03/28/96 (53) TD: 7700'(0) SUPV:SDB 03/29/96 (54) TD' 7700'(0) MW' 0.0 PV/YP: 0/ 0 RU TEST EQUIPMENT Cleaned location. Built berms & set test tanks. APIWL: 0.0 MW' 0.0 PV/YP: 0/ 0 APIWL: 0.0 RU TEST EQUIPMENT Built berms. Moved test separator & scrubber from Alpine %1. Set separator and scrubber. MW' 0.0 PV/YP: 0/ 0 APIWL: 0.0 RU TEST EQUIPMENT Moved generators, choke manifold and compressors from Alpine #lB location. Pressure tested lines downstream of separator to 120 psi w/air. OK. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PRESSURE TEST EQUIPMENT Set choke manifold and flanged up actuated SSV to wing valve. Ran remaining hardline & insulated lines downstream of separator'. MW' 0.0 PV/YP' 0/ 0 APIWL' 0.0 FLOW TESTING Pressure tested separator to 1000 psi. Pressure tested hardline and choke manifold to 3000 psi. Held safety meeting. Perf'd 726807376' w 6 jspf usinf 4-5/8" TCP gun w/DP charges. Opened well tot--~est tanks on 24/64" ck w/ftp 0 psi. MW- 0.0 PV/YP' 0/ 0 APIWL: 0.0 FLOW TESTING Flowed perfs. Left well open to test tank to flow test. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PRESSURE BUILD-UP Flow test well. Held safety meeting. Pressure test lubri- cator to 3000 %. Set plug in XN nipple at 7071' wlm. RIH w/ petredat gauge in mandrel at 7032' Pressure test tubing to 3000% for 30 min. Pressure test 7" casing to 3000#. OK. MW' 0.0 PV/YP: 0/ 0 APIWL: 0.0 PUMPING FRAC Standby for weather. Held safety meeting. Pressure test line to 7" casing valve to 4000#. MW: 0.0 POST FRAC FLOWBACK PV/YP: 0/ 0 APIWL: 0.0 SU?V:SDB 03/30/96 (55) TD: 7700'(0) SUPV:SDB 03/31/96 (56) TD: 7700'(0) SUPV:SDB 04/1/96 (57) TD: 7700' (0) SUPV:SDB 04/2/96 (58) TD: 7700'(0) SUPV:SDB 04/3/96 (59) TD: 7700'(0) SUPV:SDB 04/4/96 (60) TD: 7700' (0) SUPV: MEE 04/5/96 (61) TD: 7700' (0) SUPV:MEE 04/6/96 (62) TD: 7700'(0) SUPV:MEE 04/7/96 ( 63) TD: 7700' (0) SUPV:MEE 04/8/96 (64) TD: 7700'(0) SUPV:MEE 04/9/96 (65) TD: 7700'(0) SUPV:MEE 04/10/96 (66) TD: '7700'(0) SUPV:SDB 04/11/96 (67) TD: 7700'(0) SUPV:SDB Pump breakdown stage. Pump step rate test, conditioning stage and scour stage. Pump data frac. Pump frac. RIH w/ 1-11/16" temp. log, ccl, gamma ray. Log from 7440-7000' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 POST FRAC FLOWBACK Flow well back to tanks thru choke to cleanup well after frac. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RD COIL UNIT Continue to flow well back to tanks thru choke to cleanup well after frac. Held safety meeting. Test BOP/s to 4000#. SI well and secure well. MW: 0.0 PV/YP: 0/ 0 FLOW TEST WELL Flow well thru choke to flowback tanks. APIWL: 0.0 MW: 0.0 PV/YP: 0/ 0 APIWL: 0 0 FLOW TEST WELL Continue to flow well thru choke to flowback tanks. MN: 0.0 PV/YP: 0/ 0 APIWL: 0 0 FLOW TEST WELL Flow well thru HES test separator and testin9 facilities. MW: 0.0 PV/YP: 0/ 0 FLOW TEST WELL Flow well thru HES test separator. APIWL: 0 0 MW: 0.0 PV/YP: 0/ 0 FLOW TEST WELL Flow well thru HES test separator. APIWL: 0 0 MW: 0.0 PV/YP: 0/ 0 FLOW TEST WELL Flow well thru HES test separator. APIWL: 0 0 MW: 0.0 PV/YP: 0/ 0 APIWL: 0 0 RIGGING DOWN HES TEST EQUIPMENT Flow well thru HES test separator HES downhole shut-in tool actuated and shut in well downhole. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 SI FOR BHP BUILDUP Rigged down HES test equipment dry stacking on location. Well to remanin shutin for BHP buildup until 4/13/96. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 SI FOR BHP BUILDUP Rigged down HES test equipment dry stacking on location. Well to remanin shutin for BHP buildup until 4/13/96. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 SI FOR BHP BUILDUP Rigged down HES test equipment dry stacking on location. Well to remanin shutin for BHP buildup until 4/13/96. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 SI FOR BHP BUILDUP Rigged down HES test equipment dry stacking on location. 04/12/96 ( 68) TD: 7700'(0) SUPV:SDB 04/13/96 (69) TD: 7700' (0) SUPV:SDB 04/14/96 ( 70) TD: 7700'(0) SUPV:SDB 04/15/96 (71) TD: 7700' (0) SUPV:SDB 04/16/96 (72) TD: 7700' (0) SUPV: SDB 04/17/96 (73) TD: 7700'(0) SUPV:DCL 04/18/96 (74) TD: 7700' (0) SUPV:DCL 04/19/96 (75) TD: 7700'(0) SUPV:DCL 04/20/96 (76) TD: 7700'(0) SUPV:DCL 04/21/96 ( 77) TD: 7700' (0) SUPV:DCL 04/22/96 ( 78) TD: 7700'(0) SUPV: DCL Well to remanin shutin for BHP buildup until 4/13/96. MW: 0.0 PV?YP: 0/ 0 APIWL: 0.0 SI FOR BHP BUILDUP Rigged down HES test equipment dry stacking on location. Well to remanin shutin for BHP buildup until 4/13/96. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 SI FOR BHP BUILDUP Rigged down HES test equipment dry stacking on location. HES downhole gauges scheduled to be pulled today. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 P&AWELL Pressure test lubricator to 3000#. Pressure test tubing to 30000. OK. Pump cement to P&A well. No pressure on 9-5/8" x 7" annulus. WOC. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 P&AWELL Wait on coil tubing unit to continue P&A operations. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 P&AWELL Wait on coil tubing unit to continue P&A operations. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 P&A WELL Wait on coil tubing unit to continue P&A operations. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 P&AWELL Move tanks and flow back equipment from Bergschrund to Neve. Prep for P&A. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREP FOR PLUG #2 Held pre-job safety meeting. Test all lines and equipment to 4000 psi. RIH w/1-3/4" coiled tbg. Spot cement from 7459' to 7000'. Displace top 1000' w/diesel for freeze protection. Secure well. WOC. RIH w/coil tbg to TOC @ 7155'. Press tbg to 1500 psi for 10 min. OK. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RD DOWELL RIH w/blanking plug and set in XN nipple at 7092'. POH. Spot 'G' cement through open GLM from 7046' to 6846'. WOC. Est. TOC in tbg at 6670'. Perf 3-1/2" tbg at 260' to 263' w/4 spf. Pump cement down tbg and out 3-1/2" x 7" annulus. RU to 9-5/8" annulus and pump cement. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO CUT OFF WELLHEADS Demob flowback and upright tanks. RD choke equipment. Prep for cut off 3' below ground level. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO CEMENT 9-5/8" X 16" ANNULUS Cut off 16", 9-5/8", 7" and 3-1/2" tbg @ 7' below ground level. Blow down water from 9-5/8" x 16" annulus. ./23/96 ( 79) D: 77007(0) SUPV: DCL MW: 0.0 PV/YP: 0/ 0 FINAL REPORT Pump cement to fill annulus. Demob equipment. APIWL: 0.0 ARCO ALASKA, INC. Neve No. 1 Surface Well Test March 24- April 6, 1996 R CEIVED JUL 23 199~ 0ii & Gas Cons. Comm~'~sion Ancho~a§e Date ~ 'l.~J~ H'A i B U RTO N Halliburton Energy Services Phone Number: Facsimile Number: 6900 Arctic Blvd. Anchorage, Alaska 99518 (907) 344-2929 (907) 344-6746 Attention: Daniel Wuthrich James Mills Robert Richey HALLIBURTON HALLIBURTON ENERGY SERVICES Anchorage, Alaska CUSTOMER: WELL NUMBER: FIELD: AREA: TEST DATE: TEST NUMBER: ARCO Alaska, INC. Neve No. 1 Coleville River Delta Prudhoe Bay, Alaska March 24- April 6, 1996 Surface Test I & 2 HALLIBURTON report copies have been sent to the following companies and/or individuals: # COPIES RECIPIENT 9 ARCO Alaska, INC. Attn: Tim Scarbrough T#032496-T#030696 ARCO ALASKA, INC. Neve No. 1 Surface Well Test March 24 - March 27, 1996 Initial Flow HALLIBURTON HALLIBURTON ENERGY SERVICES REPORT TICKET NO: MEMORY GAUGE TICKET NO: DATE: HALLIBURTON CAMP: TESTER: WITNESS: DRILLING CONTRACTOR: LEGAL LOCATION: OPERATOR: LEASE NAME: WELL NO: TESTED INTERVAL: 032496 24-Mar-96 Kenai Mike Lintner Steve Weimer Wellhead Land ARCO Alaska, INC. Coleville River Neve No. 1 7268 To 7376 FIELD AREA: COUNTY/LSD: STATE/PROVINCE: COUNTRY: Coleville River Delta North Slope Alaska U.S.A NOTICE: THIS REPORT IS BASED ON SOUND ENGINEERING PRACTICES, BUT BECAUSE OF VARIABLE WELL CONDITIONS AND OTHER INFORMATION WHICH MUST BE RELIED UPON HALLIBURTON MAKES NO WARRANTY, EXPRESS OR INPLIED AS TO THE ACCURACY OF THE DATA OR OF ANY CALCULATIONS OR OPINIONS EXPRESSED HEREIN. YOU AGREE THAT HALLIBURTON SHALL NOT BE LIABLE FOR ANY LOSS OR DAMAGE, WHETHER DUE TO NEGLIGENCE OR OTHERWISE ARISING OUT OF OR IN CONNECTION WITH SUCH DATA, CALCULATIONS OR OPINIONS. TABLE OF CONTENTS SECTION 1: SECTION 2: SECTION 3: TEST SUMMARY & INFORMATION Sequence of Events 1.1 Well Test Results Summary 2.1 Well Test Separator Summary ............. 3.1 Well Test Summary Plots 4.1 Pressure / Temperature History Plot 5.1 Storage Tank Data 6.1 Fluid Transfer Data 7.1 Fluid Summary 8.1 MEMORY GAUGE DATA Gauge History Plot 1.1 Gauge Data Listing 2.1 ASCII FILE DATA Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# x 200" WC HES Rep: Mike Lintner Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size COMMENTS (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 24-Mar 23:45 0.000 Schlumberger pressure up tubing to perforate 24-Mar 23:52 0.117 Interval perforated 25-Mar 0:05 0.333 44 Tank #5 Opening gauge - 9.5" / 15.84 bbls. 25-Mar 0:13 0.467 283 Close master to pull tree saver ,__ 25-Mar 0:43 0.967 Open master. Shut In at choke manifold. 25-Mar 0:45 1.000 310 , 25-Mar 0:50 1.083 500 24 Adj. Open well on 24/64 direct to tank #5 25-Mar 1:00 1.250 20 24 Adj. 25-Mar 1:30 1.750 23 24 Adj. 25-Mar 2:00 2.250 22 24 Adj. 25-Mar 2:30 2.750 22 24 Adj. 25-Mar 3:00 3.250 22 24 Adj. 25-Mar 3:06 3.350 22 Shut In Well @ Choke Manifold to monitor surface press. 25-Mar 3:10 3.417 90 25-Mar 3:15 3.500 202 25-Mar 3:20 3.583 350 25-Mar 3:30 3.750 480 25-Mar 3:45 4.000 551 25-Mar 4:00 4.250 571 25-Mar 4:30 4.750 581 .... 25-Mar 5:00 5.250 585 16 Adj. Open well to tank #5 on 16/64 adj choke. 25-Mar 5:30 5.750 37 16 Adj. 25-Mar 6:00 6.250 36 16 Adj. Page no: 1.1 Ney1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# x 200" WC HES Rep: Mike Lintner Tubing Vol. bbl/ft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size COMMENTS (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 25-Mar 6:30 6.750 36 16 Adj. 25-Mar 7:00 7.250 35 16 Adj. 25-Mar 7:30 7.750 34 16 Adj. 25-Mar 8:00 8.250 34 16 Adj. 25-Mar 8:30 8.750 34 16 Adj. 25-Mar 9:00 9.250 34 16 Adj. CTU rig up. 25-Mar 9:30 9.750 33 16 Adj. N2 unit rig up. 25-Mar 10:00 10.250 32 16 Adj. 25-Mar 10:30 10.750 33 16 Adj. 25-Mar 11:00 11.250 32 16 Adj. RIH with CTU. 25-Mar 11:30 11.750 300 16 Adj. CTU @ 1000 ft. Start pumping N2. 25-Mar 12:00 12.250 290 16 Adj. Adjust Choke to maintain 300 psi. CTU at 2000 ft at 12:13. 25-Mar 12:30 12.750 300 Adj. 25-Mar 13:00 13.250 335 Adj. CTU at 3000 ft. 25-Mar 13:30 13.750 328 Adj. 13:41 increase N2 rate. 13:58 Fluid to surface. CTU @ 4000 ft. 25-Mar 14:00 14.250 310 Adj. At 14:15 Oil to surface. 25-Mar 14:30 14.750 275 Adj. ~At 14:57 CTU at 6000 ft. 25-Mar 15:00 15.250 250 Adj. Adjust Choke to maintain 200 psi. 25-Mar 15:30 15.750 223 Adj. CTU at 7000 ft. 25-Mar 16:00 16.250 210 Adj. 25-Mar 16:30 16.750 180 Adj. 25-Mar 17:00 17.250 198 Adj. 25-Mar 17:30 17.750 220 Adj. At 17:55 shut down N2 pumps. Page no: 1.2 Nevl / Job Log l'- Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# x 200" WC HES Rep: Mike Lintner Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size COMMENTS (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) ..~.-- ~,~-~, 25-Mar 18:00 18.250 49 128 Adj. 25-Mar 18:30 18.750 128 Adj. At 18:46 start pumping N2. 25-Mar 19:00 19.250 128 Adj. 25-Mar 19:30 19.750 128 Adj. At 19:46 start pumping N2. 25-Mar 20:00 20.250 128 Adj. Fluid to surface at 20:10. 25-Mar 20:30 20.750 64 128 Adj. 25-Mar 21:00 21.250 68 128Adj. Switch to Tank #4. Opening Gauge 4" / 6.666 bbls. 25-Mar 21:30 21.750 71 128 Adj. 25-Mar 22:00 22.250 70 128 Adj. At 22:31 stopped pumping N2. 25-Mar 22:30 22.750 16 128 Adj. At 23:15 CTU out of hole. 25-Mar 23:00 23.250 16 128 Adj. 26-Mar 0:00 24.250 16 128 Adj. 26-Mar 1:00 25.250 57 128 Adj. !BS&W 27% with 1% solids, well flowing on its own 26-Mar 2:00 26.250 35 128Adj. BS&W 11/2%, gray40.7 at60 26-Mar 3:00 27.250 47 128 Adj. BS&W 11/2%, grav 40.9 at 60 26-Mar 4:00 28.250 30 25 128 Adj. BS&W 1/2%, grav 41.0 at 60 26-Mar 5:00 29.250 16 25 128 Adj. BS&W 11/2%, Chlorides 23,000 ppm 26-Mar 5:30 29.750 64 25 24 Adj. BS&W 2% 26-Mar 6:00 30.250 54 25 24 Adj. BS&W 7%, 1% solids, gray 41.5 at 60 26-Mar 6:30 30.750 128 25 24 Adj. Trace of solids 26-Mar 7:00 31.250 163 25 24 Adj. 26-Mar 7:30 31.750 146 25 24 Adj. 26-Mar 8:00 32.250 143 25 24 Adj. Page no: 1.3 Ney1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3,83 Barton Recorder Range: 1500# x 200" WC HES Rep: Mike Lintner Tubing Vol. bbl/ft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size COMMENTS (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 26-Mar 8:05 32.333 Shut in well at the wing valve to rig up W/L unit 26-Mar 8:25 32.667 PT Lub. and pump 1 bbl diesel down tubing. 26-Mar 8:30 32.750 RIH w/2.2 cent to 7245' Tag guns at 7460'. 26-Mar 8:35 32.833 251 26-Mar 9:00 33.250 251 26-Mar 9:15 33.500 273 RIH with 3" x-line RT and 2.81 plug Set at 7092 26-Mar 9:30 33.750 930 26-Mar 9:45 34.000 379 Shut in at wing to pressure test plug. 26-Mar 10:00 34.250 435 26-Mar 10:10 34.417 437 Pump 17 bbls diesel. Press tbg to 3000#. Latch Gauge @ 7046' 26-Mar 10:20 34.583 3000 Pull Gauge. 26-Mar 11:05 35.333 1800 425 OOH with Petradat gauge. Standby for Petradat rep to arrive loc. 26-Mar 11:20 35.583 1700 425 Petradat Rep on loc. Read and reprogram gauge. 26-Mar 13:45 38.000 RIH with Petradat gauge. 26-Mar 14:30 38.750 3000 300 POOH PT tubing to 3000 psi Csg to 300 psi. 26-Mar 15:05 39.333 1500 Bleed tubing to 1500 psi. RU LRS to 7" csg. 26-Mar t5:15 39.500 1700 3000 PT 7" csg to 3000 psi Tubing to 1700 psi (2bbl diesel) 26-Mar 15:37 39.867 1700 500 Bleed casing to 500 psi 26-Mar 15:38 39.883 1700 500 RIH w/equalizing prong and GS. 26-Mar 16:10 40.417 1200 POOH with Plug. 26-Mar 16:30 40.750 1000 Rig Down W/L 26-Mar 16:55 41.167 780 20 Adj. Open well direct to tank~, 26-Mar 17:30 41.750 470 20 Adj. Page no: 1.4 Ney1 / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well' Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# x 200" WC HES Rep: Mike Lintner Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size COMMENTS (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) ! 26-Mar 18:00 42.250 ' 229 28 Adj. 17:45 rock choke, increase to 28/64 26-Mar 18:30 42.750 221 24 Adj. Decrease choke to 24/64 26-Mar 19:00 43.250 237 48 24 Adj, BS&W trace 26-Mar 19:30 43.750 230 49 24 Adj. BS&Wtrace 26-Mar 20:00 44.250 215 50 24 Adj. BS&W trace 26-Mar 20:30 44.750 190 50 24 Adj. BS&W trace 26-Mar 21:00 45.250 186 50 24 Adj. BS&W trace 26-Mar 21:30 45.750 183 46 24 Adj. BS&Wtrace 26-Mar 22:00 46.250 184 50 24 Adj. BS&W trace 26-Mar 22:30 46.750 190 50 24 Adj. BS&W trace, oil gravity 41.2 at 60 26-Mar 23:00 47.250 191 50 24 Adj. BS&W trace 26-Mar 23:30 47.750 186 50 24 Adj. BS&W 1% 27-Mar 0:00 48.250 185 50 24 Adj. Shut in well at wing valve. ..... ., Page no: 1.5 Ney1 / Job Log Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve #1 Stage: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 II Wellhead Data II Cumulative Volumes and Rates It II ,,,,, , ..... , Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) ~ , , 24-Mar 23:45 Schlumberger pressure up tubing to perforate ,, 24-Mar 23:52 Interval perforated , , 25-Mar 00:05 44.0 Tank #5 Opening gauge = 9.5" / 15.84 bbls. 25-Mar 00:13 283.0 Close master to pull tree saver 25-Mar 00:43 Open master. Shut In at choke manifold. , , 25-Mar 00:45 310.0 .... 25-Mar 00:50 500.0 24 Adj. 100.0 0.00 0.00 0.00 0.00 0.00 Open well on 24/64 direct to tank #5 25-Mar 01:00 20.0 24 Adj. 100.0 0.00 0.00 4.17 600.48 0.00 25-Mar 01:30 23.0 24 Adj. 100.0 0.00 0.00 4.17 0.00 0.00 - 25-Mar 02:00 22.0 24 Adj. 100.0 0.00 0.00 5.42 60.00 0.00 25-Mar 02:30 22.0 24 Adj. 100.0 0.00 0.00 6.25 39.84 0.00 ., 25-Mar 03:00 22.0 24 Adj. 100.0 0.00 0.00 7.08 39.84 0.00 25-Mar 03:06 22.0 Shut In Well ,.. 25-Mar 03:10 90.0 25-Mar 03:15 202.0 25-Mar 03:20 350.0 25-Mar 03:30 480.0 . , 25-Mar 03:45 551.0 Page 2.1 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve #1 Stage: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 ''' Wellhead Data ..... Il ...... cu'mu'lat'ive'Volumes and Rates II , , ,, Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas II Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) ,,, 25-Mar 04:00 571.0 25-Mar 04:30 581.0 25-Mar 05:00 585.0 16 Adj. 100.0 0.00 0.00 7.08 0.00 0,00 Open well to tank #5 on 16/64 adj choke. 25-Mar 05:30 37.0 16 Adj. 100.0 0.00 0.00 8.75 80.16 0.00 25-Mar 06:00 36,0 16 Adj. 100.0 0.00 0.00 10.42 80.16 0.00 25-Mar 06:30 36.0 16 Adj. 100.0 0.00 0.00 10.84 20.16 0.00 25-Mar 07:00 35.0 16 Adj. 100.0 0.00 0.00 13.34 120.00 0.00 25-Mar 07:30 34.0 16 Adj. 100.0 0.00 0.00 13.34 0.00 . 0.00 25-Mar 08:00 34.0 16 Adj. 100.0 0.00 0.00 13.34 0.00 0.00 25-Mar 08:30 34.0 16 Adj. 100.0 0.00 0.00 14.17 39.84 0.00 25-Mar 09:00 34.0 16 Adj. 100.0 0.00 0.00 15.00 39.84 0.00 CTU rig up. 25-Mar 09:30 33.0 16 Adj. 100.0 0.00 0.00 15.83 39.84 0.00 N2 unit rig up. 25-Mar 10:00 32.0 16 Adj. 100.0 0.00 0.00 16.66 39.84 0.00 25-Mar 10:30 33.0 16 Adj. 100.0 0.00 0.00 17.08 20.16 0.00 25-Mar 11:00 32.0 16 Adj. 100.0 0.00 0.00 17.91 39.84 0.00 RIH with CTU. 25-Mar 11:30 300.0 16 Adj. 100.0 0.00 0.00 23.33 260.16 0.00 CTU (~ 1000 ft. Start pumping N2. 25-Mar 12:00 290.0 16 Adj. 100.0 0.00 0.00 30.83 360.00 0.00 Adjust Choke to maintain 300 psi. CTU at 2000 ff at 12:13. 25-Mar 12:30 300.0 Adj. 100.0 0.00 0.00 32.50 80.16 0.00 Page 2.2 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve #1 Stage: Initial Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates Date tTime Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin. Rate Cumm. Rate Cumm. Rate GOR Comments Z i'~':~;~ .... (.!!I'~ :~;'~ ,~,:' . ....... (dd-mmm,.,.hh:,mm). (psig) (°F) (psig) (64ths) (%) (,bbls) ..... -(.bbl/d) (bbls) (bblld) ~msef,) (mscf/d) (mscf/bbl) Z' i¢; ~i~':; '.'/,: ;.ii., . ,,, ,. ,, ..i~ ,r;.,-'2 0.~, ........ ',r b. C',(~!.! ..... "~c,;" ": '"'"' t""~:1 , t',~'! ..~;~ .,:i(. l,,,'r, .,. ?'.f',~,; ':,. :.: CtC,,'.) ,~ (. ';re'ih; ;'!,t, l.'J~. ,: ,~. ' ~,¢~ .,,, ~,,. .... . .,,, -2S-Mar-"13:00 ..... '335.0 ........................ Adj. ''' ~00'0 0:.'I~ ........ I ....... e;O0 ?~I3:I',~'1',t3'"'"'I'"-' '3,9~.84 o:ee CTU at,i,3OOO.ft,. .. . ' :,¥'" '? "'"" ~ :! '! :?:", !..'2 '('.' '";' ' ..... , ,, ',, ,~, .~ '!;' , ....... . 25-Mar 13:30 328.0 Adj.: .......... 100':0.. 0.00 0.00. . 40.83 360,.00 . 0.00 13:41 increase' N2 rate:. 1.3:58 Fluid.tosurface. C-TU @ 4000 ft. ...... 25-Mar 14:00 310.0 Adj. 100.0 0.00 0.00 42.50 80.16 0.00 At 14:15 Oil to surface. 25-Mar 14:30 275.0 Adj. 74.6 6.91 331.89 62.70 969.68 0.00 .. At 14:57 CTU at 6000 ft. ,, 25-Mar 15:00 250.0 Adj. 27.0 7.52 29.24 62.93 10.76 0.00 Adjust Choke to maintain 200 psi. 25-Mar 15:30 223.0 Adj. 75.0 9.72 105.55 69.49 315.00 0.00 CTU at 7000 ft. 25-Mar 16:00 210.0 Adj. 90.0 10.90 56.31 79.99 504.15 0.00 25-Mar 16:30 180.0 Adj. 0.0 10.90 0.00 79.99 0.00 , 0.00 25-Mar 17:00 198.0 Adj. 27.0 21.29 499.12 83.82 183.64 0.00 25-Mar 17:30 220.0 Adj. 0.0 21.29 0.00 83.82 0.00 0.00 At 17:55 shut down N2 pumps. 25-Mar 18:00 49.0 128 Adj. 27.0 22.52 58.82 84.27 21.64 0.00 25-Mar 18:30 128 Adj. 27.0 28.33 278.97 86.41 102.64 0.00 At 18:46 start pumping N2. 25-Mar 19:00 ,128 Adj. 0.0 29.59 60.32 86.41 0.00 0.00 25-Mar 19:30 128 Adj. 0.0 29.59 0.00 86.41 0.00 0.00 At 19:46 start pumping N2. 25-Mar 20:00 128 Adj. 0.0 30.42 40.05 86.41 0.00 0.00 Fluid to surface at 20:10. 25-Mar 20:30 64.0 128 Adj. 27.0 30.42 0.00 86.41 0.00 0.00 25-Mar 21:00 68.0 128 Adj. 27.0 32.26 88.06 87.08 32.40 0.00 Switch to Tank #4. Opening Gauge 4" / 6.666 bbls, 25-Mar 21:30 71.0 128 Adj. 27.0 35.32 146.88 88.21 54.04 0.00 Page 2.3 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve #1 Stage: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates ,, , , ,, , ...... ,, Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm, Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 25-Mar 22:00 70.0 128 Adj, 27.0 36.84 73.27 88.77 26.96 0.00 At 22:31 stopped pumping N2. 25-Mar 22:30 16.0 128 Adj, 27.0 38.37 73.26 89.33 26.95 0.00 At 23:15 CTU out of hole, 25-Mar 23:00 16.0 128 Adj, 27.0 40.20 88.06 90.01 32,40 0.00 26-Mar 00:00 16.0 128 Adj. 27.0 41.12 22.01 90.34 8.10 0.00 ,. 26-Mar 01:00 57.0 128 Adj. 27.0 45.10 95.46 91.81 35.12 0.00 BS&W 27% with 1% solids, well flowing on its own 26-Mar 02:00 35.0 128 Adj. 1.5 71.58 635.52 92.21 9.60 0.00 BS&W 11/2%, grav 40.7 at 60 26-Mar 03:00 47.0 128 Adj. 1.5 83.57 287.86 92.39 4.35 0.00 BS&W 11/2%, gray 40.9 at 60 26-Mar 04:00 30.0 25.0 128 Adj. 0.5 98.19 350.78 92.46 1.75 0.00 BS&W 1/2%, gray 41.0 at 60 26-Mar 05:00 16.0 25.0 128 Adj. 1.5 103.14 118.86 92.54 1.80 0.00 BS&W 11/2%, Chlorides 23,000 ppm 26-Mar 05:30 64.0 25.0 24 Adj. 2.0 114.23 532.17 92.76 10.80 0.00 BS&W 2% 26-Mar 06:00 54.0 25.0 24 Adj. 7.0 115.40 56.19 92.85 4.20 0.00 BS&W 7%, 1% solids, gray 41.5 at 60 26-Mar 06:30 128.0 25.0 24 Adj. 4.0 120.22 231.61 93.05 9.60 0.00 Trace of solids 26-Mar 07:00 163.0 25.0 24 Adj. 0.5 123.98 180.04 93.07 0.90 0.00 26-Mar 07:30 146.0 25.0 24 Adj. 0.5 130.24 300.74 93.10 1.50 0.00 26-Mar 08:00 143.0 25.0 24 Adj. 1.0 135.22 238.85 93.15 2.40 0.00 26-Mar 08:05 Shut in well at the wing valve to rig up W/L unit 26-Mar 08:25 ;PT Lub. and pump I bbl diesel down tubing. 26-Mar 08:30 RIH w/2.2 cent to 7245' Tag guns at 7460'. Page 2.4 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve #1 Stage: Initial Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500'# x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas ,,, Press Temp Press Size BS&W Cumin. Rate Cumin. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 26-Mar 08:35 251.0 .......... 26-Mar 09:00 251.0 26-Mar 09:15 273,0 RIH with 3" x-line RT and 2.81 plug Set at 7092 ....... 26-Mar 09:30 930.0 26-Mar 09:45 379.0 Shut in at wing to pressure test plug. 26-Mar 10:00 435.0 26-Mar 10:10 437.0 Pump 17 bbls diesel. Press tbg to 3000~. Latch Gauge @ 7046' 26-Mar 10:20 3000.0 , Pull Gauge. .., 26-Mar 11:05 1800,0 425.0 OOH with Petradat gauge. Standby for Petradat rep to arrive loc. ,,. 26-Mar 11:20 1700.0 425.0 Petradat Rep on loc. Read and reprogram gauge. 26-Mar 13:45 RIH with Petradat gauge. 26-Mar 14:30 3000.0 300.0 POOH PT tubing to 3000 psi Csg to 300 psi. 26-Mar 15:05 1500,0 Bleed tubing to 1500 psi. RU LRS to 7" csg. 26-Mar 15:15 1700.0 3000.0 PT 7" csg to 3000 psi Tubing to 1700 psi (2bbl diesel) 26-Mar 15:37 1700.0 500.0 Bleed casing to 500 psi 26-Mar 15:38 1700,0 500.0 RIH w/equalizing prong and CS, 26-Mar 16:10 1200,0 POOH with Plug. 26-Mar 16:30 1000.0 Rig Down W/L Page 2.5 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve #1 Stage: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 I[ Wellhead Data ][ Cumulative Volumes and Rates II ,,, Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm, Rate Cumm. Rate Cumin. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 26-Mar 16:55 780.0 20 Adj. Open well direct to tank #4 26-Mar 17:30 470.0 20 Adj. 0.0 147.55 507.44 93.15 0.00 0.00 26-Mar 18:00 229.0 28 Adj. 1.5 163.06 744.37 93.38 11.10 0.00 17:45 rock choke, increase to 28/64 ,., 26-Mar 18:30 221.0 24 Adj, 1.5 170.60 362.05 93.49 5.40 0.00 Decrease choke to 24/64 26-Mar 19:00 237.0 48.0 24 Adj. 0.0 174.43 183.78 93.49 0.00 0.00 BS&W trace .,. 26-Mar 19:30 230.0 49.0 24 Adj. 0.0 182.29 377.50 93.49 0.00 4.40 211.00 0.559 BS&W trace 26-Mar 20:00 215.0 50.0 24 Adj, 0.0 186.84 218.38 93.49 0.00 8.42 193.00 0.884 BS&W trace 26-Mar 20:30 190.0 50.0 24 Adj. 0.0 193.00 295.65 93.49 0.00 . 11.71 158.00 0.534 BS&W trace 26-Mar 21:00 186.0 50,0 24 Adj. 0.0 199.60 316.80 93.49 0.00 15.13 164.00 0.518 ,BS&W trace 26-Mar 21:30 183.0 46.0 24 Adj. 0.0 204.13 217.38 93.49 0.00 18.42 158.00 0.727 BS&W trace 26-Mar 22:00 184.0 50.0 24 Adj. 0.0 207,02 138.79 93.49 0.00 21.65 155.00 1.117 BS&W trace 26-Mar 22:30 190.0 50.0 24 Adj. 0.0 214.02 336.03 93.49 0.00 24.88 155.00 0.461 BS&W trace, oil gravity 41.2 at 60 26-Mar 23:00 191.0 50.0 24 Adj, 0.0 218,54 216.98 93.49 0.00 28.19 159.00 0.733 BS&W trace 26-Mar 23:30 186.0 50.0 24 Adj. 0.0 223.08 217.84 93.49 0.00 31.42 15500 0.712 BS&W 1% 27-Mar 00:00 185.0 50.0 24 Adj. 1.0 225.54 117.76 93.52 1.20 33,98 123.00 1.044 Shut in well at wing valve, Page 2.6 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMPi Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64tbs) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) , ,, 24-Mar 23:45 24-Mar 23:52 25-Mar 00:05 44.0 ,, 25-Mar 00:13 283.0 25-Mar 00:43 ,,, 25-Mar 00:45 310.0 25-Mar 00:50 500.0 24 Adj. 100.0 0.00 0.00 45.0 0.00 0.00 0.00 Q00 0.00 25-Mar 01:O0 20.0 24 Adj. 100.0 4.17 0.00 . 45.0 0.00 0.00 4.17 600.48 0.00 25-Mar 01:30 23.0 24 Adj. 100.0 0.00 0.00 45.0 0.00 0.00 0.00 0.00 0.00 25-Mar 02:00 22.0 24 Adj. 100.0 1.25 0.00 45.0 0.00 0.00 1.25 60.00 0.00 25-Mar 02:30 22.0 24 Adj. 100.0 0.83 0.00 45.0 0.00 0.00 0.83 39.84 0.00 25-Mar 03:00 22.0 24 Adj. 100.0 0.83 0.00 45.0 0.00 0.00 0.83 39.84 0.00 25-Mar 03:06 22.0 25-Mar 03:10 90.0 25-Mar 03:15 202.0 25-Mar 03:20 350.0 25-Mar 03:30 480.0 25-Mar 03:45 551.0 Page 3.1 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scoff Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 II II Date/Time, iI Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@6OF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) ~ , 25-Mar 04:00 571.0 25-Mar 04:30 581.0 25-Mar 05:00 585.0 16 Adj. 100.0 0.00 0.00 45.0 0.00 0.00 0.00 0.00 0.00 25-Mar 05:30 37.0 16 Adj. 100.0 1.67 0.00 45.0 0.00 0.00 1.67 80.16 0.00 25-Mar 06:00 36.0 16 Adj. 100.0 1.67 0.00 45.0 0.00 0.00 1.67 80.16 0.00 25-Mar 06:30 36.0 16 Adj. 100.0 0.42 0.00 45.0 0.00 0.00 0.42 2Q16 0.00 25-Mar 07:00 35.0 16 Adj. 100.0 :2.50 0.00 45.0 0.00 0.00 2.50 120.00 0.00 25-Mar 07:30 34.0 16 Adj. 100.0 0.00 0.00 45.0 0.00 0.00 0.00 0.00 0.00 25-Mar 08:00 34.0 16 Adj. 100.0 0.00 0.00 45.0 0.00 0.00 0.00 0.00 0.00 25-Mar 08:30 34.0 16 Adj. 100.0 0.83 0.00 45.0 0.00 0.00 0.83 39.84 0.00 25-Mar 09:00 34.0 16 Adj. 100.0 0.83 0.00 45.0 0.00 0.00 0.83 39.84 0.00 25-Mar 09:30 33.0 16 Adj. 100.0 0.83 0.00 45.0 0.00 0.00 0.83 39.84 0.00 ?5-Mar 10:00 32.0 16 Adj. 100.0 0.83 Q00 45.0 0.00 0.00 0.83 39.84 0.00 25-Mar 10:30 33.0 16 Adj. 100.0 0.42 0.00 45.0 0.00 0.00 0.42 20.16 0.00 25-Mar 11:00 32.0 16 Adj. 100.0 0.83 0.00 45.0 0.00 0.00 0.83 39.84 0.00 25-Mar 11:30 300.0 16 Adj. 100.0 5.42 0.00 45.0 0.00 0.00 5.42 260.16 0.00 ?5-Mar 12:00 290.0 16 Adj. 100.0 7.50 0.00 45.0 0.00 0.00 7.50 360.00 0.00 25-Mar 12:30 300.0 Adj. 100.0 1.67 0.00 45.0 0.00 0.00 1.67 80.16 0.00 Page 3.2 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 25-Mar 13:00 335.0 Adj. 100.0 0.83 0.00 45.0 0.00 0.00 0.83 39.84 0.00 25-Mar 13:30 328.0 Adj. 100.0 7.50 0.00 45.0 0.00 0.00 7.50 360.00 0.00 25-Mar 14:00 310.0 Adj. 100.0 1.67 0.00 45.0 0.00 0.00 1.67 80.16 0.00 25-Mar 14:30 275.0 Adj. 74.6 27.08 6.88 45.0 6.91 331.89 20.20 969.68 0.00 25-Mar 15:00 250.0 Adj. 27.0 0.83 0.61 45.0 0.61 29.24 0.22 10.76 0.00 25-Mar 15:30 223.0 Adj. 75.0 8,75 2.19 45.0 2.20 105.55 6.56 315.00 0.00 25-Mar 16:00 210.0 Adj, 90.0 11.67 1~17 45.0 1.17 56.31 10.50 504.15 0.00 25-Mar 16:30 180.0 Adj, 0,0 0.00 0.00 . 45.0 0.00 0.00 0.00 0,00 0.00 25-Mar 17:00 198.0 Adj. 27.0 14.17 10.34 45.0 10.40 499,12 3.83 183.64 0.00 25-Mar 17:30 220.0 Adj. 0,0 0.00 0.00 45.0 0.00 0.00 0.00 0.00 0.00 25-Mar 18:00 49.0 128 Adj. 27.0 1.67 1.22 45.0 1.23 58.82 0.45 21.64 0.00 25-Mar 18:30 128 Adj. 27.0 7.92 5.78 45,0 5,81 278.97 2,14 102.64 0.00 25-Mar 19:00 128 Adj. 0.0 1.25 1.25 45.0 1.26 60.32 0.00 0.00 Q00 25-Mar 19:30 128 Adj, Q0 0.00 0.00 45.0 0.1:30 0.00 0.00 0.00 0.00 25-Mar 20:00 128 Adj. 0.0 0.83 0.83 45.0 0.83 40.05 0.00 0.00 0.00 25-Mar 20:30 64.0 128 Adj. 27.0 0.00 0.00 45.0 Q00 0.00 0.00 0.00 0,00 25-Mar 21:00 68.0 128 Adj. 27.0 2.50 1.83 45.0 1.83 88.06 0.68 32.40 0.00 25-Mar 21:30 71.0 128 Adj. 27.0 4,17 3.04 45.0 3.06 146.88 1.13 54.04 0.00 Page 3.3 Final_Reports/Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3~826 Barton Recorder Range: 1500~ x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bblld) (mscf) (mscf/d) (mscf/bbl) (ppm) 25-Mar 22:00 70,0 128 Adj. 27.0 2.08 1.52 450 1.53 73.27 0.56 26.96 0,00 25-Mar 22:30 16.0 128 Adj, 27,0 2.08 1.52 45.0 1.53 73.26 0.56 26.95 Q00 25-Mar 23:00 160 128 Adj. 27.0 2,50 1.83 45,0 1.83 88.06 0.68 32.40 0.00 26-Mar 00:00 16.0 128 Adj. 27,0 1.25 0.91 45.0 0.92 22.01 0.34 8.10 0.00 26-Mar 01:00 57.0 128 Adj. 27.0 5.42 3.96 45.0 3.98 95.46 1.46 35.12 0.00 26-Mar 02:00 35.0 128 Adj. 1.5 26.67 26.27 40.70 44.0 26.48 635.52 0.40 9.60 0.00 26-Mar 03:00 47.0 128Adj 1.5 12,08 11.90 40.90 44.0 11.99 287.86 0.18 4.35 0.00 26-Mar 04:00 30,0 128 Adj 0.5 14.58 14.51 41.00 . 45.0 14.62 350,78 0.07 1.75 0,00 26-Mar 05:00 16.0 128 Adj 1.5 5.00 4.93 44.0 4.95 118.86 0.08 1.80 0.00 23,000 26-Mar 05:30 64.0 24 Adj. 2.0 11.25 11.03 44.0 11.09 532.17 0.23 10.80 0.00 26-Mar 06:00 54,0 24 Adj. 7.0 1.25 1.16 41.50 46.0 1.17 56.19 0.09 4.20 0.00 26-Mar 06:30 128.0 24 Adj. 4.0 5.00 4.80 45.0 4.83 231.61 0.20 9.60 0.00 26-Mar 07:00 163.0 24 Adj. 0,5 3.75 3.73 45.0 3.75 180.04 0.02 0.90 0.00 26-Mar 07:30 146.0 24 Adj. 0.5 6.25 6.22 41.50 45.0 6.27 300.74 0.03 1.50 0.00 26-Mar 08:00 143.0 24 Adj. 1.0 5.00 4.95 45.0 4.98 238.85 0.05 2.40 0.00 ,, 26-Mar 08:05 26-Mar 08:25 26-Mar 08:30 Page 3.4 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC, Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDE~ (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (msCf) (mscf/d) (mscf/bbl) (ppm) 26~Mar 08:35 251.0 26-Mar 09:00 251.0 26-Mar 09:15 273.0 26-Mar 09:30 930.0 26-Mar 09:45 379.0 26-Mar 10:00 435.0 26-Mar 10:10 437.0 26-Mar 10:20 3000.0 26-Mar 11:05 1800.0 26-Mar 11:20 1700.0 26-Mar 13:45 26-Mar 14:30 3000.0 26-Mar 15:05 1500.0 26-Mar 15:15 1700.0 26-Mar 15:37 1700.0 26-Mar 15:38 1700.0 -- 26-Mar 16:10 1200.0 26-Mar 16:30 1000.0 Page 3.5 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, IN©. Well: Neve #1 Test Number: Initial Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# x 200" WC H.E.S. Rep: Mike Lintner Storage Tank Coeff: 1.6667 Date/Time II , Wellhead Data Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr, GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc, Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) ((~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) ,, 26-Mar 16:55 780.0 20 Adj. 26-Mar 17:30 470.0 20 Adj. 0.0 12.08 12.08 12.33 507.44 Q00 0,00 0.00 26-Mar 18:00 229.0 28 Adj. 1.5 15.42 15.19 15.51 744,37 0,23 11.10 0.00 26-Mar 18:30 221.0 24 Adj. 1.5 7.50 7.39 7.54 362.05 0.11 5.40 0.00 26-Mar 19:00 237.0 24 Adj. 0.0 3.75 3.75 3.83 183.78 0.00 0.00 0.00 26-Mar 19:30 230.0 24 Adj. 0.0 7,92 7.92 0.842 0.842 110.0 46.0 80.0 80,0 7.86 377.50 0.00 0,00 4.40 211.00 0.559 26-Mar 20:00 215.0 24 Adj. 0.0 4.58 4,58 0.842 0.842 110.0 38.0 78.0 79.0 4.55 218.38 0.00 0,00 4,02 193.00 0.884 26-Mar 20:30 190.0 24 Adj. 0.0 6.25 6.25 41.40 0.842 0.842 110.0 , 26.0 82.0 89.0 6.16 295.65 0.00 0.00 3.29 158.00 0.534 26-Mar 21:00 186.0 24 Adj. 0.0 6.67 6.67 0.842 0.842 110.0 28.0 84.0 90.0 6.60 316.80 0.00 0.00 3.42 164.00 0.518 26-Mar 21:30 183.0 24 Adj. 0.0 4.58 4.58 0.842 0.842 110.0 26.0 84.0 92.0 4.53 217.38 0.00 0.00 3.29 158.00 0.727 26-Mar 22:00 184.0 24 Adj. 0.0 2.92 2.92 0.842 0.842 110.0 25.0 84.0 88.0 2.89 138.79 0.00 0.00 3.23 155.00 1.117 26-Mar 22:30 190.0 24 Adj. 0.0 7.08 7.08 0.842 0.842 110.0 25.0 85.0 92.0 7.00 336.03 0.00 0.00 3.23 155.00 0.461 26-Mar 23:00 191.0 24 Adj. 0.0 4.58 4.58 41.20 0.842 0.842 120.0 24.0 85.0 86.0 4.52 216.98 0.00 0.00 3.31 159.00 0.733 26-Mar 23:30 186.0 24 Adj. 0.0 4.58 4.58 0.842 0.842 120.0 23.0 85.0 86.0 4.54 217.84 0.00 0.00 3.23 155.00 0.712 27~Mar 00:00 185.0 24 Adj. 1.0 2.50 2.48 0.842 0.842 120.0 21.0 84.0 85.0 2.45 117.76 0.03 1.20 2.56 123.00 1.044 Page 3.6 Final_Reports / Separator Reading Company: ARCO Alaska, INC, Well: Neve #1 Test Number: Inital Flow Date: 24-Mar-96 Halliburton Energy Services Wellhead Reading vs Time 3000 2500 I 0 ~ 18:00 0:00 6:00 12:00 18:00 0:00 6:00 Time 12:00 18:00 0:00 128 112 96 80 64 48 32 16 6:00 Tubing -+--Casing + Temperature ~-~ Choke Size Plot Start Time: 24-Mar-96 18:00:00 Nevel / Current Wellhead Plot Page no: 4,1 Plot End Time: 27-Mar-96 Company: ARCO A~aska, INC, Well: Nave ~1 Tesl Number: Initial Flow Date: 24-Mar-96 Halliburton EnerGy Services Fluid Rate Histop/P~ot 1500 300 1000 50O 18:00 0:00 6:00 I2:00 18:00 0:00 6:00 Time 12:00 18:00 0:00 250 2OO 150 ~ 100 0 6:00 5O Oil ---~'-~ Water/Diesel ~ Gas Plot Start Time: 24~Mer~ 18i00100 Ney1 t Current Rote Plot Page no: 4,2 FI(~ End Time: 27~ar4~6 Company: ARCO Alaska, INC, Well: Neve #1 Test Number: Initial Flow Date: 24~Mar,-96 Haliiburt(~n Energy Services Fluid Cures vs Time 40O 4O 35O 300 25O 200 150 35 3O 25~ 20 S t5® lO0 t0 5O 18:00 0:00 6:00 12:00 18:00 0:00 6:00 Time 12:00 18:00 0:00 0 6:00 ~Oil ----e---~ Wa t e r/D i e sel Plot Start Time: 24-Mar~ 18:00:00 Nevi / Current Total Cum Plot Page no: 4,3 PIc4 End Time: 27-Mar4~6 06:00;00 This Section Left Intentionally Blank. Company: ARCO Alaska, INC. Well Number: Neve #1 Test Number: Initial Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Mike Lintner Company Rep: Scott Weimer Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (b Pre-Flow Strap 3.25 5.42 6.00 10.00 3.50 5.83 4.00 6.67 9.50 15.83 ..... , , 25-Mar 0:50 0.00 0.00 0.00 0.00 9.50 0.00 25-Mar 1:00 0.00 0.00 0.00 0.00 1.00 4.17 4.17 , ,, 25-Mar 1:30 0.00 0.00 0.00 0.00 1.00 0.00 4.17 25-Mar 2:00 0.00 0.00 0.00 0.00 1.00 0.75 1.25 5.42 25-Mar 2:30 0.00 0.00 0.00 0.00 1.00 1.25 0.83 6.25 25-Mar 3:00 0.00 0.00 0.00 0.00 1.00 1.75 0.83 7.08 25-Mar 5:00 0.00 0.00 - 0.00 0.00 1.00 1.75 0.00 7.08 25-Mar 5:30 0.00 0.00 0.00 0.00 1.00 2.75 1.67 8.' 25-Mar 6:00 0.00 0.00 0.00 0.00 1.00 3.75 1.67 10.42 25-Mar 6:30 0.00 0.00 0.00 0.00 1.00 4.00 0.42 10.83 25-Mar 7:00 0.00 0.00 0.00 0.00 1.00 5.50 2.50 13.33 25-Mar 7:30 0.00 0.00 0.00 0.00 1.00 5.50 0.00 13.33 25-Mar 8:00 0.00 0.00 0.00 0.00 1.00 5.50 0.00 13.33 25-Mar 8:30 0.00 0.00 0.00 0.00 1.00 6.00 0.83 14.17 25-Mar 9:00 0.00 0.00 0.00 0.00 1.00 6.50 0,83 15.00 Page no' 6.1.1 Nevl / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: NeYe #1 Test Number: Initial Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Mike Lintner Company Rep: Scott Weimer Tank Coefficient: 1.667 Date / Time Tank No. I Tank No. 2 Tank No. 3 Tank No. 4 Tank No, 5 Inc. Cum Tot' Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft,) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft,) (in.) (bbls) (L 25-Mar 9:30 0.00 0.00 0.00 0.00 1.00 7.00 0,83 15.83 ..... 25-Mar 10:00 0.00 0.00 0.00 0.00 1.00 7.50 0.83 16.67 25-Mar 10:30 0.00 0.00 0.00 0.00 1,00 7.75 0.42 17.08 25-Mar 11:00 0.00 0.00 0.00 0.00 1.00 8.25 0.83 17.92 25-Mar 11:30 0.00 0.00 0.00 0.00 1.00 11.50 5.42 23.33 25-Mar 12:00 0.00 0.00 0.00 0.00 2.00 4.00 7.50 30.83 25-Mar 12:30 0.00 0.00 0.00 0.00 2.00 5.00 1.67 32.50 , ,, 25-Mar 13:00 0.00 0,00 0.00 0.00 2.00 5.50 0.83 33.33 25-Mar 13:30 0.00 0.00 - 0.00 0.00 2.00 10.00 7.50 40.83 25-Mar 14:00 0.00 0.00 0.00 0,00 2.00 11.00 1.67 4', 25-Mar 14:30 0.00 0.00 0.00 0.00 4.00 3.25 27.08 69.58 25-Mar 15:00 0.00 0.00 0.00 0.00 4.00 3.75 0.83 70.42 25-Mar 15:30 0.00 0.00 0.00 0.00 4.00 9.00 8.75 79.17 25-Mar 16:00 0.00 0.00 0.00 0.00 5.00 4.00 11.67 90.84 25-Mar 16:30 0.00 0.00 0,00 0.00 5.00 4.00 0.00 90.84 25-Mar 17:00 0.00 0.00 0.00 0.00 6.00 0.50 14.17 105.00 25-Mar 17:30 0.00 0.00 0.00 0.00 6.00 0,50 0.00 105.00 Page no: 6.1.2 Ney1 / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Neve #1 Test Number: Initial Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Mike Lintner Company Rep: Scott Weimer Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 , , Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc, Cum Tot .. (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in,) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ([ 25-Mar 18:00 0.00 0.00 0.00 0.00 6.00 1.50 1,67 106.67 25-Mar 18:30 0,00 0.00 0.00 0.00 6.00 6.25 7.92 114.59 25-Mar 19:00 0.00 0.00 0.00 0.00 6.00 7.00 1.25 115.84 25-Mar 19:30 0.00 0.00 0.00 0.00 6.00 7.00 0.00 115.84 25-Mar 20:00 Q00 0.00 0.00 0.00 6.00 7.50 0.83 116.67 25-Mar 20:30 0,00 0.00 0.00 0.00 6.00 7.50 Q00 116.67 .... 25-Mar 21:00 0,00 0.00 0.00 4.00 0.00 6.00 9.00 2.50 119,17 , ,, 25-Mar 21:30 0.00 0.00 0.00 6.50 4.17 4.17 0.00 ,.. 25-Mar 22:00 0.00 0.00 - 0.00 7.75 2.08 6.25 0.00 25-Mar 22:30 0.00 0.00 0.00 9.00 2.08 8.33 25-Mar 23:00 0.00 0.00 0.00 10.50 2.50 10.83 0.00 26-Mar 0:00 0.00 0.00 0.00 11.25 1.25 12.08 0.00 26-Mar 1:00 0.00 0.00 0.00 1.00 2.50 5.42 17.50 0.00 ,, 26-Mar 2:00 0.00 0.00 0.00 2.00 6.50 26.67 44.17 0.00 26-Mar 3:00 0.00 0.00 0.00 3.00 1.75 12.08 56.25 0.00 26-Mar 4:00 0.00 0.00 0.00 3.00 10.50 14.58 70.83 0.00 26-Mar 5:00 0.00 0.00 0.00 4.00 1.50 5.00 75.83 0.00 Page no' 6.1.3 Ney1 / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve #1 Test Number: Initial Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Mike Lintner Company Rep: Scott Weimer Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ( ~! 26-Mar 5:30 0.00 0.00 0.00 4.00 8.25 11.25 87.09 Q00 , , 26-Mar 6:00 0.00 0.00 0.00 4.00 9.00 1.25 88.34 0.00 26-Mar 6:30 0.00 0.00 0.00 5.00 0.00 5.00 93.34 0.00 , 26-Mar 7:00 0.00 0.00 0.00 5.00 2.25 3.75 97.09 0.00 26-Mar 7:30 0.00 0.00 0.00 5.00 6.00 6.25 103.34 0.00 26-Mar 8:00 0.00 0.00 " 0.00 5.00 9.00 5.00 108.34 0.00 26-Mar 17:00 0.00 0.00 0.00 5.00 9.00 0.00 108.34 0.00 26-Mar 17:30 0.00 0.00 0.00 6.00 4.25 12.08 120.42 0.00 26-Mar 18:00 0.00 0.00 , 0.00 7.00 1.50 15.42 135.84 0.00 , 26-Mar 18:30 0.00 0.00 0.00 7.00 6.00 7.50 143.34 ~ · 26~Mar 19:00 0.00 0.00 0.00 7.00 8.25 3.75 147.09 0.00 26-Mar 19:30 0.00 0.00 0.00 8.00 1.00 7.92 155.00 0.00 26-Mar 20:00 0.00 0.00 0.00 8.00 3.75 4.58 159.59 0.00 26-Mar 20:30 0.00 0.00 0.00 8.00 7.50 6.25 165.84 0.00 26-Mar 21:00 0.00 0.00 0.00 8.00 11.50 6.67 172.50 0.00 26-Mar 21'30 0.00 0.00 0.00 9.00 2.25 4.58 177.09 0.00 26-Mar 22:00 0.00 0.00 0.00 9.00 4.00 2.92 180.00 0.00 Page no: 6.1.4 Nevl / Tank Farm 1 thru 5 Company: ARCO Alaska, iNC. Well Number: Neve #1 Test Number: Initial Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Mike Lintner Company Rep: Scott Weimer Tank Coefficient: 1.667 Date / Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 .... Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot . (dd-mmm hh:mm) (ff.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ') 26-Mar 22:30 0.00 0.00 0.00 9.00 8.25 7.08 187.09 0.00 ..... 26-Mar 23:00 0.00 0.00 0.00 9.00 11.00 4.58 191.67 0.00 26-Mar 23:30 0.00 0.00 0.00 10.00 1.75 4.58 196.25 0.00 ,, 27-Mar O:00 0.00 0.00 0.00 10.00 3.25 2.50 198.75 0.00 Post-Flow Strap 3.25 5.42 6.00 10.00 3.50 5.83 6.00 10.00 4.50 7.50 ,,, · ,, Page no: 6.1.5 Ney1 / Tank Farm 1 thru 5 Halliburton Energy Services Tank Farm Transfer Sheet Company: ARCO Alaska, INC. Well Number: Neve #1 Test Number: Initial Flow HES Rep: Mike Lintner Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date / Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred Volumn (dd-mmm hh:mm) (ft) (in) (bbls) (ft) (in) (bbls) (bbl) (bbl) 28-Mar 22:00 2200 5 6.00 9.00 135.00 4.50 7.50 127.50 127.50 28-Mar 22:00 2200 4 10.00 3.25 205.42 7.00 1.50 142.50 62.92 190.42 29-Mar 4:00 143014 4 7.00 1.50 142.50 6.00 10.00 132.50 322.92 · Page 7.1 Nevel / Tank Transfer Data Halliburton Energy Services Tank Farm Totals Summary Company: ARCO Alaska, INC. Well Number: Neve #1 Test Number: Initial Flow H.E.S. Rep: Mike Lintner Company Rep: Scott Weimer Tank Coefficient: 1.667 Date / Time Tank Pre-Flow Total Flow Total Vacuum Post-Vac Volume3 Number Volume (A) Volume (B) Volume (C) Volume (D) (A+B)-(C+D) (dd-mm-yy hh:mm) (bbl) (bbl) (bbl) (bbl) (bbl) 08-Mar-96 10:00 1 5.42 0.00 0.00 5.42 0.00 08-Mar-96 10:00 2 10.00 0.00 0.00 10.00 0.00 08-Mar-96 10:00 3 5.83 0.00 0.00 5.83 0.00 08-Mar-96 10:00 4 6.67 198.75 195.42 10.00 (0.00) 08-Mar-96 10:00 5 15.83 119.17 127.50 7.50 0.00 6 0.00 0.00 0.00 0.00 0.00 7 0.00 0.00 0.00 0.00 0.00 8 0.00 0.00 0.00 0.00 0.00 9 0.00 0.00 0.00 0.00 0.00 10 0.00 0.00 0.00 0.00 0.00 08-Mar-96 10:00 Fracl 0.00 0.00 0.00 0.00 0.00 Frac2 0.00 0.00 0.00 0.00 0.00 08-Mar-g6 10:00 Frac3 0.00 0.00 0.00 0.00 0.00 Fluid Split Fluid Splits At Recorded Conditions To Correlate To Tank Volumes. Oil (bbl) 224.39 Water2 (bbl) 11.52 Diesel~ (bbl) 82.00 Notes: ~ Estimated By Customer. 2 Includes solids and gel fluids.(BS&W) 3 Volume Difference Due To Measurment, Expansion or Contraction of Fluids Page 8.1 Ney1 / Tank Farm Summary ARCO ALASKA, INC. Neve No. I Surface Well Test March 28 -April 6, 1996 Post-Frac Flow HALLIBURTON HALLIBURTON ENERGY SERVICES REPORT TICKET NO: MEMORY GAUGE TICKET NO: DATE: HALLIBURTON CAMP: TESTER: WITNESS: DRILLING CONTRACTOR: LEGAL LOCATION: OPERATOR: LEASE NAME: WELL NO: TESTED INTERVAL: 032896 28-Mar-96 Kenai Ron Cookson Steve Weimer Wellhead Land ARCO Alaska, INC. Coleville River Neve No. 1 7268 To 7376 FIELD AREA: COUNTY/LSD: STATE/PROVINCE: COUNTRY: Coleviile River Delta North Slope Alaska U.S.A NOTICE: THIS REPORT IS BASED ON SOUND ENGINEERING PRACTICES, BUT BECAUSE OF VARIABLE WELL CONDITIONS AND OTHER INFORMATION WHICH MUST BE RELIED UPON HALLIBURTON MAKES NO WARRANTY, EXPRESS OR INPLIED AS TO THE ACCURACY OF THE DATA OR OF ANY CALCULATIONS OR OPINIONS EXPRESSED HEREIN. YOU AGREE THAT HALLIBURTON SHALL NOT BE LIABLE FOR ANY LOSS OR DAMAGE, WHETHER DUE TO NEGLIGENCE OR OTHERWISE ARISING OUT OF OR IN CONNECTION WITH SUCH DATA, CALCULATIONS OR OPINIONS. TABLE OF CONTENTS SECTION 1: SECTION 2: SECTION 3: TEST SUMMARY & INFORMATION Sequence of Events 1.1 Well Test Results Summary 2.1 Well Test Separator Summary 3.1 Well Test Summary Plots 4.1 Pressure / Temperature History Plot 5.1 Storage Tank Data ................... 6.1 Fluid Transfer Data 7.1 Fluid Summary .................................. 8.1 MEMORY GAUGE DATA Gauge History Plot 1.1 Gauge Data Listing 2.1 ASCII FILE DATA Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# × 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 28-Mar 6:20 0.000 Commence Frac Stimulation 28-Mar 11:40 5.333 Frac complete,2728 bbbls pumped ofjelI,H20,sand 100,000 # 29-Mar 0:27 18.117 270 20 Adj. Open well to A.P.C. Manifold & Tank. 29-Mar 0:30 18.167 60 20 Adj. All Fluids reported as Water until Oil to Surface. 29-Mar 0:45 18.417 45 20 Adj. 29-Mar 1:00 18.667 37 20 Adj. 29-Mar 1:15 18.917 36 20 Adj. 29-Mar 1:30 19.167 12 22 Adj. 29-Mar 1:55 19.583 10 64 Adj. . 29-Mar 2:00 19.667 5 64 Adj. Frac fluid to surface 29-Mar 2:30 20.167 5 64 Adj. 29-Mar 3:00 20.667 5 64 Adj. 29-Mar 3:30 21.167 5 .64 Adj. 29-Mar 4:00 21.667 5 64 Adj. 38 bbls shipped from frac tank 29-Mar 4:30 22.167 5 64 Adj. 29-Mar 5:00 22.667 0 64 Adj. 29-Mar 5:30 23.167 0 64 Adj. 29-Mar 6:00 23.667 0 64 Adj. 29-Mar 7:00 24.667 0 64 Adj. 29-Mar 8:00 25.667 0 64 Adj. 29-Mar 9:00 26.667 0 64 Adj. 29-Mar 10:00 27.667 0 64 Adj. 29-Mar 11:00 28.667 0 64 Adj. page no: 1.1 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 29-Mar 12:00 29.667 0 64 Adj. 29-Mar 13:00 30.667 0 64 Adj. ... 29-Mar 13:30 31.167 0 24Ad~. 29-Mar 14:00 31.667 0 24 Adj. ., 29-Mar 15:00 32.667 0 128 Adj. Bypass choke direct to tank 29-Mar 16:00 33.667 0 128 Adj. 29-Mar 17:00 34.667 0 128 Adj. 29-Mar 18:00 35.667 0 128 Adj. 29-Mar 19:00 36.667 0 128 Adj. 29-Mar 20:00 37.667 0 128 Adj. 29-Mar 21:00 38.667 0 128 Adj. Monitor well thru night 29-Mar 22:00 39.667 0 128 Adj. .. 29oMar 23:00 40.667 0 128 Adj. 30-Mar 0:00 41.667 0 128 Adj. 30-Mar 1:00 42.667 0 128 Adj. 30-Mar 2:00 43.667 0 128 Adj. 30-Mar 3:00 44.667 0 128 Adj. 30-Mar 4:00 45.667 0 128 Adj. 30-Mar 5:00 46.667 0 128 Adj. .. 30-Mar 6:00 47.667 0 128 Adj. 61 bbls Fluid Recovered 30-Mar 7:00 48.667 0 128 Adj. 30oMar 8:00 49.667 0 128 Adj. I" 30-Mar 9:00 50.667 0 128 Adj. page no: 1.2 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X :200" WC HES Rep: Ron Cookson Tubing Vol. bbl/ft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 30-Mar 10:00 51.667 0 128 Adj. 30-Mar 11'00 52.667 0 128 Adj. 30-Mar 12:00 53.667 128 Adj. Dowell Schlumberger on location. Shut in well @ wing valuve. 30-Mar 13:00 54.667 30-Mar 14:00 55.667 30-Mar 15:00 56.667 30-Mar 16:00 57.667 30-Mar 17:00 58.667 30-Mar 18:00 59.667 Wait on Dowell Schlumberger 30-Mar 19:00 60.667 30-Mar 20:00 61.667 30-Mar 21:00 62.667 30-Mar 22:00 63.667 D.S. rig up C.T. on well 30-Mar 22:30 64.167 D.S. pressure test BOP'S 30-Mar 23:00 64.667 31-Mar 0:00 65.667 31-Mar 1:00 66.667 0 128 Adj. Open wing valve, D.S. run in hole C.T. to jet well with diesel. 31-Mar 2:00 67.667 0 128 Adj. 31-Mar 3:00 68.667 0 128 Adj. 31-Mar 4:00 69.667 0 128 Adj. 25% H2©,75% Diesel,Trace mud. 31-Mar 4:30 70.167 0 128 Adj. 4% H20, 96% Diesel,trace mud. 31-Mar 5:00 70.667 0 128 Adj. .5% H20, 99.5% Diesel,trace mud. 31-Mar 5:30 71.167 0 128 Adj. .25% H20, 99.75% Diesel,trace mud-D.S, out of hole. page no: 1.3 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No. 1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# × 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure ! Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 31-Mar 6:00 71.667 385 Well shut in to rig down D.S., 81 bbls recovered. 31-Mar 6:30 72.167 10 34 Adj. 31-Mar 7:00 72.667 150 32 Adj, Rocking choke 31-Mar 7:30 73.167 110 32 Adj. Rocking choke trying to establish & maintain 30 bbl/hr rate. 31-Mar 8:00 73.667 70 32 Adj. Rocking choke, BS&W 75%, trace of sand, all diesel 31-Mar 8:30 74.167 80 32 Adj. Rocking choke, BS&W 75%, trace of sand, oil to surface 31-Mar 9:00 74.667 90 32 Adj. Rocking choke, BS&W 60%,trace of sand 31~Mar 9:30 75.167 100 32 Adj. Rocking choke, BS&W 60%,trace of sand,chlorides 26,000ppm 31-Mar 10:00 75.667 90 32 Adj. Rocking choke, BS&W 60%,trace of mud 31-Mar 10:30 76.167 100 32 Adj. Rocking choke, BS&W 60%,trace of mud, chlorides 31000ppm 31-Mar 11:00 76.667 95 32 Adj. Rocking choke, BS&W 60%,trace of mud, chlorides 26000ppm 31-Mar 11:30 77.167 95 32 Adj. Rocking choke, BS&W 60%,trace of mud, chlorides 28000ppm 31oMar 12:00 77.667 115 30 Adj. Rocking choke, BS&W 60%,trace of mud, chlorides 30000ppm 31-Mar 12:30 78.167 120 30 Adj. Rocking choke, BS&W 60%,trace of mud, chlorides 30000ppm 31-Mar 13:00 78.667 115 30 Adj. Rocking choke, BS&W 60%,trace of mud, chlorides 30000ppm 31-Mar 13:30 79.167 120 30 Adj. Rocking choke, BS&W 50%, trace of mud, chlorides 29000ppm 31-Mar 14:00 79.667 120 650 30 Adj. Rocking choke, BS&W 50%, trace of mud, chlorides 29500ppm 31-Mar 14:30 80.167 120 30 Adj. Rocking choke, BS&W 50%, trace of mud, chlorides 29000ppm 31-Mar 15:00 80.667 120 30 Adj. Rocking choke, BS&W 55%, trace of mud, chlorides 29000ppm 31-Mar 15:30 81.167 120 30 Adj. Rocking choke, BS&W 55%, trace of mud 31-Mar 16:00 81.667 110 30 Adj. Rocking choke, BS&W 55%, trace of mud, chlorides 29500ppm 31-Mar 16:30 82.167 110 30 Adj. Rocking choke, BS&W 55%, trace of mud 31-Mar 17:00 82.667 110 30 Adj. Rocking choke, BS&W 50%, trace of mud, chlorides 29000ppm page no: 1.4 Ptfrac / Job Log Halliburton Energy Services Sequence of Evei;t.~ Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Ron Cookson Tubing Vol. bbllff: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 31-Mar 17:30 83.167 110 700 30 Adj. BS&W 50%, trace of mud, no debris in choke over half hour 31-Mar 18:00 83.667 150 30 Adj. Rock choke, BS&W 60% H20,trace of mud,chlorides 29,000ppm 31-Mar 18:30 84.167 200 30 Adj. Rock choke, BS&W 40%,trace of sand. No debris in choke 31-Mar 19:00 84.667 200 700 30 Adj. BS&W 40%,Trace of sand. 31-Mar 19:30 85.167 130 710 34 Adj. BS&W 35%,trace of sand. 31-Mar 20:00 85.667 135 720 34 Adj. BS&W 30%,trace of sand. 31-Mar 20:30 86.167 185 730 32 Adj. BS&W 30%,trace of sand-rock choke 31-Mar 21:00 86.667 175 740 32 Adj. BS&W 30%,trace of sand-rock choke 31-Mar 21:30 87.167 80 750 32 Adj. BS&W 15%,trace of sand-rock choke 31-Mar 22:00 87.667 180 750 32 Adj. BS&W 28%trace of sand-rock choke 31-Mar 22:30 88.167 210 750 32 Adj. BS&W 25%,trace of sand-rock choke 31-Mar 23:00 88.667 150 760 32 Adj. BS&W 15%,trace of sand-rock choke 31-Mar 23:30 89.167 80 790 32 Adj. BS&W 30%trace of sand 01-Apr 0:00 89.667 150 800 34 Adj. BS&W 25%,choke @ 34/64-trace of sand 01-Apr 0:30 90.167 180 800 34 Adj. BS&W 20%,trace sand-rock choke 01-Apr 1:00 90.667 150 800 34 Adj. BS&W 26%,trace of sand 01-Apr 1:30 91.167 180 825 34 Adj. BS&W 20%,trace sand-rock choke 01-Apr 2:00 91.667 165 845 34 Adj. BS&W 23%,trace sand. 01-Apr 2:30 92.167 150 845 34 Adj. BS&W 15%,trace sand 01-Apr 3:00 92.667 150 845 34 Adj. BS&W 15%,trace sand. 01-Apr 3:30 93.167 150 850 34 Adj. BS&W 18%,trace sand. 01-Apr 4:00 93.667 160 860 34 Adj. BS&W 22%,trace sand,rock choke 01-Apr 4:30 94.167 160 865 34 Adj. BS&W 22%,trace sand,rock choke page no: 1.5 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ X 200" VVC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 01-Apr 5:00 94.667 160 865 34 Adj. BS&W 13%,trace sand. 01-Apr 5:30 95.167 165 880 34 Adj. BS&W 14%,trace sand. 01-Apr 6:00 95.667 165 890 34 Adj. BS&W 14%,trace sand. 01-Apr 6:30 96.167 165 900 34 Adj. BS&W 15%,trace sand 01-Apr 7:00 96.667 34 Adj. 01-Apr 7:30 97.167 34 Adj. 01-Apr 8:00 97.667 34 Adj. 01-Apr 8:30 98.167 201 34 Adj. Direct flowthru separator. 01-Apr 9:00 98.667 226 34 Adj. 01-Apr 9:30 99.167 260 34 Adj. Rock choke 01oApr 10:00 99.667 403 34 Adj. BS&W 22%,trace sand. 01-Apr 10:30 100.167 475 34 Adj. BS&W 30%,trace sand. 01-Apr 11:00 100.667 273 800 34 Adj. BS&W 30%,trace sand. 01-Apr 11:30 101.167 213 50 40 Pos. Choke 40/64 ADJ.Bleed casing to 500 psi. BS&W 20%,trace sand. 01-Apr 12:00 101.667 143 55 40 Pos. Choke change 40/64 POS@ 11:18.BS&W 15%,trace sand. 01-Apr 12:30 102.167 148 55 40 Pos. BS&W 16%,trace sand. 01-Apr 13:00 102.667 188 58 600 40 Pos. BS&W 18%,trace sand. 01-Apr 13:30 103.167 169 58 625 40 Pos. !BS&W 8%,trace sand. 01-Apr 14:00 103.667 178 57 650 40 Pos. BS&W 20%,trace sand. 01-Apr 14:30 104.167 174 57 660 40 Pos. BS&W 12%,trace sand. 01-Apr 15:00 104.667 185 58 675 40 Pos. BS&W 10%,trace sand. 01-Apr 15:30 105.167 172 58 675 40 Pos. BS&W 6%,trace sand. 01-Apr 16:00 105.667 166 58 675 40 Pos. BS&W 9%,trace sand. page no: 1.6 Ptfrac Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No. 1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ × 200" WC HES Rep: Ron Cookson Tubing Vol. bbl/ft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 01-Apr 16:30 106.167 195 56 700 40 Pos. BS&W 18%,trace sand. 01-Apr 17:00 106.667 177 56 700 40 Pos. BS&W 22%,trace sand. 01-Apr 17:30 107.167 178 56 700 40 Po.s. BS&W 14%,trace sand. 01-Apr 18:00 107.667 197 56 700 40 Pos. BS&W 20%,trace sand. 01-Apr 18:30 108.167 169 56 710 40 Pos. BS&W 15%,trace sand. 01-Apr 19:00 108.667 206 61 750 40 Pos. BS&W 6%,trace sand. 01-Apr 19:30 109.167 202 60 750 40 Pos. BS&W 20 01-Apr 20:00 109.667 191 61 760 40 Pos. BS&W 21% 01-Apr 20:30 110.167 192 61 775 40 Pos. BS&W 20% 01-Apr 21:00 110.667 195 61 800 40 Pos. BS&W 20%.Change orfice plate to 1.00" 01-Apr 21:30 111.167 205 61 800 40 Pos. BS&W 20% 01-Apr 22:00 111.667 207 61 800 40 Pos. BS&W 20% 01-Apr 22:30 112.167 207 62 800 40 Pos. BS&W 18%.Haul oil from tanks 01-Apr 23:00 112.667 200 62 800 40 Pos. BS&W 18%. 01-Apr 23:30 113.167 206 62 800 40 Pos. BS&W 16% 02-Apr 0:00 113.667 204 62 800 40 Pos. BS&W 16% 02-Apr 0:30 114.167 208 62 805 40 Pos. BS&W 15% 02-Apr 1'00 114.667 207 62 805 40 Pos. BS&W 15% 02-Apr 1'30 115.167 210 62 810 40 Pos. BS&W 12% 02-Apr 2:00 115.667 209 62 810 40 Pos. BS&W 9% 02-Apr 2:30 116.167 203 62 810 40 Pos. BS&W 13% 02-Apr 3:00 116.667 201 62 820 40 Pos. BS&W 13% 02-Apr 3:30 117.167 202 62 820 40 Pos. BS&W 14% page no: 1.7 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ X 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) ii ii -i i , , 02-Apr 4:00 117.667 204 62 825 40 Pos. BS&W 13% 02-Apr 4:30 118.167 208 62 825 40 Pos. BS&W 13% ,= 02-Apr 5:00 118.667 208 62 825 40 Pos. BS&W 13% 02-Apr 5:30 119.167 208 62 825 40 Pos. BS&w 16% · 02-Apr 6:00 119.667 202 62 830 40 Pos. BS&W 13% 02-Apr 6:30 120.167 202 62 850 40 Pos. BS&W 16% 02-Apr 7:00 120.667 214 62 850 40 Pos. BS&W 14%, gravity 37.9 at 60 ., 02-Apr 7:30 121.167 203 62 850 40 Pos. BS&W 16% 02-Apr 8:00 121.667 213 62 850 40 Pos. BS&W 14% ,, ,, 02-Apr 8:30 122.167 209 62 850 40 Pos. BS&W 15% 02-Apr 9:00 122.667 214 62 850 40 Pos. BS&W 14%, gravity 38.0 at 60 , 02-Apr 9:30 123.167 207 62 850 40 Pos. BS&W 17% 02-Apr 10:00 123.667 215 62 850 40 Pos. BS&W 13% 02-Apr 10:30 124.167 215 62 850 40 Pos. BS&W 16%, gravity 39.7 at 60 ,, 02-Apr 11:00 124.667 204 62 850 40 Pos. BS&W 12% 02-Apr 11:30 125.167 213 62 850 40 Pos. BS&W 12% 02-Apr 12:00 125.667 209 62 850 40 Pos. BS&W 10% 02-Apr 12:30 126.167 210 62 850 40 Pos. BS&W 12% 02-Apr 13:00 126.667 209 62 850 40 Pos. BS&W 10%, gravity 40.3 at 60 02-Apr 13:30 127.167 214 62 850 40 Pos. BS&W 14%, pumping demulsifier est..75 liter/hr. .._ 02-Apr 14:00 127.667 210 62 850 40 Pos. BS&W 8% 02-Apr 14:30 128.167 215 62 850 40 Pos. BS&W 6% 02-Apr 15:00 128.667 213 62 850 40 Pos. BS&W 8%, gravity 40.3 at 60 page no: 1.8 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ X 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 02-Apr 15:30 129.167 211 62 850 40 Pos. BS&W 7%,casing down to 450~ 02-Apr 16:00 129.667 219 62 450 40 Pos. BS&W 18% 02-Apr 16:30 130.167 223 62 450 40 Pos. BS&W 8% 02-Apr 17:00 130.667 219 62 450 40 Pos. BS&W 8% 02-Apr 17:30 131.167 218 62 450 40 Pos. BS&W 7%, gravity 39.8 at 60 02-Apr 18:00 131.667 216 62 475 40 Pos. BS&W 10% 02-Apr 18:30 132.167 220 62 480 40 Pos. BS&W 8% 02-Apr 19:00 132.667 223 62 490 40 Pos. BS&W 10% 02-Apr 19:30 133.167 224 62 490 40 Pos. BS&W 10% 02-Apr 20:00 133.667 222 62 490 40 Pos. BS&W 10% 02-Apr 20:30 134.167 220 62 490 40 Pos. BS&W 8% 02-Apr 21:00 134.667 222 62 490 40 Pos. BS%W 10% 02-Apr 21:30 135.167 219 62 490 40 Pos. BS&W 9% 02-Apr 22:00 135.667 224 62 490 40 Pos. BS&W 9% 02-Apr 22:30 136.167 217 62 490 40 Pos. BS&W 9% 02-Apr 23:00 136.667 217 62 490 40 Pos. BS&W 9% 02oApr 23:30 137.167 223 62 490 40 Pos. BS&W 9% 03-Apr 0:00 137.667 216 62 490 40 Pos. BS&W 9% 03-Apr 0:30 138.167 224 62 500 40 Pos. BS&W 9% 03-Apr 1:00 138.667 216 62 500 40 Pos. BS&W 9% 03-Apr 1:30 139.167 218 62 500 40 Pos. BS&W 10% 03-Apr 2:00 139.667 220 62 500 40 Pos. BS&W 10% 03-Apr 2:30 140.167 221 62 500 40 Pos. BS&W 9% page no: 1.9 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ X 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 03-Apr 3:00 140.667 221 62 500 40 Pos. BS&W 9% 03-Apr 3:30 141.167 224 62 500 40 Pos. BS&W 9% 03-Apr 4:00 141.667 224 62 500 40 Pos. BS&W 9% 03-Apr 4:30 142.167 221 62 500 40 Pos. BS&W 9% 03-Apr 5:00 142.667 226 62 500 40 Pos. BS&W 8% 03-Apr 5:30 143.167 224 62 500 40 Pos. BS&W 8% , 03-Apr 6:00 143.667 226 62 500 40 Pos. BS&W 8% 03-Apr 6:30 144.167 217 62 550 40 Pos. BS&W 8%, adj. choke, decrease bp on sep, 1.250 orifice 03-Apr 7:00 144.667 215 62 550 52 Adj. BS&W 6% 03-Apr 7:30 145.167 163 62 550 52 Adj. BS&W 7% 03-Apr 8:00 145.667 142 62 550 60 Adj. BS&W 6%, increase choke to 60~64 03-Apr 8:30 146.167 140 62 600 60 Adj. BS&W 8%, pumping defoamer 03-Apr 9:00 146.667 137 62 600 60 Adj. BS&W 8% · 03-Apr 9:30 147.167 136 62 600 60 Adj. BS&W 8% 03-Apr 10:00 147.667 133 62 600 60 Adj. BS&W 6% 03-Apr 10:30 148.167 134 62 600 60 Adj. BS&W 5% 03-Apr 11:00 148.667 141 62 600 60 Adj. BS&W 6% 03-Apr 11:30 149.167 139 62 600 60 Adj. BS&W6% 03-Apr 12:00 149.667 140 62 600 60 Adj. BS&W 5% 03-Apr 12:30 150.167 142 62 600 60 Adj. BS&W 7% 03-Apr 13:00 150.667 140 62 600 60Adj. BS&W6% , , 03-Apr 13:30 151.167 140 62 600 60 Adj. BS&W 8% 03-Apr 14:00 151.667 139 62 600 60 Adj. 'BS&W 7% page no: 1.10 Ptfrac / Job Log Halliburton Energy Services Sequer,.~e of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Ron Cookson Tubing Vol, bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 03-Apr 14:30 152.167 142 62 600 60 Adj. BS&W 7% 03-Apr 15:00 152.667 141 62 600 60 Adj. BS&W 7% 03-Apr 15:30 153.167 136 62 625 60 Adj. BS&W 8% 03-Apr 16:00 153.667 139 62 625 60 Adj. BS&W 6% 03-Apr 16:30 154.167 141 62 625 60 Adj. BS&W 7%. 03-Apr 17:00 154.667 139 62 625 60Adj. BS&W 6% , 03-Apr 17:30 155.167 139 62 625 60 Adj. BS&W 6% 03-Apr 18:00 155.667 141 62 625 60 Adj. BS&W 6% 03-Apr 18:30 156.167 139 62 625 60 Adj. BS&W 6% ,, 03-Apr 19:00 156.667 140 62 625 60 Adj. BS&W 6% 03-Apr 19:30 157.167 139 62 625 60 Adj. BS&W 6% 03-Apr 20:00 157.667 141 62 625 60 Adj. BS&W 5% 03-Apr 20:30 158.167 139 62 625 60 Adj. BS&W 5% 03-Apr 21:00 158.667 140 62 625 60 Adj. 3S&W 5% 03-Apr 21:30 159.167 142 62 625 60 Adj. BS&W 5% 03-Apr 22:00 159.667 144 62 625 60 Adj. BS&W 5% 03-Apr 22:30 160.167 143 62 625 60 Adj. BS&W 5% 03-Apr 23:00 160.667 143 62 635 00Adj. BS&W 5% , , 03-Apr 23:30 161.167 144 62 640 60 Adj. BS&W 5% 04-Apr 0:00 161.667 145 62 640 60 Adj. BS&W 6% 04-Apr 0:30 162.167 144 62 640 60 Adj. BS&W 6% 04-Apr 1:00 162.667 145 62 640 60 Adj. BS&W 6% 04-Apr 1:30 163.167 145 62 640 60Adj. BS&W 5% page no: 1.11 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ × 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure I Temperature Pressure Size Comments (hh:mm) (hfs) (psig) (Deg. F.) (psig) (64ths) 04-Apr 2:00 163.667 146 62 640 60 Adj. BS&W 5% 04-Apr 2:30 164.167 145 62 645 60 Adj. BS&W 5% 04-Apr 3:00 164.667 144 62 645 60 Adj. BS&W 5% 04-Apr 3:30 165.167 145 62 645 60 Adj. BS&W 5% 04-Apr 4:00 165.667 147 62 650 60 Adj. BS&W 5% 04-Apr 4:30 166.167 147 62 650 60 Adj. BS&W 5% 04-Apr 5:00 166.667 146 62 650 60 Adj. BS&W 5% 04-Apr 5:30 167.167 147 62 650 60 Adj. BS&W 5% 04-Apr 6:00 167.667 148 62 650 60 Adj. BS&W 5% 04-Apr 7:00 168.667 149 62 650 60 Adj. BS&W 5% 04oApr 8:00 169.667 150 62 650 60 Adj. BS&W 3% 04-Apr 9:00 170.667 148 62 650 60 Adj. BS&W 3% 04-Apr 10:00 171.667 147 62 650 60 Adj. BS&W 3%, oil gravity 38.9 at 60 04oApr 11:00 172.667 150 62 650 60 Adj. BS&W 4% 04-Apr 12:00 173.667 149 62 650 60 Adj. BS&W 4% .. 04-Apr 13:00 174.667 149 62 650 60 Adj. BS&W 4%, gravity 39.8 at 60 04-Apr 14:00 175.667 151 62 700 60 Adj. BS&W 4%, sampling from separator 04-Apr 15:00 176.667 151 62 700 60 Adj. BS&W 5% 04-Apr 16:00 177.667 149 62 700 60 Adj. BS&W 4% ., 04-Apr 17:00 178.667 149 62 700 60 Adj. BS&W 4% 04-Apr 18:00 179.667 147 62 700 60 Adj. BS&W 4% 04-Apr 19:00 180.667 148 62 700 60 Adj. @S&W 4% 04-A@r 20:00 181.667 149 62 700 60 Adj. BS&W 4% page no: 1.12 Ptfrac/Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# × 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 ',, Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64tbs) 04-Apr 21:00 182.667 149 62 700 60 Adj. BS&W 4% 04-Apr 22:00 183.667 149 62 700 60 Adj. BS&W 4% 04-Apr 23:00 184.667 150 62 700 60 Adj. BS&W 4% 05-Apr 0:00 185.667 150 62 710 60 Adj. BS&W 4.5% 05-Apr 1:00 186.667 150 62 710 60 Adj. BS&W 4% 05-Apr 2:00 187.667 148 62 710 60 Adj. BS&W 4% 05-Apr 3:00 188.667 150 62 710 60 Adj. BS&W 4% 05-Apr 4:00 189.667 149 62 720 60 Adj. BS&W 4% 05-Apr 5:00 190.667 150 62 720 60 Adj. BS&W 4% 05-Apr 6:00 191.667 147 62 720 60Adj. BS&W 4% 05-Apr 7:00 192.667 149 62 720 60 Adj. BS&W 4% 05-Apr 8:00 193.667 148 62 720 60 Adj. BS&W 3% 05-Apr 9:00 194.667 149 62 750 60 Adj. BS&W 3%, shut-in well to run gauges & downho!~ shut-in tool 05-Apr 10:00 195.667 881 0 0 Adj. 10:25 open well, waiting on battery housing for d/h shut-in tool 05-Apr 10:30 196.167 815 41 24 Adj. 05-Apr 11:00 196.667 561 48 34 Adj. 05-Apr 11:30 197.167 442 54 38 Adj. BS&W 2% . 05-Apr 12:00 197.667 415 58 500 42 Adj. BS&W 2% 05-Apr 12:30 198.167 323 62 500 60 Adj. BS&W 1% 05-Apr 13:00 198.667 336 62 500 60 Adj. BS&W 5.5% 05-Apr 13:30 199.167 196 62 60 Adj. BS&W 4%, shut-in well to run gauges, d/h shut-in tool 05-Apr 14:00 199.667 914 0 Adj. 05-Apr 14:30 200.167 24 Adj. 14:43 Open well for start of 24 hr max rate page no: 1.13 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO. Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500~ × 200" WC HES Rep: Ron Cookson Tubing Vol. bblift: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) ~-- ~ ~.x_. , 05-Apr 15:00 200.667 36 Adj. BS&W 4.5% 05-Apr 15:30 201.167 427 36 Adj. BS&W 4.5% 05-Apr 16:00 201.667 384 50 40 Adj. BS&W 3% 05-Apr 16:30 202.167 305 54 40 Adj. BS&W 4% 05-Apr 17:00 202.667 228 55 600 44 Adj. BS&W 2% 05-Apr 17:30 203.167 212 57 600 48 Adj. BS&W 4.5% 05-Apr 18:00 203.667 169 59 600 60 Adj. BS&W 3% 05-Apr 18:30 204.167 150 60 610 60 Adj. BS&W 2% 05-Apr 19:00 204.667 160 61 620 60 Adj. BS&W 2% 05oApr 19:30 205.167 158 62 640 60 Adj. BS&W 2% 05-Apr 20:00 205.667 158 62 660 60 Adj. BS&W 2% 05-Apr 20:30 206.167 165 62 680 60 Adj. BS&W 2.5% 05-Apr 21:00 206.667 163 62 700 60 Adj. BS&W 2% 05-Apr 21:30 207.167 162 62 710 60 Adj. BS&W 2% 05-Apr 22:00 207.667 162 62 730 60 Adj. BS&W 2% 05-Apr 22:30 208.167 162 62 760 60 Adj. BS&W 3.5% 05-Apr 23:00 208.667 162 63 760 60 Adj. BS&W 3.5% 05-Apr 23:30 209.167 162 63 775 60 Adj. BS&W 3% 06-Apr 0:00 209.667 162 63 790 60 Adj. BS&W 3% 06-Apr 0:30 210.167 162 63 795 60 Adj. BS&W 3% 06-Apr 1:00 210.667 161 63 800 60 Adj. BS&W 3% 06-Apr 1:30 211.167 160 63 800 60 Adj. BS&W 3% 06-Apr 2:00 211.667 160 63 800 60Adj. BS&W 3% page no: 1.14 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO_ Alaska, iNC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# × 200" WC HES Rep: Ron Cookson Tubing Vol. bbl/ft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) .,~ 06-Apr 2:30 212.167 159 63 800 60 Adj. BS&W 3% 06-Apr 3:00 212.667 160 63 800 60 Adj. BS&W 3% 06-Apr 3:30 213.167 159 63 805 60 Adj. BS&W 3% 06-Apr 4:00 213.667 160 63 810 60 Adj. BS&W 3% 06-Apr 4:30 214.167 159 63 810 60 Adj. BS&W 3% 06-Apr 5:00 214.667 161 63 810 60 Adj. BS&W 3% 06-Apr 5:30 215.167 159 65 820 60 Adj. 3S&W 3% 06-Apr 6:00 215.667 159 65 820 60 Adj. BS&W 3% 06-Apr 6:30 216.167 158 65 820 60 Adj. BS&W 3% 06-Apr 7:00 216.667 160 65 820 60 Adj. BS&W 3% 06-Apr 7:30 217.167 160 65 820 60 Adj. BS&W 3% 06-Apr 8:00 217.667 159 65 820 60 Adj. BS&W 4% 06-Apr 8:30 218.167 159 65 850 60 Adj. BS&W 3% 06-Apr 9:00 218.667 158 65 850 60 Adj. BS&W 3% 06-Apr 9:30 219.167 160 65 850 60 Adj. BS&W 3% 06-Apr 10:00 219.667 161 65 850 60 Adj. BS&W 3% 06-Apr 10:30 220.167 160 65 850 60 Adj. BS&W 3% 06-Apr 11:00 220.667 159 65 850 60 Adj. BS&W 3% 06-Apr 11:30 221.167 159 65 850 60Adj. BS&W3% 06-Apr 12:00 221.667 159 65 850 60 Adj. BS&W 3% 06-Apr 12:30 222.167 160 65 850 60 Adj. BS&W 3% 06-Apr 13:00 222.667 160 65 850 60 Adj. BS&W 3%.13:07 Shut in well downhole. 06-Apr 13:30 223.167 Bleed tubing to zero. End surface test. page no: 1.15 Ptfrac / Job Log Halliburton Energy Services Sequence of Events Customer: ARCO Alaska, INC. Well' Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.83 Barton Recorder Range: 1500# X 200" WC HES Rep: Ron Cookson Tubing Vol. bbllft: 0.01 Date / Time Delta Tubing Tubing Casing Choke (dd-mmm) Time Pressure Temperature Pressure Size Comments (hh:mm) (hrs) (psig) (Deg. F.) (psig) (64ths) 06-Apr 14:00 223.667 06oApr 14:30 224.167 Flush lines with 12 bbls methanol,10 bbls diesel, (water volumes.) ,,- , page no: 1.16 Ptfrac / Job Log Customer: ARCO Alaska, INC. Well: Neve No,1 Stage: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data Cumulative Volumes and Rates Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) , , 28-Mar 06:20 Commence Frac Stimulation 28-Mar 11:40 Frac complete,2728 bbbls pumped of jell,H20,sand 100,000 # 29-Mar 00:27 270.0 20 Adj. 0.00 0.00 0.00 0.00 0.00 Open well to A.P.C. Manifold & Tank. ,,, 2g-Mar 00:30 60.0 20 Adj. 100.0 0.130 0.00 0.00 0.130 0.00 .. All Fluids reported as Water until Oil to Surface. 29-Mar 00:45 45.0 20 Adj. 100.0 0.00 0.00 5.50 528.00 0.00 29-Mar 01:00 37.0 20 Adj. 100.0 0.00 0.00 11.00 528.00 0.130 29-Mar 01:15 36.0 20 Adj. 100.0 0.00 0.00 13.50 240.00 0.00 29-Mar 01:30 12.0 22 Adj. 100.0 0.00 0.00 15,78 218.69 . 0.00 29-Mar 01:55 10.0 64 Adj. 100.0 0.00 0.00 19.11 191,98 0.00 , ,, 29-Mar 02:00 5.0 64 Adj. 100.0 0.00 0.00 19.67 160.13 0.00 Frac fluid to surface 29-Mar 02:30 5.0 64 Adj. 100.0 0.130 0.00 20.97 62.30 0.00 29-Mar 03:00 5.0 64 Adj. 100.0 0.00 0.00 22.80 88.13 0.00 29-Mar 03:30 5.0 64 Adj. 100.0 0.00 0.{30 25.40 124.80 0.00 29-Mar 04:00 5.0 64 Adj. 100,0 0.00 0.00 28.00 124.80 0.00 38 bbls shipped from frac tank 29-Mar 04:30 5.0 64 Adj. 100.0 0.00 0.00 29.93 92.59 0.00 29-Mar 05:00 0.0 64 Adj. 100.0 0.00 0.00 31.86 92.59 0.(30 29-Mar 05:30 0.0 64 Adj. 100.0 0.00 0.00 33.79 92.59 0.00 29-Mar 06:00 0.0 64 Adj. 100.0 0.00 0.00 35.72 92.59 0.00 Page 2.1 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates II Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 29-Mar 07:00 0.0 64 Adj. 100.0 0.00 0.00 38.34 62.86 0.00 29-Mar 08:00 0.0 64 Adj. 100.0 0.00 0.00 40.34 48.00 0.00 29-Mar 09:00 0.0 64 Adj. 100.0 0.00 0.00 42.00 40.01 0.00 29-Mar 10:00 0.0 64 Adj. 100.0 0.00 0.00 42.00 0.00 0.00 29-Mar 11:00 ' 0.0 64 Adj. 100.0 0.00 0.00 42.25 6.00 0.00 29-Mar 12:00 0.0 64 Adj. 100.0 0.00 0.00 42.50 6.00 0.00 29-Mar 13:00 0.0 64 Adj. 100.0 0.00 0.00 42.75 6.00 0.00 29-Mar 13:30 0.0 24 Adj. 100.0 0.00 0.00 43.00 12.00 0.00 29-Mar 14:00 0.0 24 Adj. 100.0 0.00 0.00 43.50 24.00 0.00 29-Mar 15:00 0.0 128 Adj. 100.0 0.00 0.00 44.50 24.00 0.00 Bypass choke direct to tank 29-Mar 16:00 0.0 128 Adj.' 100.0 0.00 0.00 45.50 24.00 0.00 29-Mar 17:00 0.0 128 Adj. 100.0 0.00 0.00 46.50 24.00 0.00 29-Mar 18:00 0.0 128 Adj. 100.0 0.00 0.00 47.50 24.00 0.00 29-Mar 19:00 0.0 128 Adj. 100.0 0.00 0.00 48.50 24.00 0.00 29-Mar 20:00 0.0 128 Adj. 100.0 0.00 0.00 49.50 24.00 0.00 29-Mar 21:00 0,0 128 Adj. 100.0 0.00 0.00 50.25 18.00 0.00 Monitor well thru night 29-Mar 22:00 0.0 128 Adj. 100.0 0.00 0.00 50.75 12.00 0.00 29-Mar 23:00 0.0 128 Adj. 100.0 0.00 0.00 51.25 12.00 0.00 Page 2.2 Final_Reports/Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 I Wellhead Data Cumulative Volumes and Rates I Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas 't Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate G©R Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 30-Mar O0:00 0.0 128 Adj. 100.0 0.00 0.00 51.50 6.00 0.00 30-Mar 01:00 0.0 128 Adj. 100.0 0.00 0.00 51.50 0.00 0.00 30-Mar 02:00 0.0 128 Adj. 100.0 0.00 0.00 52.00 12.00 0.00 30-Mar 03:00 0.0 128 Adj. 100.0 0.00 0.00 52.50 12.00 0.00 30-Mar 04:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 12.00 0.00 30-Mar 05:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 30-Mar 06:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 31 bbls Fluid Recovered 30-Mar 07:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 30-Mar 08:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 30-Mar 09:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 30-Mar 10:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 30-Mar 11:00 0.0 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 30-Mar 12:00 128 Adj. 100.0 0.00 0.00 53.00 0.00 0.00 Dowell Schlumberger on location.Shut in well @ wing valuve. 30-Mar 13:00 30-Mar 14:00 30-Mar 15:00 30-Mar 16:00 30-Mar 17:00 Page 2.3 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates II Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 30-Mar 18:00 Wait on Dowell Schlumberger 30-Mar 19:00 30-Mar 20:00 30-Mar 21:00 30-Mar 22:00 D.S. rig up C.T. on well 30-Mar 22:30 D.S. pressure test BOP'S 30-Mar 23:00 31-Mar O0:00 31-Mar O1:00 0.0 128 Adj. 100.0 0.00 0.00 69.20 388.80 0.00 Open wing valve,D.S, run in hole C.T. to jet well with diesel. 31-Mar 02:00 0.0 128 Adj. 100.0 0.00 0.00 85.40 388.80 0.00 ,' 31-Mar 03:00 0.0 128 Adj. 100.0 0.00 0.00 101.60 388.80 0.00 31-Mar 04:00 0.0 128 Adj. 100.0 0.00 0.00 117.80 388.80 0.00 25% H20,75% Diesel,Trace mud. 31-Mar 04:30 0.0 128 Adj. 100.0 0.00 0.00 134.00 777.60 0.00 4% H20, 96% Diesel,trace mud. 31-Mar 05:00 0.0 128 Adj. 100.0 0.00 0.00 150.20 777.60 0.00 .5% H20, 99.5% Diesel,trace mud. 31-Mar 05:30 0.0 128 Adj. 100.0 0.00 0.00 166.40 777.60 0.00 .25% H20, 99.75% Diesel,trace mud-D.S, out of hole. 31-Mar 06:00 385.0 100.0 0.00 0.00 182.60 777.60 0.00 Well shut in to rig down D.S., 81 bbls recovered. 31-Mar O6:15 34 Adj. 0.00 0.00 182.60 0.00 0.00 Open well to A.P.C. Manifold & Tank. 31-Mar 06:30 10.0 34 Adj. 100.0 0.00 0.00 185.60 144.00 0.00 .- Page 2.4 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scoff Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 150C~ X 200" WC H.E.S. Rep: Eon Cookson Storage Tank Coeff: 1.6667 ......................................................... Wellhead Data Ii ........................................................ Cumulative Volumes and Rates Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 31-Mar 07:00 150.0 32 Adj. 100.0 0.00 0.00 201.60 768.00 0.00 Rocking choke 31-Mar 07:30 110.0 32 Adj. 100.0 0.00 0.00 206.60 240.00 0.00 Rocking choke trying to establish & maintain 30 bbl/hr rate. 31-Mar 08:00 70.0 32 Adj. 100.0 0.00 0.00 217.85 540.00 0.00 Rocking choke, BS&W 75%, trace of sand, all diesel 31-Mar 08:30 80.0 32 Adj. 100.0 0.00 0.00 229.60 564.00 0.00 .. Rocking choke, BS&W 75%, trace of sand, oil to surface 31-Mar 09:00 90.0 32 Adj. 60.0 6.94 333.25 239.80 489.60 0.00 Rocking choke, BS&W 60%,trace of sand 31-Mar 09:30 100.0 32 Adj. 60.0 10.21 156.83 244.60 230.40 0.00 Rocking choke, BS&W 60%,trace of sand,chlorides 26,000ppm 31-Mar 10:00 90.0 32 Adj. 60.0 15.52 254.84 252.40 374.40 0.00 Rocking choke, BS&W 60%,trace of mud 31-Mar 10:30 100.0 32 Adj. 60.0 22.46 333.25 262.60 489.60 0.00 Rocking choke, BS&W 60%,trace of mud, chlorides 3100Oppm 31-Mar 11:00 95.0 32 Adj. 60.0 28.18 274.44 271.00 403.20 0.00 ,Rocking choke, BS&W 60%,trace of mud, chlorides 260OOppm 31-Mar 11:30 95.0 32 Adj. 60.0 33.54 257.29 278.88 378.00 0.00 Rocking choke, BS&W 60%,trace of mud, chlorides 28000ppm 31-Mar 12:00 115.0 30 Adj. 60.0 40.84 350.41 289.60 514.80 0.00 Rocking choke, BS&W 60%,trace of mud, chlorides 30000ppm 31-Mar 12:30 120.0 30 Adj. 60.0 44.92 196.03 295.60 288.00 0.00 Rocking choke, BS&W 60%,trace of mud, chlorides 30000ppm 31-Mar 13:00 115.0 30 Adj. 60.0 49.01 196.03 301.60 288.00 0.00 Rocking choke, BS&W 60%,trace of mud, chlorides 30000ppm 31-Mar 13:30 120.0 30 Adj. 50.0 59.22 490.08 311.60 480.00 0.00 Rocking choke, BS&W 50%, trace of mud, chlorides 29000ppm 31-Mar 14:00 120.0 650.0 30 Adj. 50.0 69.43 490.08 321.60 480.00 0.00 Rocking choke, BS&W 50%, trace of mud, chlorides 29500ppm 31-Mar 14:30 120.0 30 Adj. 50.0 76.06 318.55 328.10 312.00 0.00 Rocking choke, BS&W 50%, trace of mud, chlorides 29000ppm 31-Mar 15:00 120.0 30 Adj. 55.0 83.42 352.86 336.90 422.40 0.00 Rocking choke, BS&W 55%, trace of mud, chlorides 29000ppm 31-Mar 15:30 120.0 30 Adj. 55.0 88.47 242.59 342.95 290.40 0.00 Rocking choke, BS&W 55%, trace of mud Page 2.5 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 31-Mar 16:00 110.0 30 Adj. 55.0 95.36 330.80 351.20 396.00 0.00 Rocking choke, BS&W 55%, trace of mud, chlorides 29500ppm 31-Mar 16:30 110.0 30 Adj. 55.0 102.25 330.80 359.45 396.00 0.00 Rocking choke, BS&W 55%, trace of mud 31-Mar 17:00 110.0 30 Adj. 50.0 108.38 294.05 365.45 288.00 0.00 Rocking choke, BS&W 50%, trace of mud, chlorides 29000ppm , , 31-Mar 17:30 110.0 700.0 30 Adj. 50.0 117.57 441.07 374.45 432.00 0.00 .. BS&W 50%, trace of mud, no debris in choke over half hour 31-Mar 18:00 150.0 30 Adj. 60.0 121.65 196.03 380.45 288.00 0.00 Rock choke,BS&W 60% H20,trace of mud,chlorides 29,00Oppm 31-Mar 18:30 200.0 30 Adj. 40.0 121.65 0.00 380.45 0.00 0.00 Rock choke,BS&W 40%,trace of sand. No debris in choke 31-Mar 19:00 200.0 700.0 30 Adj. 40.0 126.96 254.85 383.92 166.41 0.00 BS&W 40%,Trace of sand. 31-Mar 19:30 130.0 710.0 34 Adj. 35.0 137.90 524.85 389.69 276.80, 0.00 BS&W 35%,trace of sand. 31-Mar 20:00 135.0 720.0 34 Adj. 30.0 147.08 441.07 393.54 185.14 0.00 BS&W 30%,trace of sand. ~t. 31-Mar 20:30 185.0 730.0 32 Adj. 30.0 155.66 411.67 397.14 172.80 0.00 BS&W 30%,trace of sand-rock choke 31-Mar 21:00 175.0 740.0 32 Adj. 30.0 164.95 445.97 401.04 187.20 0.00 BS&W 30%,trace of sand-rock choke 31-Mar 21:30 80.0 750.0 32 Adj. 15.0 178.84 666.51 403.44 115.20 0.00 BS&W 15%,trace of sand-rock choke 31-Mar 22:00 180.0 750.0 32 Adj. 28.0 184.20 257.59 405.49 98.11 0.00 BS&W 28%trace of sand-rock choke 31-Mar 22:30 210.0 750.0 32 Adj. 25.0 195.84 558.69 409.29 182.40 0.00 BS&W 25%,trace of sand-rock choke 31-Mar 23:00 150.0 760.0 32 Adj. 15.0 212.33 791.48 412.14 136.80 0.00 BS&W 15%,trace of sand-rock choke 31-Mar 23:30 80.0 790.0 32 Adj. 30.0 224.04 562.10 417.05 235.94 0.00 BS&W 30%trace of sand 1-Apr 00:00 150.0 800.0 34 Adj. 25.0 235.33 541.92 420.71 175.38 0.00 BS&W 25%,choke {~ 34/64-trace of sand 1-Apr 00:30 180.0 800.0 34 Adj. 20.0 249.30 670.43 424.13 164.16 0.00 BS&W 20%,trace sand-rock choke Page 2.6 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 1-Apr 01:00 150.0 800.0 34 Adj. 26.0 256.70 355.41 426.67 122.30 0.00 BS&W 26%,trace of sand 1-Apr 01:30 180.0 825.0 34 Adj. 20.0 271.98 733.16 430.41 179.52 0.00 BS&W 20%,trace sand-rock choke l-Apr 02:00 165.0 845.0 34 Adj. 23.0 286.92 716.99 434.78 209.76 0.00 BS&W 23%,trace sand. 1-Apr 02:30 150.0 845.0 34 Adj. 15.0 298.37 549.87 436.76 95.04 0.00 BS&W 15%,trace sand l-Apr 03:00 150.0 845.0 34 Adj. 15.0 311.56 633.18 439.04 109.44 0.00 BS&W 15%,trace sand. l-Apr 03:30 150.0 850.0 34 Adj. 18.0 336.26 1185.50 444.35 254.88 0.00 BS&W 18%,trace sand. 1-Apr 04:00 160.0 860.0 34 Adj. 22.0 351.07 711.01 448.45 196.42 0.00 BS&W 22%,trace sand,rock choke 1-Apr 04:30 160.0 865.0 34 Adj. 22.0 362.62 554.28 451.64 153.12 0.00 BS&W 22%,trace sand,rock choke l-Apr 05:00 160.0 865.0 34 Adj. 13.0 375.61 623.69 453.52 90.48 0.00 BS&W 13%,trace sand. l-Apr 05:30 165.0 880.0 34 Adj. 14.0 387.86 587.95 455.47 93.74 0.00 BS&W 14%,trace sand. l-Apr 06:00 165.0 890.0 34 Adj. 14.0 402.83 718.60 457.86 114.58 0.00 BS&W 14%,trace sand. 1-Apr 06:30 165.0 900.0 34 Adj. 15.0 416.29 645.68 460.19 111.60 0.00 BS&W 15%,trace sand 1-Apr 07:00 34 Adj. 14.0 429.90 653.28 462.36 104.16 0.00 l-Apr 07:30 34 Adj. 16.0 446.16 780.81 465.39 145.67 0.00 l-Apr 08:00 34 Adj. 15.0 462.62 790.10 468.24 136.56 0.00 1-Apr 08:30 201.0 34 Adj. 17.0 .'.i 478.70 ,771.51 471.46 154.77 0.00 Direct flow thru separator. l-Apr 09:00 226.0 34 Adj. 20.0 478.70 0.00 471.46 0.00 0.00 1-Apr 09:30 260.0 34 Adj. 22.0 483.90 249.64 472.93 70.44 5.89 282.77 1.133 Rock choke Page 2.7 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates I Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumin. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) l-Apr 10:00 403.0 34 Adj. 22.0 489.66 276.48 474.58 79.20 14.63 419.60 1.518 BS&W 22%,trace sand. 1-Apr 10:30 475.0 34 Adj. 30.0 504.55 714.86 481.08 312.05 24.00 449.72 0.629 BS&W 30%,trace sand. 1-Apr 11:00 273.0 800.0 34 Adj. 30.0 514.27 466.45 485.33 204.05 30.11 293.40 0.629 BS&W 30%,trace sand. l-Apr 11:30 213.0 50.0 40 Pos. 16.0 523.19 428.41 487.06 83.17 40.21 484.63 1.131 Choke 40/64 ADJ.Bleed casing to 500 psi. BS&W 20%,trace sand. l-Apr 12:00 143.0 55.0 40 Pos. 8.0 542.02 903.76 488.73 79.99 49.10 426.64 0.472 Choke change 40/64 POS.@ 11:18.BS&W 15%,trace sand. 1-Apr 12:30 148.0 55.0 40 Pos. 8.0 559.01 815.54 490.23 72.00 57.99 426.64 0.523 BS&W 16%,trace sand. l-Apr 13:00 188.0 58.0 600.0 40 Pos. 20.0 567.87 425.35 492.48 108.00 67.13 438.99 1.032 BS&W 18%,trace sand. l-Apr 13:30 169.0 58.0 625.0 40 Pos. 12.0 586.64 900.60 495.08 124.82 76.28 438.99 0.487 BS&W 8%,trace sand. l-Apr 14:00 178.0 57.0 650.0 40 Pos. 10.0 625.01 1841.72 499.41 207.98 85.42 438.99 0.238 BS&W 20%,trace sand. l-Apr 14:30 174.0 57.0 660.0 40 Pos. 6.0 641.19 776.89 500.46 50.40 95.20 469.40 0.604 BS&W 12%,trace sand. 1-Apr 15:00 185.0 58.0 675.0 40 Pos. 9.0 656.86 752.09 502.04 75.60 104.98 469.40 0.624 BS&W 10%,trace sand. l-Apr 15:30 172.0 58.0 675.0 40 Pos. 18.0 671.54 704.88 505.34 158.37 114.13 438.99 0.623 BS&W 6%,trace sand. l-Apr 16:00 166.0 58.0 675.0 40 Pos. 22.0 682.42 521.98 508.45 149.64 123.27 438.99 0.841 BS&W 9%,trace sand. l-Apr 16:30 195.0 56.0 700.0 40 Pos. 14.0 695.81 642.94 510.67 106.38 132.07 422.17 0.657 BS&W 18%,trace sand. l-Apr 17:00 177.0 56.0 700.0 40 Pos. 20.0 709.26 645.31 514.09 163.97 141.30 443.24 0.687 BS&W 22%,trace sand. l-Apr 17:30 178.0 56.0 700.0 40 Pos. 15.0 724.24 719.36 516.77 129.02 150.55 443.67 0.617 BS&W 14%,trace sand. 1-Apr 18:00 197.0 56.0 700.0 40 Pos. 16.0 737.33 627.99 519.31 121.57 159.79 443.67 0.706 BS&W 20%,trace sand. l-Apr 18:30 169.0 56.0 710.0 40 Pos. 6.0 754.29 814.18 520.41 52.82 170.88 532.28 0.654 BS&W 15%,trace sand. Page 2.8 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1,6667 Wellhead Data II Cumulative Volumes and Rates Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) l-Apr 19:00 206.0 61.0 750.0 40 Pos. 6.0 773.53 923.40 521.66 59.99 181.72 520.32 0.563 BS&W 6%,trace sand. 1-Apr 19:30 202.0 60.0 750.0 40 Pos. 20.0 790.56 817.57 525.99 208.03 192.56 520.32 0.636 BS&W 20 l-Apr 20:00 191.0 61.0 760.0 40 Pos.: 21.0 806.08 745.13 530.19 201.60 203.40 520.32 0.698 BS&W 21% 1-Apr 20:30 192.0 61.0 775.0 40 Pos. 20.0 822.45 785.87 534.36 199.97 214.68 541.65 0.689 BS&W 20% 1-Apr 21:00 195.0 61.0 800.0 40 Pos. 20.0 835.88 644.39 537.77 163.97 226.11 548.58 0.851 BS&W 20%.Change orfice plate to 1.00" .., l-Apr 21:30 205.0 61.0 800.0 40 Pos. 20.0 851.48 748.80 541.77 192.00 237.03 523.90 0.700 BS&W 20% -, l-Apr 22:00 207.0 61.0 800.0 40 Pos. 20.0 865.56 676.09 545.36 172.03 248.14 533.48 0.789 3S&W 20% 1-Apr 22:30 207.0 62.0 800.0 40 Pos. 18.0 881.01 741.33 548.81 165.63 259.25 533.48 0.720 BS&W 18%.Haul oil from tanks l-Apr 23:00 200.0 62.0 800.0 40 Pos. 18.0 897.12 773.42 552.41 172.80 270.43 536.64 0.694 BS&W 18%. ,, l-Apr 23:30 206.0 62.0 800.0 40 Pos. 16.0 913.28 775.65 555.54 150.37 281.61 536.64 0.692 BS&W 16% 2-Apr 00:00 204.0 62.0 800.0 40 Pos. 16.0 925.65 593.79 557.94 115.20 292.92 542.91 0.914 BS&W 16% 2-Apr 00:30 208.0 62.0 805.0 40 Pos. 15.0 946.52 1001.44 561.69 180.00 304.24 542.91 0.542 BS&W 15% 2-Apr 01:00 207.0 62.0 805.0 40 Pos. 15.0 957.64 533.97 563.69 95.98 315.55 542.91 1.017 BS&W 15% ,_ 2-Apr 01:30 210.0 62.0 810.0 40 Pos. 12.0 979.96 1071.20 566.79 148.78 326.86 542.91 0.507 BS&W 12% 2-Apr 02:00 209.0 62.0 810.0 40 Pos. 9.0 995.97 768.50 568.40 77.41 338.17 542.91 0.706 BS&W 9% 2-Apr 02:30 203.0 62.0 810.0 40 Pos. 15.0 1013.70 851.22 571.59 153.00 349.48 542.91 0.638 BS&W 13% 2-Apr 03:00 201.0 62.0 820.0 40 Pos. 13.0 1026.87 632.22 573.60 96.22 360.85 546.01 0.864 BS&W 13% ,,_ 2-Apr 03:30 202,0 62.0 820.0 40 Pos. 14.0 1045.52 894.87 576.69 148.38 372.42 555.23 0.620 BS&W 14% Page 2.9 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 I I Wellhead Data I Cumulative Volumes and Rates I Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 2-Apr 04:00 204.0 62.0 825.0 40 Pos. 13.0 1060.10 700.28 578.91 106.58 383.80 546.01 0.780 BS&W 13% 2-Apr 04:30 208.0 62.0 825.0 40 Pos. 13.0 1075.76 751.53 581.29 114.38 395.17 546.01 0.727 BS&W 13% 2-Apr 05:00 208.0 62.0 825.0 40 Pos. 13.0 1093.20 837.22 583.94 127.42 406.74 555.23 0.663 BS&W 13% 2-Apr 05:30 208.0 62.0 825.0 40 Pos. 16.0 1111.41 874.06 587.48 169.57 418.31 555.23 0.635 BS&w 16% 2-Apr 06:00 202.0 62.0 830.0 40 Pos. 13.0 1125.54 678.04 589.64 104.02 429.87 555.23 0.819 BS&W 13% 2-Apr 06:30 202.0 62.0 850.0 40 Pos. 16.0 1142.03 791.72 592.84 153.60 441,48 557.18 0.704 BS&W 16% 2-Apr 07:00 214.0 62.0 850.0 40 Pos. 14.0 1158.57 793.55 595.59 131.58 453.09 557.18 0.702 BS&W 14%, gravity 37.9 at 60 2-Apr 07:30 203.0 62.0 850.0 40 Pos. 16.0 1171.28 610.42 598.05 118.43 464.76 560.23 0.918 BS&W 16% 2-Apr 08:00 213.0 62.0 850.0 40 Pos. 14.0 1188.87 844.21 600.97 139.98 476.43 560.23 0.664 BS&W 14% 2-Apr 08:30 209.0 62.0 850.0 40 Pos. 15.0 1206.60 851.22 604.16 153.00 488.10 560.23 0.658 BS&W 15% 2-Apr 09:00 214.0 62.0 850.0 40 Pos. 14.0 1220.32 658.59 606.43 109.20 499.77 560.23 0.851 !BS&W 14%, gravity 38.0 at 60 2-Apr 09:30 207.0 62.0 850.0 40 Pos. 17.0 1236.62 782.30 609.83 163.20 511.51 563.27 0.720 BS&W 17% 2-Apr 10:00 215.0 62.0 850.0 40 Pos. 13.0 1252.28 751.53 612.21 114.38 523.24 563.27 0.749 BS&W 13% 2-Apr 10:30 215.0 62.0 850.0 40 Pos. 16.0 1268.64 785.43 615.41 153.60 535.10 569.29 0.725 BS&W 16%, gravity 39.7 at 60 2-Apr 11:00 204.0 62.0 850.0 40 Pos. 12.0 1285.92 829.42 617.81 115.20 546.96 569.29 0.686 BS&W 12% 2-Apr 11:30 213.0 62.0 850.0 40 Pos. 12.0 1301.40 743.16 619.96 103.22 558.76 566.29 0.762 BS&W 12% 2-Apr 12:00 209.0 62.0 850.0 40 Pos. 10.0 1319.81 883.48 622.05 99.98 570.37 557.18 0.631 BS&W 10% 2-Apr 12:30 210.0 62.0 850.0 40 Pos. 12.0 1337.31 840.11 624.50 117.62 581.89 552.82 0.658 BS&W 12% Page 2,10 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data Cumulative Volumes and Rates Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate G©R Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 2-Apr 13:00 209.0 62.0 850.0 40 Pos. 10.0 1352.41 724.43 626.21 81.98 593.40 552.82 0.763 BS&W 10%, gravity 40.3 at 60 2-Apr 13:30 214.0 62.0 850.0 40 Pos. 14.0 1368.24 759.91 628.83 126.00 605.11 561.95 0.739 BS&W 14%, pumping demulsifier est..75 liter/hr. 2~Apr 14:00 210.0 62.0 850.0 40 Pos. 8.0 1384.42 776.94 630.26 68.81 616.56 549.74 0.708 BS&W 8% 2-Apr 14:30 215.0 62.0 850.0 40 Pos. 6.0 1402.49 867.37 631.44 56.39 628.02 549.74 0.634 BS&W 6% 2-Apr 15:00 213.0 62.0 850.0 40 Pos. 8.0 1420.93 885.02 633.07 78.41 639.82 566.64 0.640 BS&W 8%, gravity 40.3 at 60 2-Apr 15:30 211.0 62.0 850.0 40 Pos. 7.0 1438.43 839.87 634.42 64.41 651.63 566.64 0.675 BS&W 7%,casing down to 450# 2-Apr 16:00 219.0 62.0 450.0 40 Pos. 18.0 1453.18 708.09 637.71 158.37 663.43 566.64 0.800 BS&W 18% 2-Apr 16:30 223.0 62.0 450.0 40 Pos. 8.0 1471.24 866.82 639.31 76.80 675.24 566.64 0.654 BS&W 8% 2-Apr 17:00 219.0 62.0 450.0 40 Pos. 8.0 1489.30 866.82 640.91 76.80 686.99 564.31 0.651 BS&W 8% 2-Apr 17:30 218.0 62.0 450.0 40 Pos. 7.0 1507.79 887.39 642.34 68.61 698.80 566.64 0.639 BS&W 7%, gravity 39.8 at 60 2-Apr 18:00 216.0 62.0 475.0 40 Pos. 10.0 1525.08 830.17 644.30 93.98 710.37 555.23 0.669 BS&W 10% 2-Apr 18:30 220.0 62.0 480.0 40 Pos. 8.0 1540.88 758.46 645.70 67.20 721.93 555.23 0.732 BS&W 8% 2-Apr 19:00 223.0 62.0 490.0 40 Pos. 10.0 1557.81 812.78 647.62 92.02 733.74 566.49 0.697 BS&W 10% 2-Apr 19:30 224.0 62.0 490.0 40 Pos. 10.0 1576.58 900.97 649.74 102.00 745.47 563.08 0.625 BS&W 10% 2-Apr 20:00 222.0 62.0 490.0 40 Pos. 10.0 1594.63 866.09 651.79 98.02 757.70 587.44 0.678 BS&W 10% 2-Apr 20:30 220.0 62.0 490.0 40 Pos. 8.0 1609.69 722.75 653.12 64.01 769.94 587.44 0.813 BS&W 8% 2-Apr 21:00 222.0 62.0 490.0 40 Pos. 10.0 1627.73 866.09 655.16 98.02 782.18 587.44 0.678 BS%W 10% 2-Apr 21:30 219.0 62.0 490.0 40 Pos. 9.0 1641.13 643.28 656.51 64.80 794.42 587.44 0.913 BS&W 9% Page 2.11 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 ii Wellhead Data II Cumulative Volumes and Rates II Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate G©R Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 2-Apr 22:00 224.0 62.0 490.0 40 Pos. 9.0 1661.23 964.91 658.54 97.20 806.66 587.44 0.609 BS&W 9% 2-Apr 22:30 217.0 62.0 490.0 40 Pos. 9.0 1678.96 850.89 660.34 86.40 818.97 590.84 0.694 BS&W 9% 2-Apr 23:00 217.0 62.0 490.0 40 Pos. 9.0 1695.34 786.08 661.99 79.19 831.28 590.84 0.752 BS&W 9% 2-Apr 23:30 223.0 62.0 490.0 40 Pos. 9.0 1713.58 875.71 663.82 88.21 843.83 602.77 0.688 BS&W 9% 3-Apr 00:00 216.0 62.0 490.0 40 Pos. 9.0 1729.59 768.50 665.44 77.41 856.39 602.77 0.784 BS&W 9% 3-Apr 00:30 224.0 62.0 500.0 40 Pos. 9.0 1746.34 804.09 667.12 81.00 868.90 600.62 0.747 BS&W 9% 3-Apr 01:00 216.0 62.0 500.0 40 Pos. 9.0 1765.70 929.32 669.07 93.61 881.42 600.62 0.646 BS&W 9% 3-Apr 01:30 218.0 62.0 500.0 40 Pos. 10.0 1781.90 777.44 670.91 87.98 893.99 603.70 0.777 BS&W 10% 3-Apr 02:00 220.0 62.0 500.0 40 Pos. 10.0 1799.94 866.09 672.95 98.02 906.64 606.77 0.701 BS&W 10% 3-Apr 02:30 221.0 62.0 500.0 40 Pos. 10.0 1819.83 954.31 675.20 108.00 919.28 606.77 0.636 BS&W 9% 3-Apr 03:00 221.0 62.0 500.0 40 Pos. 9.0 1833.23 643.28 676.55 64.80 931.92 606.77 0.943 BS&W 9% 3-Apr 03:30 224.0 62.0 500.0 40 Pos. 9.0 1851.10 857.70 678.35 86.40 944.56 606.77 0.707 BS&W 9% 3-Apr 04:00 224.0 62.0 500.0 40 Pos. 9.0 1867.85 804.09 680.04 81.00 957.20 606.77 0.755 BS&W 9% 3-Apr 04:30 221.0 62.0 500.0 40 Pos. 9.0 1886.83 911.31 681.95 91.80 969.84 606.77 0.666 BS&W 9% 3-Apr 05:00 226.0 62.0 500.0 40 Pos. 8.0 1903.39 794.72 683.42 70.39 982.48 606.77 0.764 BS&W 8% 3-Apr 05:30 224.0 62.0 500.0 40 Pos. 8.0 1919.82 788.41 684.88 70.39 995.12 606.77 0.770 BS&W 8% 3-Apr 06:00 226.0 62.0 500.0 40 Pos. 8.0 1937.50 848.92 686.45 75.19 1008.01 618.58 0.729 BS&W 8% 3-Apr 06:30 217.0 62.0 550.0 40 Pos 8.0 1957.82 975.52 688.25 86.40 1020.90 618.58 0.634 BS&W 8%, adj. choke, decrease bp on sep, 1.250 orifice Page 2.12 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scoff Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumin. Rate Cumin Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 3-Apr 07:00 215.0 62.0 550.0 52 Adj. 6.0 1974.74 812.00 689.35 52.79 1036.08 728.77 0.898 BS&W 6% 3-Apr 07:30 163.0 62.0 550.0 52 Adj. 7.0 1997.62 1098.03 691.10 84.00 1053.94 857.17 0.781 BS&W 7% 3-Apr 08:00 142.0 62.0 550.0 60 Adj. 6.0 2019.81 1065.47 692.55 69.61 1071.48 842.00 0.790 BS&W 6%, increase choke to 60/64 ,, ,, 3-Apr 08:30 140.0 62.0 600.0 60 Adj. 8.0 2039.40 940.20 694.28 83.21 1086.64 727.70 0.774 BS&W 8%, pumping defoamer 3-Apr 09:00 137.0 62.0 600.0 60 Adj. 8.0 2059.74 976.21 696.08 86.40 1101.98 736.42 0.754 BS&W 8% 3-Apr 09:30 136.0 62.0 600.0 60 Adj. 8.0 2080.46 994.43 697.92 88.01 1118.20 778.62 0.783 BS&W 8% , 3-Apr 10:00 133.0 62.0 600.0 60 Adj. 6.0 2101.82 1025.28 699.32 67.19 1134.77 795.19 0.776 ~BS&W 6% 3-Apr 10:30 134.0 62.0 600.0 60 Adj. 5.0 2120.08 876.60 700.29 46.99 1151.34 795.19 0.907 BS&W 5% 3-Apr 11:00 141.0 62.0 600.0 60 Adj. 6.0 2140.84 996.72 701.64 64.80 1168.50 823.87 0.827 :BS&W 6% 3-Apr 11:30 139.0 62.0 600.0 60Adj. 6.0 2162.76 1052.10 703.07 68.40 1184.61 773.53 0.735 BS&W6% 3-Apr 12:00 140.0 62.0 600.0 60 Adj. 5.0 2182.81 962.46 704.15 52.01 1200.27 751.62 0.781 BS&W 5% 3-Apr 12:30 142.0 62.0 600.0 60 Adj. 7.0 2202.22 931.34 705.64 71.40 1215.85 747.47 0.803 BS&W 7% 3-Apr 13:00 140.0 62.0 600.0 60 Adj. 6.0 2224.14 1052.10 707.07 68.40 1231.85 768.01 0.730 BS&W6% 3-Apr 13:30 140.0 62.0 600.0 60 Adj. 8.0 2243.33 921.32 708.77 81.60 1247.85 768.01 0.834 BS&W 8% 3-Apr 14:00 139.0 62.0 600.0 60 Adj. 7.0 2263.71 978.29 710.34 75.60 1263.85 768.01 0.785 !BS&W 7% 3-Apr 14:30 142.0 62.0 600.0 60 Adj. 7.0 2285.01 1022.50 711.97 78.39 1280.18 784.08 0.767 BS&W 7% 3-Apr 15:00 141.0 62.0 600.0 60 Adj. 7.0 2304.03 912.93 713.43 69.99 1296.18 768.01 0.841 BS&W 7% 3-Apr 15:30 136.0 62.0 625.0 60 Adj. 8.0 2325.86 1047.92 715.37 92.81 1312.52 784.08 0.748 BS&W 8% Page 2.13 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data I Cumulative Volumes and Rates II Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 3-Apr 16:00 139.0 62.0 625.0 60 Adj. 6.0 2344.93 915.41 716,62 59.99 1328.52 768.01 0.839 BS&W 6% 3-Apr 16:30 141.0 62.0 625.0 60 Adj. 7.0 2365.48 986.12 718,19 75.60 1343.83 734.88 0.745 BS&W 7%. 3-Apr 17:00 139.0 62.0 625.0 60 Adj. 6.0 2386.24 996.72 719.54 64.80 1360.16 784.08 0,787 BS&W 6% 3-Apr 17:30 139.0 62.0 625.0 60 Adj. 6.0 2406.62 978.12 720.87 63.59 1376.50 784.08 0,802 BS&W 6% 3-Apr 18:00 141.0 62.0 625.0 60 Adj. 6.0 2426.46 952.33 722.17 62.41 1392.83 784.08 0.823 BS&W 6% 3-Apr 18:30 139.0 62.0 625.0 60 Adj, 6,0 2446.07 941.35 723.44 61.20 1409.20 785,55 0.834 BS&W 6% 3-Apr 19:00 140.0 62.0 625.0 60 Adj. 6.0 2467.60 1033.49 724,84 67.19 1425.56 785.55 0.760 BS&W 6% 3-Apr 19:30 139.0 62.0 625.0 60 Adj. 6.0 2488.76 1015.33 726.22 66.01 1441.93 785.55 0.774 BS&W 6% 3-Apr 20:00 141.0 62.0 625.0 60 Adj. 5.0 2509.96 1017.98 727.36 55.01 1458.29 785.55 0.772 BS&W 5% 3-Apr 20:30 139.0 62.0 625.0 60 Adj. 5.0 2530.56 988.52 728.47 52.99 1474.66 785.55 0.795 BS&W 5% 3-Apr 21:00 140.0 62.0 625.0 60 Adj. 5.0 2549.60 914.21 729.49 49.01 1490.44 757.52 0,829 BS&W 5% 3-Apr 21:30 142.0 62.0 625.0 60 Adj. 5.0 2573.70 1156.41 730.78 61.99 1506.93 791.65 0.685 BS&W 5% 3-Apr 22:00 144.0 62.0 625.0 60 Adj. 5.0 2592.20 888.29 731.78 48.00 1523.43 791.65 0.891 BS&W 5% 3-Apr 22:30 143.0 62.0 625.0 60 Adj. 5.0 2615.91 1138.06 733,05 61.01 1539.92 791.65 0.696 BS&W 5% 3-Apr 23:00 143.0 62.0 635.0 60 Adj. 5.0 2636.12 970.17 734.13 52.01 1556.41 791.65 0.816 BS&W 5% 3-Apr 23:30 144.0 62.0 640.0 60 Adj. 5.0 2655.94 951.36 735.19 51.00 1572.91 791,65 0.832 BS&W 5% 4-Apr 00:00 145.0 62.0 640.0 60 Adj, 6.0 2677,30 1025.28 736.59 67.19 1589.40 791.65 0.772 BS&W 6% 4-Apr 00:30 144,0 62.0 640.0 60 Adj. 6.0 2695.76 885.98 737.79 57.60 1605.89 791.65 0.894 BS&W 6% Page 2.14 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates I Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate G©R Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 4-Apr 01:00 145.0 62.0 640.0 60 Adj. 6.0 2714.99 922.74 739.04 59.99 1622.38 791.65 0.858 BS&W 6% 4-Apr 01:30 145.0 62.0 640.0 60 Adj. 6.0 2736.52 1033.49 740.44 67.19 1638.88 791.65 0.766 BS&W 5% 4-Apr 02:00 146.0 62.0 640.0 60 Adj. 5.0 2758.88 1073.50 741.65 58.01 1655.37 791.65 0.737 BS&W 5% 4-Apr 02:30 145.0 62.0 645.0 60 Adj. 5.0 2779.87 1007.33 742.78 54.00 1672.05 800.91 0.795 BS&W 5% 4-Apr 03:00 144.0 62.0 645.0 60 Adj. 5.0 2802.41 1082.09 743.99 58.01 1688.74 800.91 0,740 BS&W 5% 4-Apr 03:30 145.0 62.0 645.0 60 Adj. 5,0 2823.01 988.52 745.09 52.99 1705.43 800.91 0,810 BS&W 5% 4-Apr 04:00 147.0 62.0 650.0 60 Adj. 5.0 2843.44 980.67 746.19 52.99 1722.02 796.58 0.812 BS&W 5% 4-Apr 04:30 147.0 62.0 650.0 60 Adj. 5.0 2864.42 1007.33 747.32 54.00 1738.71 800.91 0.795 BS&W 5% 4-Apr 05:00 146.0 62.0 650.0 60 Adj. 5.0 2885.80 1026,13 748.47 55.01 1755.39 800.91 0.781 BS&W 5% 4-Apr 05:30 147.0 62.0 650.0 60 Adj. 5.0 2906.79 1007.33 749.59 54.00 1772.08 800.91 0.795 BS&W 5% 4-Apr 06:00 148.0 62.0 650.0 60 Adj. 5.0 2926.45 943.81 750.65 51.00 1788.76 800.91 0.849 BS&W 5% 4-Apr 07:00 149.0 62.0 650.0 60 Adj. 5.0 2971.14 1072.69 753.05 57.50 1822.53 810.48 0.756 BS&W 5% 4-Apr 08:00 150.0 62.0 650.0 60 Adj. 3.0 3013.60 1018.93 754.39 32.10 1855.90 800.91 0.786 BS&W 3% 4-Apr 09:00 148.0 62.0 650.0 60 Adj. 3.0 3057.65 1057.10 755.77 33.30 1888.67 786.48 0.744 BS&W 3% 4-Apr 10:00 147.0 62.0 650.0 60 Adj. 5.0 3098.52 980.89 757.98 53.00 1921.78 794.42 0.810 BS&W 3%, oil gravity 38.9 at 60 4-Apr 11:00 150.0 62.0 650.0 60 Adj. 4.0 3145.25 1121.53 759.97 47.60 1955.20 802.29 0.715 BS&W 4% 4-Apr 12:00 149.0 62.0 650.0 60 Adj. 4.0 3184.91 951.88 761.65 40.40 1988.31 794.42 0.835 BS&W 4% 4-Apr 13:00 149.0 62.0 650.0 60 Adj. 4.0 3227.32 1017.93 763.45 43.20 2021.41 794.42 0.780 BS&W 4%, gravity 39.8 at 60 Page 2.15 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 WeLlhead Data [I Cumulative Volumes and Rates II Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate G©R Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 4-Apr 14:00 151.0 62.0 700.0 60 Adj. 4.0 3269.40 1009.84 765.25 43.20 2054.18 786.48 0,779 BS&W 4%, sampling from separator 4-Apr 15:00 151.0 62.0 700.0 60 Adj. 5.0 3315.64 1109.85 767.73 59.50 2087.28 794.42 0.716 BS&W 5% 4-Apr 16:00 149.0 62.0 700.0 60 Adj. 4.0 3357.27 999.15 769.49 42.40 2119.56 774.76 0.775 BS&W 4% 4-Apr 17:00 149.0 62.0 700.0 60 Adj. 4.0 3400.47 1036.70 771.33 44.00 2152.54 791.65 0.764 BS&W 4% 4-Apr 18:00 147.0 62.0 700.0 60 Adj. 4.0 3442.94 1019.27 773.14 43.60 2185.53 791.65 0.777 BS&W 4% 4-Apr 19:00 148.0 62.0 700.0 60 Adj. 4.0 3484.57 999.15 774.91 42.40 2218.96 802.29 0.803 BS&W 4% 4-Apr 20:00 149.0 62.0 700.0 60 Adj. 4.0 3544.96 1449.24 777.49 62.00 2252.39 802.29 0.554 BS&W 4% 4-Apr 21:00 149.0 62.0 700.0 60 Adj, 4.0 3576.01 745.20 778.81 31.60 2285.82 802.29 1,077 BS&W 4% 4-Apr 22:00 149.0 62.0 700.0 60 Adj. 4.0 3614.62 926.64 780,46 39.60 2318.30 779.58 0.841 BS&W 4% 4-Apr 23:00 150.0 62.0 700.0 60 Adj. 4.0 3658.63 1056.46 782.33 44.80 2350.78 779.58 0.738 BS&W 4% 5-Apr 00:00 150.0 62.0 710.0 60 Adj. 4.5 3703.25 1070.87 784.48 51.75 2383.17 777.40 0.726 BS&W 4.5% 5-Apr 01:00 150.0 62.0 710.0 60 Adj. 4.0 3744.52 990.36 786.23 42.00 2415.72 781.19 0.789 BS&W 4% 5-Apr 02:00 148.0 62.0 710.0 60 Adj. 4.0 3789.76 1085.69 788.17 46.40 2448.06 775.98 0.715 BS&W 4% 5-Apr 03:00 150.0 62.0 710.0 60 Adj. 4.0 3834.56 1075.25 790.07 45.60 2480.39 775.98 0,722 BS&W 4% 5-Apr 04:00 149.0 62.0 720.0 60 Adj. 4.0 3877.83 1038.43 791.92 44.40 2511.69 751.36 0.724 BS&W 4% 5-Apr 05:00 150.0 62.0 720.0 60 Adj. 3.5 3921,26 1042.48 793.52 38.50 2543.39 760.63 0.730 BS&W 4% 5-Apr 06:00 147.0 62.0 720.0 60 Adj. 4.0 3965.72 1067.04 795.42 45.60 2575,25 764.81 0,717 BS&W 4% 5-Apr 07:00 149,0 62.0 720.0 60 Adj. 4.0 4012.88 1131.84 797.42 48,00 2606.71 754.93 0.667 BS&W 4% Page 2.16 Final_Reports / Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Results Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E,S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data . Cumulative Volumes and Rates Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm, Rate Cumin. Rate Cumin. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 5-Apr 08:00 148.0 62.0 720.0 60 Adj. 3.0 4050.32 898~61 798.61 28.50 2638.31 758.29 0.844 BS&W 3% , , 5-Apr 09:00 149.0 62.0 750.0 60 Adj. 3.0 4094.80 1067.49 800.01 33.60 2669.90 758.29 0,710 BS&W 3%, shut-in well to run gauges & downhole shut-in tool , , 5-Apr 10:00 881.0 0.0 0 Adj. 10:25 open well, waiting on battery housing for d/h shut-in tool ,. 5-Apr 10:30 815.0 41 ~0 24 Adj. 2.0 4098.13 159.93 800.08 3.20 2669.90 5-Apr 11:00 561.0 48.0 34 Adj. 2.0 4124.82 1280.90 800.61 25.60 2669.90 5-Apr 11:30 442,0 54.0 38 Adj. 2.0 4137.33 600.35 800.86 12.00 2669.90 BS&W 2% , 5-Apr 12:00 415.0 58.0 500.0 42 Adj. 2.0 4154.15 807.69 801.19 16.00 2669.90 BS&W 2% 5-Apr 12:30 323.0 62.0 500.0 60 Adj. 1.0 4179.00 1192.57 801.44 11.80 2669.90 BS&W 1% __ 5-Apr 13:00 336.0 62.0 500,0 60 Adj. 5.5 4195.08 772.03 802.36 44.01 2669.90 BS&W 5.5% .,. 5-Apr 13:30 196.0 62.0 60 Adj. 4.0 4224.64 1418.84 803,61 60.00 2685.80 763.29 0.538 BS&W 4%, shut-in well to run gauges, d/h shut-in tool , 5-Apr 14:00 914.0 0 Adj. 4227.19 122.52 803.61 0.00 2685.80 5-Apr 14:30 24 Adj. 4.0 4227.19 0.00 803.61 0.00 2685.80 14:43 Open well for start of 24 hr max rate 5-Apr 15:00 36 Adj. 4,5 4241.41 682.38 804.26 31.49 2685.80 BS&W 4.5% 5-Apr. 15:30 427.0 36 Adj. 4.5 4261.32 955,71 805.18 44,11 2685.80 BS&W 4.5% 5-Apr 16:00 384.0 50.0 40 Adj. 3.0 4282.69 1025.53 805.84 31.80 2696.51 514.02 0.501 BS&W 3% 5-.AI3r 16:30 305.0 54.0 40 Adj. 4.0 4306.78 1156.44 806.83 47.19 2696.51 BS&W 4% 5-Apr 17:00 228.0 55.0 600.0 44 Adj. 2.0 4328.38 1036.83 807.27 21.20 2710,96 693.57 0.669 BS&W 2% 5-Apr 17:30 212.0 57.0 600.0 48 Adj. 4.5 4357.27 1386.65 808.64 65.71 2724.45 647.48 0.467 BS&W 4.5% Page 2.17 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3,826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data II Cumulative Volumes and Rates ]1 Date/Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate G©R Comments (dd~mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 5-Apr 18:00 169.0 59.0 600.0 60 Adj. 3.0 4379.12 1049.02 809.32 33.00 2739.97 744.97 0.710 BS&W 3% 5-Apr 18:30 150,0 60.0 610.0 60 Adj. 2.0 4404.42 1214.49 809.85 25.20 2756.87 811.26 0,668 BS&W 2% 5-Apr 19:00 160.0 61.0 620.0 60 Adj. 2.0 4425.30 1002.23 810.28 20.80 2772.79 764.33 0.763 BS&W 2% 5~Apr 19:30 158.0 62.0 640.0 60 Adj. 2.0 4450.19 1194.63 810.80 24.80 2788.88 772.12 0.646 BS&W 2% 5-Apr 20:00 158.0 62,0 660.0 60 Adj. 2.0 4475.08 1194.63 811.32 24.80 2805.13 779.92 0,653 BS&W 2% 5-Apr 20:30 165.0 62.0 680.0 60 Adj. 2.5 4497.85 1092.83 811.91 28.50 2821.28 775.54 0.710 BS&W 2.5% 5-Apr 21:00 163.0 62.0 700.0 60 Adj. 2.0 4517.91 963.04 812.33 20.00 2837.43 774.82 0.805 BS&W 2% 5-Apr 21:30 162.0 62.0 710.0 60 Adj. 2.0 4543.59 1232.60 812.86 25.60 2853.73 782.46 0.635 :BS&W 2% 5-Apr 22:00 162.0 62.0 730.0 60 Adj. 2.0 4565.49 1051.20 813.32 22.00 2869.86 774.16 0.736 BS&W 2% 5-Apr 22:30 162.0 62.0 760.0 60 Adj. 3.5 4587.22 1043.08 814.12 38.51 2885.87 768.54 0.737 BS&W 3.5% 5-Apr 23:00 162.0 63.0 760.0 60 Adj. 3.5 4612.51 1213.74 815.05 44.81 2901.63 756.65 0,623 BS&W 3.5% 5-Apr 23:30 162,0 63.0 775.0 60 Adj. 3.0 4636.33 1143.63 815.80 36.00 2917.83 777.59 0,680 BS&W 3% 6-Apr 00:00 162.0 63.0 790.0 60 Adj. 3.0 4659.19 1097,22 816.53 34.80 2933.77 764.85 0.697 BS&W 3% 6-Apr 00:30 162.0 63.0 795.0 60 Adj. 3.0 4681.43 1067.24 817.23 33.60 2949.97 777.59 0.729 BS&W 3% 6-Apr 01:00 161.0 63.0 800.0 60 Adj. 3.0 4706.04 1181.60 818.00 37.20 2966.15 777.01 0,658 BS&W 3% 6-Apr 01:30 160.0 63.0 800.0 60 Adj. 3.0 4729.47 1124.42 818.74 35.40 2982.34 777.01 0.691 BS&W 3% 6-Apr 02:00 160.0 63.0 800.0 60 Adj. 3.0 4751.54 1059.63 819.44 33.60 2998.53 777.01 0.733 BS&W 3% 6-Apr 02:30 159.0 63,0 800.0 60 Adj. 3.0 4776,17 1182.02 820.22 37.20 3014,72 777.31 0.658 BS&W 3% Page 2.18 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 I Wellhead Data I Cumulative Volumes and Rates Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumm. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 6-Apr 03:00 160.0 63.0 800.0 60 Adj. 3.0 4796.83 991.65 820.87 31.20 3030.84 773.70 0.780 BS&W 3% 6-Apr 03:30 159.0 63.0 805.0 60 Adj. 3.0 4817.88 1010.41 821.53 31.80 3046.96 773.70 0.766 BS&W 3% 6-Apr 04:00 160.0 63.0 810.0 60 Adj. 3.0 4842.72 1192.26 822.32 37.80 3063.08 773.70 0.649 BS&W 3% 6-Apr 04:30 159.0 63.0 810.0 60 Adj. 3.0 4867.74 1201.24 823.10 37.80 3079.20 773.70 0.644 BS&W 3% 6-Apr 05:00 161.0 63.0 810.0 60 Adj. 3.0 4888.80 1010.77 823.77 31.80 3095.39 777.31 0.769 BS&W 3% 6-Apr 05:30 159.0 65.0 820.0 60 Adj. 3.0 4911.83 1105.66 824.49 34.80 3111.58 777.01 0.703 BS&W 3% 6~Apr 06:00 159.0 65.0 820.0 60 Adj. 3.0 4933.69 1049.23 825.18 33.00 3127.77 777.31 0.741 BS&W 3% 6-Apr 06:30 158.0 65.0 820.0 60 Adj. 3.0 4959.11 1220.02 825.98 38.40 3143.95 776.28 0.636 BS&W 3% 6-Apr 07:00 160.0 65.0 820.0 60 Adj. 3.0 4979.76 991.30 826.63 31.20 3160.12 776.28 0.783 BS&W 3% 6-Apr 07:30 160.0 65.0 820.0 60 Adj. 3.0 5004.78 1200.81 827.42 37.80 3176.29 776.28 0.646 BS&W 3% 6-Apr 08:00 159.0 65.0 820.0 60 Adj. 4.0 5026.40 1037.67 828.33 44.01 3192.46 776.28 0.748 BS&W 4% 6-Apr 08:30 159.0 65.0 850.0 60 Adj. 3.0 5050.22 1143.63 829.08 36.00 3208.64 776.28 0.679 BS&W 3% 6-Apr 09:00 158.0 65.0 850.0 60 Adj. 3.0 5074.45 1162.84 829.85 36.60 3224.81 776.28 0.668 BS&W 3% 6-Apr 09:30 160.0 65.0 850.0 60 Adj. 3.0 5095.89 1029.27 830.52 32.40 3240.98 776.28 0.754 BS&W 3% 6-Apr 10:00 161.0 65.0 850.0 60 Adj. 3.0 5118.75 1097.22 831.25 34.80 3257.15 776.28 0.707 BS&W 3% 6-Apr 10:30 160.0 65.0 850.0 60 Adj. 3.0 5142.58 1143.63 832.00 36.00 3273.33 776.28 0.679 BS&W 3% 6-Apr 11:00 159.0 65.0 850.0 60 Adj. 3.0 5165.61 1105.66 832.72 34.80 3289.50 776.28 0.702 BS&W 3% 6-Apr 11:30 159.0 65.0 850.0 60 Adj. 3.0 5188.65 1105,66 833.45 34.80 3305.67 776.28 0.702 BS&W 3% Page 2.19 Final_Reports / Results Summary Halliburton Energy Services Well Test Results Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Stage: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Wellhead Data Cumulative Volumes and Rates Date / Time Tubing Tubing Casing Choke Choke Oil Oil Water Water Gas Gas Press Temp Press Size BS&W Cumm. Rate Cumm. Rate Cumin. Rate GOR Comments (dd-mmm hh:mm) (psig) (o F) (psig) (64ths) (%) (bbls) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) 6-Apr 12:00 159.0 65.0 850.0 60 Adj. 3.0 5212.87 1162.84 834.21 36.60 3321.84 776.28 0.668 BS&W 3% 6-Apr 12:30 160.0 65.0 850.0 60 Adj. 3.0 5234.72 1048.48 834.90 33.00 3337.93 772.25 0.737 BS&W 3% 6-Apr 13:00 160.0 65.0 850.0 60 Adj. 3.0 5257.75 1105.66 835.62 34.80 3354.02 772.25 0.698 BS&W 3%.13:07 Shut in well downhole. 6-Apr 13:30 Bleed tubing to zero. End surface test. 6-Apr 14:00 6-Apr 14:30 100.0 .525_~7..75- "' 0.00 857.62 1056.00 3354.02 Flush lines with 12 bbls methanol,10 bbls diesel, (water volumes.) Page 2.20 Final_Reports / Results Summary Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3,826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1,6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDE,~ (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 28-Mar 06:20 28-Mar 11:40 29-Mar 00:27 270.0 20 Adj. 0.00 0.00 0.00 0.00 0.00 0.00 29-Mar 00:30 60.0 20 Adj. 100.0 0.00 0.00 0.00 0.00 Q00 0.00 0.00 29-Mar 00:45 45.0 20 Adj. 100.0 5.50 0.00 0.00 0.00 5.50 528.00 0.00 29~Mar 01:00 37.0 20 Adj, 100.0 5.50 0.00 0.00 0.00 5.50 528.00 0.00 29-Mar 01:15 36.0 20 Adj. 100.0 2.50 0.00 0.00 0.00 2.50 240.00 0.00 29-Mar 01:30 12.0 22 Adj. 100.0 2.28 Q00 0.00 0.00 2.28 218.69 0.00 29-Mar 01:55 10.0 64 Adj, 100.0 3.33 0.00 0.00 0.00 3.33 191.98 0.00 29-Mar 02:00 5.0 64 Adj. 100.0 0.56 0.00 0.00 0.00 0.56 160.13 0.00 _ 29-Mar 02:30 5.0 64 Adj. 100.0 1.30 0.00 0.00 0.00 1.30 62.30 0.00 29-Mar 03:00 5.0 64 Adj. 100.0 1.84 0.00 0.00 0.00 1.84 88.13 0.00 29-Mar 03:30 5.0 64 Adj. 100.0 2.60 0.00 0.00 0.00 2.60 124.80 0.00 29-Mar 04:00 5.0 64 Adj. 100.0 2.60 0.00 0.00 0.00 2.60 124.80 0.00 29-Mar 04:30 5.0 64 Adj. 100.0 1.93 0.00 0.00 0.00 1.93 92.59 0.00 29-Mar 05:00 0.0 64 Adj. 100.0 1.93 0.00 0.00 0.00 1.93 92.59 0.00 29-Mar 05:30 0.0 64 Adj. 100.0 1.93 000 0.00 0.00 1.93 92.59 0,00 29-Mar 06:00 0.0 64 Adj. 100.0 1.93 0.00 0.00 0.00 1.93 92.59 0.00 Page 3.1 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott VVeimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" VVC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ...... ORIFICE GAS Gas OIL Oil Oil Vvater Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr, GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc, Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (t~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 29-Mar 07:00 0.0 64 Adj, 100.0 2.62 0.00 0,00 0.00 2.62 62.86 0.00 29-Mar 08:00 0.0 64 Adj. 100.0 2,00 0,00 0.00 0.00 2.00 48.00 0.00 29-Mar 09:00 0.0 64 Adj. 100.0 1.67 0.00 0.00 0,00 1.67 40,01 0.00 29-Mar 10:00 0,0 64 Adj. 100.0 0.00 0.00 0.00 0,00 0.00 0.00 0.00 29-Mar 11:00 0.0 64 Adj. 100.0 0.25 0,00 0.00 0,00 0.25 6.00 0.00 29-Mar 12:00 0.0 64Adj. 100.0 0.25 0.00 0.00 0.00 0.25 6.00 0.00 29-Mar 13:00 0.0 64 Adj. 100.0 0.25 0.00 0.00 0.00 0.25 6.00 0.00 29-Mar 13:30 0.0 24 Adj. 100.0 0.25 0.00 0.00 0.00 0.25 12.00 0,00 29-Mar 14:00 0.0 24 Adj. 100.0 0.50 0.00 0.00 0.00 0.50 24.00 0.00 29-Mar 15:00 0.0 128 Adj. 100.0 1.00 0.00 0.00 0.00 1.00 24.00 0.00 ,,, 29-Mar 16:00 0.0 128 Adj, 100.0 1.00 0.00 0.00 0.00 1.00 24.00 0.00 29-Mar 17:00 0.0 128 Adj. 100,0 1.00 0.00 0.00 0.00 1.00 24.00 0.00 29-Mar 18:00 0.0 128 Adj. 100.0 1.00 0.00 0.00 0.00 1.00 24.00 0.00 29-Mar 19:00 0.0 128 Adj. 100.0 1.00 0.00 0.00 0.00 1.00 24.00 0.00 29-Mar 20:00 0.0 128 Adj. 100.0 1.00 0.00 0.00 0.00 1.00 24.00 0.00 29-Mar 21:00 0.0 128 Adj. 100.0 0.75 0.00 0.00 0.00 0.75 18.00 0,00 29-Mar 22:00 0.0 128 Adj 100.0 0.50 0.00 0.00 0.00 0.50 12.00 0.00 29-Mar 23:00 0.0 128 Adj 100.0 0.50 0.00 0.00 0.00 0.50 12.00 0.00 Page 3.2 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr, GRAV SIZE GRAV Static Diff Temp TEMP Inc, Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) ((~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 30-Mar 00:00 0.0 128 Adj. 100.0 0.25 0.00 0.00 0.00 0.25 6.00 0.00 30-Mar 01:00 0.0 128 Adj. 100,0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 02:00 0.0 128 Adj. 100.0 0.50 0.00 0.00 0.00 0.50 12.00 0.00 30-Mar 03:00 0.0 128 Adj. 100.0 0.50 0.00 0.00 0.00 0.50 12.00 0.00 , 30-Mar 04:00 0.0 128 Adj,! 100.0 0.50 0.00 0.00 0.00 0.50 12.00 0.00 30~Mar 05:00 0.0 128 Adj.' 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 06:00 0.0 128 Adj., 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 07:00 0.0 128 Adj. 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 08:00 0.0 128 Adj, 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 09:00 0.0 128 Adj. 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30oMar 10:00 0.0 128 Adj. 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 11:00 0.0 128 Adj. 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 12:00 128 Adj. 100.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 30-Mar 13:00 30-Mar 14:00 30-Mar 15:00 30-Mar 16:00 30-Mar 17:00 Page 3.3 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time Wellhead Data Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) ("F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) i III i i I II i i i i i I 30-Mar 18:00 30-Mar 19:00 30-Mar 20:00 30-Mar 21:00 30-Mar 22:00 30-Mar 22:30 30-Mar 23:00 31-Mar 00:00 31-Mar 01:00 0.0 128 Adj. 100.0 16.20 0.00 0.00 0.00 16.20 388.80 0.00 31-Mar 02:00 0.0 128 Adj. 100.0 16.20 0.00 0.00 0.00 16.20 388.80 0.00 31-Mar 03:00 0.0 128 Adj. 100.0 16.20 0.00 0.00 0.00 16.20 388.80 0.00 31-Mar 04:00 0.0 128 Adj. 100.0 16.20 0.00 0.00 0.00 16.20 388.80 0.00 31-Mar 04:30 0.0 128 Adj. 100.0 16.20 0.00 0.00 0.00 16.20 777.60 0.00 31-Mar 05:00 0.0 128 Adj. 100.0 16.20 0.00 0.00 0.00 16.20 777.60 0.00 31-Mar 05:30 0.0 ,128 Adj. 100.0 16.20 0.00 0.00 0.00 16.20 777.60 0.(30 31-Mar 06:00 385.0 100.0 16.20 0.00 0.00 0.00 16.20 777.60 0.00 31-Mar 06:15 34 Adj. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 31-Mar 06:30 10.0 34 Adj. 100.0 3.00 0.00 0.00 0.00 3.00 144.00 0.00 Page 3.4 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC, Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cool<son Storage Tank Coeff: 1.6667 Date/TimeII Wellhead DataII Separator Readings Tubing Choke Choke Tank Oil Inc, OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc, Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20)! (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 31-Mar 07:00 150,0 32 Adj. 100.0 16.00 0.00 0.00 0.00 16.00 768.00 0.00 31-Mar 07:30 110.0 32 Adj. 100.0 5.00 Q00 0.00 0.00 5.00 240.00 0.00 , 31-Mar 08:00 70.0 32 Adj. 100.0 11,25 0.00 0.00 0,00 11.25 540.00 0.00 31-Mar 08:30 80.0 32 Adj. 100.0 11,75 0.00 0.00 0,00 11.75 564.00 0.00 31-Mar 09:00 90.0 32 Adj. 60.0 17.00 6.80 6,94 333.25 10.20 489.60 0.00 31-Mar 09:30 100.0 32 Adj. 60.0 8,00 3.20 3.27 156.83 4.80 230.40 0.00 26,000 31-Mar 10:00 90.0 32 Adj. 60.0 13.00 5.20 5.31 254.84 7.80 374.40 0.00 31-Mar 10:30 100.0 32 Adj. 60.0 17.00 6.80 6.94 333.25 10.20 489.60 0.00 26,000 31-Mar 11:00 95.0 32 Adj. 60.0 14.00 5.60 5.72 274.44 8.40 403.20 0.00 31 31-Mar 11:30 95.0 32 Adj. 60.0 13.13 525 5.36 257.29 7.88 378.00 0.00 28,000 , 31-Mar 12:00 115.0 30Adj. 60.0 17.88 7.15 7.30 350.41 10.73 514.80 0.00 30,000 31-Mar 12:30 120.0 30 Adj. 60.0 10.00 4.00 4.08 196.03 6.00 288.00 0.00 30,000 31-Mar 13:00 115.0 30 Adj. 60.0 10.00 4.00 4.08 196.03 6.00 288.00 0.00 31-Mar 13:30 120.0 30 Adj. 50.0 20.00 10.00 10.21 490.08 10.00 480.00 0.00 31-Mar 14:00 120.0 30 Adj. 50.0 20.00 10.00 10.21 490.08 10.00 480.00 0.00 29,500 31-Mar 14:30 120.0 30 Adj. 50.0 13.00 6.50 6.64 318.55 6.50 312.00 0.00 31-Mar 15:00 120.0 30 Adj. 55.0 16.00 7.20 7.35 352.86 8.80 422.40 0.00 29,000 31-Mar 15:30 120.0 30 Adj, 55.0 11.00 4.95 5.05 242.59 6.05 290.40 0.00 Page 3.5 Final_Reports/Separator Reading Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 .... Date/TimelY' ,,,iL ..................................... Wellhead Data II .................................................... Separator Readings , Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAY Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 31-Mar 16:00 110.0 30 Adj. 55.0 15.00 6.75 6.89 330.80 8.25 396.00 0.00 28,500 31-Mar 16:30 110.0 30 Adj. 55.0 15.00 6,75 6.89 330.80 8.25 396.00 0.00 31-Mar 17:00 110.0 30 Adj. 50.0 12.00 6.00 6.13 294.05 6.00 288.00 0.00 29,000 31-Mar 17:30 110.0 30 Adj. 50.0 18.00 9.00 9.19 441.07 9.00 432,00 0.00 31-Mar 18:00 150.0 30 Adj, 60,0 10.00 4.00 4.08 196.03 6.00 288.00 0.00 29,000 31-Mar 18:30 200.0 30 Adj. 40.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 31-Mar 19:00 200.0 30 Adj. 40.0 8.67 5.20 5.31 254.85 3.47 16641 0.00 29,000 31-Mar 19:30 130.0 34 Adj. 35.0 16.48 10.71 10.93 524.85 5.77 276.80 0.00 31-Mar 20:00 135.0 34 Adj. 30.0 12.86 9.00 9.19 441.07 3.86 185.14 0.00 28,' 31-Mar 20:30 185.0 32 Adj. 30.0 12.00 8.40 8.58 411.67 3.60 172.80 0.00 31-Mar 21:00 175.0 32Adj. 30.0 13.00 9,10 9.29 445.97 3.90 187.20 0.00 28,000 31-Mar 21:30 80.0 32 Adj. 15.0 16.00 13.60 13.89 666.51 2.40 115.20 0.00 31-Mar 22:00 180.0 32 Adj. 28.0 7.30 5.26 5.37 257.59 2.04 98.11 0.00 28,000 ,, 31-Mar 22:30 210.0 32 Adj. 25.0 15.20 11.40 11.64 558.69 3.80 182.40 0.00 31-Mar 23:00 150.0 32 Adj. 15.0 19.00 16.15 16.49 791.48 2.85 136.80 0.00 28,000 31-Mar 23:30 80.0 32 Adj. 30.0 16.39 11.47 11.71 562.10 4.92 235.94 0.00 1-Apr 00:00 150.0 34 Adj. 25.0 14.62 10.96 39.80 11.29 541.92 3.65 17538 0.00 28,000 1-Apr 00:30 180.0 34 Adj. 20.0 17.10 13.68 13.97 670.43 3.42 164.16 0.00 Page 3~6 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No,1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3,826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time Wellhead Data II Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR ~CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 1-Apr 01:00 150.0 34 Adj. 26,0 9.80 7,25 7.40 355.41 2.55 122.30 0.00 28,000 1-Apr 01:30 180,0 34 Adj. 20.0 18.70 14.96 15,27 733.16 3.74 179.52 0.00 1-Apr 02:00 165.0 34 Adj. 23.0 19,00 14.63 14.94 716.99 4.37 209.76 0.00 31,000 1-Apr 02:30 150.0 34 Adj. 15,0 13.20 11,22 11.46 549.87 1.98 95.04 0.00 1-Apr 03:00 150.0 34 Adj. 15.0 15.20 12.92 13.19 633.18 2.28 109.44 0.00 1-Apr 03:30 150.0 34 Adj. 18.0 29.50 24.19 24,70 1185.50 5.31 254.88 0.00 1-Apr 04:00 160.0 34 Adj. 22.0 18.60 14.51 14.81 711.01 4.09 196.42 0.00 30,500 L 1-Apr 04:30 160.0 34 Adj, 22.0 14.50 11.31 11.55 554.28 3.19 153.12 0.00 1-Apr 05:00 160.0 34 Adj. 13.0 14.50 12.62 40.10 12.99 623.69 1.89 90.48 0.00 1-Apr 05:30 165.0 34 Adj. 14.0 13.95 12.00 12.25 587.95 1.95 93.74 0.00 1-Apr 06:00 165.0 34 Adj. 14.0 17,05 14.66 14,97 718.60 2.39 114.58 Q00 30,500 1-Apr 06:30 165.0 34 Adj. 15.0 15.50 13.18 13.45 645.68 2.33 111.60 0.00 1-Apr 07:00 34 Adj. 14.0 15.50 13.33 13.61 653.28 2.17 104.16 0.00 1-Apr 07:30 34 Adj. 16.0 18.97 15.93 16.27 780.81 3.03 145.67 0.00 1-Apr 08:00 34 Adj. 15.0 18.97 16.12 16.46 790.10 2.85 136.56 0.00 1-Apr 08:30 201.0 34 Adj. 17.0 18.97 15.74 16.07 771.51 3.22 154.77 0.00 1-Apr 09:00 226.0 34 Adj. 20.0 0.00 0.00 38.30 0.810 0.810 0.00 0.00 0.00 0.00 0.00 1-Apr 09:30 260.0 34 Adj. 22.0 6.67 5.20 110.0 24.0 60.0 61.0 5.20 249.64 1.47 70.44 5.89 282.77 1.133 Page 3.7 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scoff Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time Wellhead Data Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~OF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbl$) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 1-Apr 10:00 403.0 34 Adj. 22.0 7.50 5.85 110.0 56.0 90.0 104.0 5.76 276.48 1.65 79.20 8.74 419.60 1,518 30,000 .... 1-Apr 10:30 475.0 34 Adj. 30.0 21.67 15.17 120.0 60.0 100,0 112.0 14.89 714.86 6.50 312.05 9.37 449.72 0.629 1-Apr 11:00 273.0 34 Adj. 30.0 14.17 9.92 110,0 28.0 100.0 118.0 9.72 466.45 4.25 204.05 6.11 293.40 0.629 30,000 .... 1-Apr 11:30 213.0 40Pos. 16.0 10.83 9.10 110.0 74.0 100.0 114.0 8.93 428,41 1.73 83,17 10.10 484.63 1.131 1-Apr 12:00 143.0 40Pos. 8.0 20.83 19.16 0.810 0,810 110.0 24.0 100.0 110.0 18.83 903,76 1.67 79.99 8.89 426.64 0.472 25,000 1-Apr 12:30 148.0 40 Pos. 80 18,75 17.25 110.0 24.0 100.0 103.0 16.99 815,54 1.50 72.00 8.89 426.64 0.523 1-Apr 13:00 188.0 40Pos. 20.0 11,25 9.00 110.0 28.0 100.0 104.0 8.86 425.35 2.25 108.00 9.15 438.99 1.032 25,000 l-Apr 13:30 169.0 40 Pos, 12.0 21.67 19.07 100,0 28.0 102,0 106.0 18.76 900.60 2.60 124.82 9.15 438.99 0.487 1-Apr 14:00 178.0 40 Pos 10,0 43.33 39.00 100.0 28.0 102.0 106.0 38.37 11841,72 4.33 207.98 9.15 438.99 0.238 ,', l-Apr 14:30 174.0 40 Pos. 6.0 17.50 16.45 100.0 32.0 102.0 106.0 16.19 776.89 1.05 50.40 9.78 469.40 0.604 1-Apr 15:00 185.0 40 Pos 9.0 17.50 15.93 100.0 32.0 102.0 106.0 15.67 752.09 1.58 75.60 9.78 469.40 0.624 29,000 l-Apr 15:30 172.0 40 Pos. 18.0 18.33 15.03 3830 100.0 28.0 102.0 106.0 14.68 704.88 3,30 15837 9.15 438.99 0.623 1-Apr 16:00 166.0 40Pos. 22.0 14.17 11.05 0.810 0,810 100.0 28.0 102.0 106.0 10.87 521.98 3,12 149.64 9.15 438.99 0.841 .... l-Apr 16:30 195.0 40 Pos. 14.0 15.83 13.61 100.0 26.0 102.0 106.0 13.39 642.94 2.22 106.38 8.80 422.17 0.657 1-Apr 17:00 177,0 40Pos. 20.0 17.08 13.66 110.0 26.0 102.0 106.0 13.44 645.31 3,42 163.97 9.23 443,24 0,687 30,000 1-Apr 17:30 178,0 40 Pos. 15.0 17,92 15.23 110.0 26.0 101.0 106.0 14.99 719.36 2.69 129.02 9.24 443.67 0,617 l-Apr 18:00 197.0 40Pos. 16.0 1583 13.30 110.0 26.0 101.0 106.0 13,08 627.99 2.53 121.57 9.24 443.67 0,706 l-Apr 18:30 169.0 40Pos. 6.0 18.34 17.24 110.0 36.0 105.0 106.0 16.96 814.18 1.10 52.82 11.09 532.28 0.654 Page 3.8 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC, Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3,826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1,6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas ~ (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc, Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 1-Apr 19:00 206.0 40 Pos. 60 20.83 19.58 110.0 36.0 105.0 110.0 19.24 923.40 1.25 59.99 10.84 520.32 0.563 28,000 1-Apr 19:30 202.0 40Pos. 20.0 21,67 17.34 110.0 36.0 105.0 110.0 17.03 817.57 4.33 208.03 10.84 520.32 0.636 1-Apr 20:00 191.0 40 Pos. 21.0 20.00 15.80 0.810 0.810 110.0 36.0 105.0 110.0 15.52 745.13 4.20 201.60 10.84 520.32 0.698 1-Apr 20:30 192.0 40 Pos. 20.0 20.83 16.66 110.0 39.0 105.0 110.0 16.37 785.87 4.17 199.97 11.28 541.65 0.689 1-Apr 21:00 195.0 40 Pos. 20.0 17.08 13.66 110.0 40.0 105.0 110.0 13.42 644,39 3.42 163.97 11.43 548.58 0,851 26,500 1-Apr 21:30 205.0 40 Pos. 20.0 20.00 16.00 38,20 12Q0 82.0 105.0 110.0 15.60 748.80 4.00 192.00 10.91 523.90 0.700 l-Apr 22:00 207.0 40 Pos. 20.0 17.92 14.34 120.0 85.0 105.0 110,0 14.09 676.09 3.58 172,03 11.11 533.48 0.789 l-Apr 22:30 207.0 40 Pos. 18.0 19.17 15.72 120.0 85.0 105.0 110.0 15.44 741.33 3.45 165.63 11.11 533.48 0.720 ,, 1-Apr 23:00 200.0 40 Pos. 18.0 20.00 16.40 120.0 86.0 105.0 110.0 16.11 773.42 3.60 172.80 11.18 536.64 0.694 1-Apr 23:30 206.0 40Pos. 16.0 19.58 16.45 120,0 86.0 105.0 110.0 16.16 775.65 3.13 150.37 11.18 536.64 0.692 2-Apr 00:00 204.0 40 Pos. 16.0 15.00 12.60 0.810 0.810 120.0 88.0 105.0 112.0 12.37 593.79 2.40 115.20 11.31 542,91 0,914 26,000 2-Apr 00:30 208,0 40 Pos. 15.0 25.00 21.25 120.0 88.0 105.0 112.0 20.86 1001.44 3.75 180.00 11.31 542.91 0,542 2-Apr 01:00 207.0 40 Pos. 15.0 13.33 11.33 120.0 88.0 '105,0 112,0 11.12 533.97 2.00 95.98 11.31 542.91 1.017 2-Apr 01:30 210.0 40 Pos. 12.0 25.83 22.73 120.0 88.0 105.0 112.0 22.32 1071.20 3.10 148.78 11.31 542.91 0.507 2-Apr 02:00 209.0 40 Pos. 9.0 17.92 16.31 120.0 88.0 105.0: 112.0 16.01 768.50 1.61 77.41 11.31 542.91 0.706 26,000 2-Apr 02:30 203.0 40 Pos. 15.0 21.25 18.06 120.0 88.0 105.0! 112.0 17.73 851.22 3.19 153.00 11.31 542.91 0.638 2-Apr 03:00 201.0 40 Pos. 13.0 15.42 13.42 120.0 89.0 105.0 112.0 13.17 632.22 2,00 96.22 11.38 546.01 0.864 2-Apr 03:30 202.0 40 Pos. 14.0 22.08 18.99 120.0 92.0 105.0 112.0 18.64 894.87 3.09 148.38 11.57 555.23 0.620 Page 3.9 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scoff Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time . Wellhead Data I , II I1' ,,, ,,,,,, , , ,,, , ,~..,.~,,,,, , , ...... ,,,.,,,,,,, ,,, ....... , ....................... ,, ,,, , Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 2-Apr 04:00 204.0 40 Pos. 13.0 17.08 14.86 0.810 0.810 120,0 89.0 105.0 112.0 14.59 700.28 2.22 106.58 11.38 546.01 0.780 2-Apr 04:30 208.0 40 Pos. 13.0 18.33 15.95 120.0 89.0 105.0 112.0 15.66 751.53 2.38 114,38 11.38 546.01 0.727 2-Apr 05:00 208.0 40 Pos. 13.0 20.42 17.77 120.0 92.0 105.0 112.0 17.44 837.22 2.65 127.42 11.57 555.23 0.663 2-Apr 05:30 208.0 40 Pos. 16.0 22.08 18.55 120.0 92.0 '105.0 112.0 18.21 874.06 3.53 169.57 11.57 555.23 0.635 2-Apr 06:00 202.0 40 Pos. 13.0 16.67 14.50 37.90 120.0 92.0 105.0 112.0 14.13 678.04 2.17 104.02 11.57 555.23 0.819 2-Apr 06:30 202.0 40 Pos. 16.0 20.00 16.80 120.0 92.0 105.0 112.0 16.49 791.72 3,20 153,60 11.61 557.18 0,704 2-Apr 07:00 214.0 40 Pos. 14,0 19,58 16.84 120.0 92.0 105.0 112.0 16.53 793.55 2.74 131.58 11.61 557.18 0.702 2-Apr 07:30 203.0 40 Pos. 16.0 15.42 12.95 120.0 93.0 105.0 112.0 12.72 610.42 2.47 118.43 11.67 560.23 0.918 2-Apr 08:00 213.0 40 Pos. 14.0 20.83 17.91 0.804 0.804 120,0 93.0 105.0 112.0 17.59 844.21 2.92 139.98 11.67 560.23 0.664 2-Apr 08:30 209.0 40 Pos. 15.0 21.25 18.06 120,0 93,0 105.0 112.0 17.73 851.22 3.19 153.00 11.67 560.23 0.658 26,000 2-Apr 09:00 214.0 40 Pos. 14.0 16.25 13.98 120.0 93,0 105.0 112.0 13.72 658.59 2,28 109.20 11.67 560.23 0.851 2-Apr 09:30 207.0 40 Pos. 17.0 20.00 16.60 120.0 94,0 105.0 112.0 16.30 782.30 3.40 163.20 11.73 563.27 0.720 2-Apr 10:00 215.0 40Pos. 13.0 18.33 15.95 120.0 94.0 105.0 112.0 15.66 751.53 2.38 114.38 11.73 563.27 0.749 2-Apr 10:30 215.0 40 Pos. 16.0 20.00 16.80 39.70 120.0 96.0 105.0: 112.0 16.36 785.43 3.20 153.60 11.86 569.29 0.725 2-Apr 11:00 204.0 40Pos, 12.0 20.00 17.60 120.0 96.0 105,0 112.0 17.28 829.42 2.40 115.20 11.86 569.29 0.686 29,000 2-Apr 11:30 213.0 40Pos. 12.0 17.92 15.77 120.0 95.0 105.0 112.0 15.48 743.16 2.15 103.22 11.80 566.29 0.762 2-Apr 12:00 209.0 40Pos, 10.0 20.63 18.75 0.808 0.808 120.0 92.0 105.0 112.0 18,41 883.48 2.08 99.98 11.61 557.18 0.631 2-Apr 12:30 210.0 40Pos. 12.0 20.42 17.97 40.30 120.0 91.0 105.0 112.0 17.50 840.11 2.45 117.62 11.52 552.82 0.658 Page 3.10 Final_Reports / Separator Reading Customer: ARCO Alaska, INC, Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time Wellhead Data il Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas ,i) (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp !TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~T)OF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscfld) (mscf/bbl) (ppm) 2-Apr 13:00 209.0 40Pos. 10.0 17.08 15.37 120.0 91.0 105,0 112.0 15,09 724.43 1.71 81.98 11.52 552.82 0.763 2-Apr 13:30 2140 40Pos. 14.0 18.75 16.13 120.0 94.0 105.0 112.0 15.83 759,91 2.63 126.00 11.71 561.95 0,739 2-Apr 14:00 210.0 40Pos. 8.0 17.92 16.49 120.0 90.0 105,0 112.0 16.19 776.94 1.43 68.81 11.45 549.74 0.708 2-Apr 14:30 215.0 40Pos. 6.0 19.58 18.41 120.0 90.0 105.0 112.0 18.07 867.37 1.17 56.39 11.45 549.74 0.634 2-Apr 15:00 213.0 40Pos. 8.0 20.42 18.79 120.0 96.0 105.0 113.0 18.44 885.02 1.63 78.41 11,81 566.64 0,640 2-Apr 15:30 211.0 40 Pos. 7.0 19.17 17.83 120.0 96.0 105.0 113.0 17.50 839.87 1.34 64.41 11.81 566,64 0.675 2-Apr 16:00 219.0 40Pos, 18.0 18.33 15.03 0.810 0.810 120.0 96.0 105.0 113.0 14.75 708,09 3.30 158.37 11.81 566.64 0.800 26,000 2-Apr 16:30 223.0 40Pos. 8.0 20.00 18.40 120.0 96.0 105.0 113.0 18.06 866.82 1.60 76.80 11.81 566.64 0.654 2-Apr 17:00 219.0 40Pos. 80 20.00 18.40 120.0 95.0 105,0 113.0 18.06 866.82 1.60 76.80 11.76 564.31 0.651 2-Apr 17:30 218.0 40 Pos. 7,0 20.42 18.99 39.80 120,0 96,0 105.0 113.0 18.49 887.39 1.43 68.61 11.81 566.64 0.639 2-Apr 18:00 216.0 40Pos. 10.0 19,58 17.62 120.0 92.0 105.0 113.0 17.30 830.17 1.96 93.98 11.57 555.23 0.669 2-Apr 18:30 220.0 40Pos. 8.0 17.50 16.10 120.0 92.0 105.0 113.0 15.80 758.46 1.40 67.20 11.57 555.23 0.732 2-Apr 19:00 223.0 40Pos, 10.0 19.17 17.25 135.0 84.0 105.0 113,0 16.93 812.78 1.92 92.02 11.80 566.49 0,697 2-Apr 19:30 224.0 40 Pos. 10.0 21.25 19.13 135.0 83.0 105,0 113,0 18.77 900.97 2.13 102.00 11.73 563.08 0.625 2-Apr 20:00 222.0 40Pos. 10.0 20,42 18,38 0,800 0.800 140.0 87.0 105.0 112.0 18.04 866.09 2.04 98.02 12.24 587.44 0.678 26,000 2-Apr 20:30 220,0 40Pos. 8.0 16.67 15,34 140.0 87,0 105.0 112.0' 15.06 722.75 1.33 64.01 12.24 587.44 0.813 2-Apr 21:00 222.0 40Pos, 10.0 20,42 18.38 140.0 87.0 105.0 112.0 18.04 866.09 2.04 98.02 12.24 587.44 0.678 2-Apr 21:30 219.0 40 Pos. 9.0 15.00 13.65 140.0 87.0 105.0 112.0 13.40 643.28 1,35 64.80 12.24 587.44 0.913 Page 3.11 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas ~ (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=I)i (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) ,, 2-Apr 22:00 224.0 40 Pos. 9.0 22.50 20.48 140,0 87.0 105.0 112.0 20.10 964.91 2.03 97.20 12.24 587.44 0.609 , , 2-Apr 22:30 217.0 40 Pos. 9.0 20.00 18.20 40.10 140.0 88,0 105.0 112.0 17,73 850.89 1.80 86.40 12.31 590.84 0.694 ,, 2-Apr 23:00 217.0 40Pos. 9.0 18.33 16.68 140,0 88.0 105.0 112,0 16.38 786.08 1,65 79.19 12.31 590.84 0.752 2-Apr 23:30 223.0 40 Pos, 9.0 20.42 18.58 135.0 95.0 105.0 112.0 18.24 875.71 1,84 88.21 12.56 602.77 0,688 25,500 3-Apr 00:00 216.0 40 Pos, 9.0 17,92 16.31 0.810 0.810 135.0 95.0 105.0 112,0 16.01 768.50 1.61 77.41 12,56 602.77 0.784 3-Apr 00:30 224.0 40 Pos, 9.0 18.75 17,06 130.0 98.0 1050 112.0 16.75 804.09 1.69 81.00 12.51 600.62 0.747 3-Apr 01:00 216.0 40 Pos. 90 21.67 19.72 130.0 98,0 105.0 112.0 19.36 929.32 1.95 93,61 12.51 600,62 0646 3-Apr 01:30 218.0 40 Pos, 10,0 18.33 16.50 130.0 99.0 105,0 112.01 16.20 777.44 1.83 87.98 12.58 603.70 0.777 3-Apr 02:00 220,0 40 Pos. 10.0 20.42 18.38 130.0 100.0 105.0 112.0 18.04 866.09 2,04 98.02 12.64 606.77 0.701 ,~ 3-Apr 02:30 221.0 40 Pos. 10.0 2250 20.25 130.0 100.0 105.0 112.0 19.88 954,31 2.25 108.00 12.64 606.77 0.636 3-Apr 03:00 221,0 40 Pos. 9.0 15.00 13.65 130.0 100.0 105.0 112.0 13.40 643.28 1,35 64.80 12.64 606.77 0.943 3-Apr 03:30 224,0 40 Pos. 9.0 20.00 18.20 130.0 100.0 105.0 112.0 17.87 857.70 1.80 86.40 12.64 606.77 0.707 ,,, 3-Apr 04:00 224.0 40 Pos. 9.0 18,75 17.06 0.810 0,810 130.0 100.0 1050 1120 16.75 804.09 1,69 81,00 12.64 606.77 0,755 26,000 3-Apr 04:30 221.0 40 Pos. 9.0 21.25 19.34 130,0 100.0 105.0 1120 18.99 911.31 1.91 91.80 12.64 606,77 0.666 3-Apr 05:00 226.0 40 Pos. 8.0 18.33 16.86 130.0 100,0 105,0 112.0 16.56 79472 1.47 70,39 12.64 606.77 0.764 3-Apr 05:30 2240 40 Pos. 8.0 18.33 16,86 38.20 130.0 100.0 105.0 112.0 16.43 788.41 1.47 70.39 12.64 606.77 0.770 3-Apr 06:00 226.0 40 Pos. 80 19.58 1801 135.0 100.0 105.0 1120 17.69 848,92 1.57 75,19 12.89 618.58 0.729 3-Apr 06:30 217.0 40 Pos. 8.0 22.50 20,70 135.0 100.0 1050 112.0 20,32 975.52 1.80 86.40 12.89 618.58 0.634 Page 3.12 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc, OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=I)i (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) , , ~ 3-Apr 07:00 215.0 52 Adj. 6.0 18.33 17.23 85.0 90.0 105.0 112.0 16.92 812,00 1.10 52.79 15.18 728,77 0.898 ......... 3-Apr 07:30 163.0 52 Adj. 7.0 25.00 23.25 90.0 116.0 100.0 106.0 22.88 1098.03 1.75 84.00 17.86 857.17 0.781 3-Apr 08:00 142.0 60Adj. 6.0 24.17 22.72 39.20 0,810 0.810 90.0 1120 100,0 106,0 22.20 1065.47 1.45 69.61 17.54 842.00 0,790 26,000 3-Apr 08:30 140.0 60 Adj. 8.0 21.67 19.94 90.0 84.0 100.0 110.0 19.59 940.20 1.73 83.21 15.16 727.70 0.774 3-Apr 09:00 137.0 60 Adj. 8.0 22,50 20.70 90.0 86.0 100.0 110.0 20.34 976.21 1.80 86.40 15.34 736.42 0.754 3-^pr 09:30 136.0 60Adj. 8.0 22.92 21.09 90.0 96.0 100.0 110.0 20.72 994.43 1.83 88.01 16.22 778.62 0.783 3-Apr 10:00 133.0 60Adj. 6.0 23.33 21.93 38,90 90.0 101.0 105.0 112.0 21.36 1025.28 1.40 67.19 16.57 795.19 0.776 3-Apr 10:30 134.0 60 Adj. 5.0 19.58 18.60 90.0 101.0 105.0 112.0 18.26 876.60 0.98 46.99 16.57 795.19 0.907 3-Apr 11:00 141.0 60Adj. 6.0 22.50 21.15 85.0 115.0 i107.0 112.0 20.77 996,72 1.35 64.80 17.16 823.87 0.827 3-Apr 11:30 139.0 60Adj. 6.0 23.75 22.33 90.0 96.0 '107.0 112.0 21.92 1052.10 1.43 68.40 16.12 773.53 0.735 3-Apr 12:00 140,0 60Adj. 5.0 21.67 20.59 39.50 0.812 0.812 90.0 92.0 107.0 112.0 20.05 962.46 1.08 52.01 15.66 751.62 0.781 25,500 3-Apr 12:30 142.0 60Adj. 7.0 21.25 19.76 90.0 91.0 107.0 112.0 19.40 931.34 1.49 71.40 15.57 747.47 0.803 3-Apr 13:00 140,0 60 Adj. 6.0 23.75 22.33 90.0 96.0 107.0 112.0 21.92 1052.10 1.43 68.40 16.00 768.01 0,730 3-Apr 13:30 140.0 60Adj. 8.0 21.25 19.55 90.0 96.0 107.0 112.0 19.19 921.32 1.70 81.60 16.00 768.01 0.834 3-Apr 14:00 139.0 60Adj. 7.0 22.50 20.93 39.40 90.0 96.0 107.0 112.0 20.38 978.29 1,58 75.60 16.00 768.01 0.785 3-Apr 14:30 142.0 60 Adj. 7.0 23.33 21.70 90.0 100.0 107.0 112.0 21.30 1022.50 1.63 78.39 16.34 784.08 0,767 3-Apr 15:00 141.0 60Adj. 7.0 20.83 19.37 90.0 96.0 107.0' 112.0 19.02 912.93 1.46 69.99 16.00 768.01 0.841 3-Apr 15:30 136.0 60Adj. 8.0 24,17 22.24 90.0 100.0 107.0 112.0 21.83 1047.92 1.93 92.81 16.34 784.08 0.748 Page 3.13 Final_Reports/Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time Wellhead Data Separator Readings , , , ,, , , Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDE~ (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 3-Apr 16:00 139.0 60Adj. 6.'0 20.83 19.58 39.20 0.810 0.810 90.0 96.0 107.0 112.0 19.07 915.41 1.25 59.99 16.00 768.01 0.839 26,000 3-Apr 16:30 141.0 60Adj. 7.0 22.50 20.93 90.0 88.0 107.0 112.0 20.54 986.12 1.58 75.60 15.31 734.88 0.745 3-Apr 17:00 139.0 60Adj. 6.0 22.50 21.15 90.0 100.0 107.0 112.0 20.77 996.72 1.35 64.80 16.34 784.08 0.787 3-Apr 17:30 139.0 60Adj. 6.0 22.08 20.76 90.0 100.0 107.0 1120 20.38 978.12 1.32 63.59 16.34 784.08 0.802 3-Apr 18:00 141.0 60Adj. 6.0 21.67 20.37 39.80 90.0 100.0 107.0 112.0 19.84 952.33 1.30 62.41 16.34 784.08 0.823 3-Apr 18:30 139.0 60Adj. 6.0 21.25 19.98 90.0 100.0 105.0 112.0 19.61 941.35 1.28 61.20 16.37 785.55 0.834 3-Apr 19:00 140.0 60Adj. 6.0 23.33 21.93 90.0 100.0 105.0 112.0 21.53 1033.49 1.40 67.19 16.37 785.55 0.760 3-Apr 19:30 139.0 60Adj. 60 22.92 21.54 90.0 100.0 105.0 112.0 21.15 1015.33 1.38 66.01 16.37 785.55 0.774 3-Apr 20:00 141.0 60 Adj. 5.0 22.92 21.77 39.80 0.810 0.810 90.0 100.0 105.0 112,0 21.21 1017.98 1.15 55.01 16.37 785.55 0.772 2',' 3-Apr 20:30 139.0 60Adj. 5.0 22.08 20.98 90.0 100.0 105.0 112.0 20.59 988.52 1.10 52.99 16.37 785.55 0,795 3-Apr 21:00 140.0 60Adj. 5.0 20.42 19.40 95.0 88.0 105.0 112.0 19.05 914.21 1.02 49.01 15.78 757.52 0.829 3-Apr 21:30 142.0 60Adj. 5.0 25.83 24.54 95.0 96.0 105.0 112.0 24.09 1156.41 1.29 61.99 16.49 791.65 0.685 3-Apr 22:00 144.0 60Adj. 5.0 20.00 19.00 40.00 95.0 96.0 105.0 112.0 18.51 888.29 1.00 48.00 16.49 791.65 0.891 3-Apr 22:30 143.0 60 Adj. 5.0 25.42 24.15 95.0 96.0 105.0 112.0 23.71 1138.06 1.27 61.01 16.49 791.65 0.696 3-Apr 23:00 143.0 60 Adj. 5.0 21.67 20.59 95.0 96.0 105.0 112.0 20.21 970.17 1.08 52,01 16.49 791.65 0,816 3-Apr 23:30 144.0 60 Adj. 5.0 21.25 20.19 95.0 96.0 105.0 112.0 19.82 951.36 1.06 51.00 16.49 791.65 0.832 4-Apr 00:00 145.0 60 Adj. 6.0 23.33 21.93 40.00 0.810 0.810 95.0 96.0 105.0 112.0 21.36 1025.28 1.40 67.19 16.49 791.65 0,772 25,000 4-Apr 00:30 144.0 60 Adj. 6.0 20,00 18.80 95.0 96.0 105.0 112.01 18.46 885.98 1.20 57.60 16.49 791.65 0.894 Page 3.14 Final_Reports / Separator Reading Customer: ARCO Alaska, INC, Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time Wellhead Data Separator Readings Tubing Choke Choke Tank Oil Inc. , 'OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Templ TEMP Inc, Rate Inc. Rate Inc. Rate GOR CHLORIDE5 (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (@6OF) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) , .... 4-Apr 01:00 145.0 60Adj. 6.0 20.83 19.58 95.0 96.0 105,0 112.0 19.22 922.74 1,25 59.99 16.49 791.65 0.858 4-Apr 01:30 145,0 60Adj. 6,0 23.33 21.93 95.0 96,0 105.0 112.0 21,53 1033.49 1.40 67.19 16.49 791.65 0.766 4-Apr 02:00 146.0 60Adj. 5.0 24.17 22,96 40,30 95.0 96.0 105.0 112.0 22,36 1073.50 1.21 58.01 16.49 791.65 0.737 4-Apr 02:30 145.0 60Adj. 5,0 22.50 21.38 95.0 98.0 105.0 112.0 20,99 1007.33 1.13 54.00 16.69 800.91 0.795 4-Apr 03:00 144.0 60Adj. 5.0 24,17 22.96 95.0 98,0 105.0 112.0 22,54 1082.09 1.21 58.01 16,69 800.91 0.740 4-Apr 03:30 145.0 60Adj. 5.0 22.08 20,98 95.0 98,0 105.0 112.0 20,59 988.52 1.10 52.99 16,69 800.91 0.810 4-Apr 04:00 147.0 60Adj. 5.0 22.08 20.98 40.50 0.808 0.808 95.0 97.0 105.0 112.0 20,43 980.67 1.10 52.99 16.60 796.58 0.812 25.000 4-Apr 04:30 147.0 60Adj. 5.0 22.50 21.38 95.0 98,0 105.0 112.0 20,99 1007.33 1.13 54.00 16.69 800.91 0.795 4-Apr 05:00 146.0 60Adj. 5.0 22.92 21.77 95.0 98.0 105.0 112.0 21.38 1026.13 1.15 55.01 16.69 800.91 0.781 4-Apr 05:30 147.0 60Adj. 5.0 22.50 21,38 95.0 98,0 105.0 112.0 20,99 1007.33 1.13 54.00 16.69 800.91 0,795 4-Apr 06:00 148,0 60 Adj, 5.0 21.25 20.19 40.10 95.0 98,0 105.0 112.0 19.66 943.81 1.06 51.00 16.69 800.91 0.849 4-Apr 07:00 149.0 60Adj. 5.0 47.92 45.52 85.0 112.0 105.0 112.0 44.70 1072.69 2.40 57.50 33.77 810.48 0.756 4-Apr 08:00 150.0 60Adj. 3.0 44.58 43.24 95.0 98.0 105.0 112.0' 42.46 1018.93 1.34 32.10 33.37 800.91 0.786 4-Apr 09:00 148.0 60Adj. 3.0 46,25 44.86 90.0 100.0 105.0 112.0 44.05 1057.10 1.39 33.30 32.77 786.48 0.744 4-Apr 10:00 147.0 60Adj. 5.0 44.17 41.96 38.90 0.810 0,810 90.0 102.0 105.0 112.0 40.87 980.89 2.21 53,00 33.10 794.42 0.810 4-Apr 11:00 150.0 60Adj. 4.0 49.58 47.60 90.0 104,0 105.0 112.0 46.73 1121.53 1.98 47.60 33,43 802.29 0.715 4-Apr 12:00 149.0 60Adj. 4.0 42.08 40.40 90.0 102.0 105.0 112.0 39.66 951.88 1.68 40.40 33,10 794.42 0.835 26.000 4-Apr 13:00 149.0 60Adj. 4.0 45.00 43.20 90.0 102.0 105,0 112.0 42.41 1017,93 1.80 43.20 33.10 794,42 0.780 Page 3,15 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/TimeII, Wellhead Data Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLO~,..,~'~ (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 4-Apr 14:00 151.0 60Adj. 4.0 45.00 43.20 39.80 90.0 100.0 105.0 112.0 42.08 1009.84 1.80 43.20 32.77 786.48 0.779 , , 4-Apr 15:00 151.0 60Adj. 5.0 49.58 47.10 90.0 102.0 105.0 112.0 46.24 1109.85 2.48 59.50 33.10 794.42 0.716 4-Apr 16:00 149.0 60Adj. 4.0 44.17 42.40 95.0 92.0 105.0 1120 41.63 999.15 1.77 42.40 32.28 774.76 0.775 4-Apr 17:00 149.0 60Adj. 4.0 45.83 44.00 95.0 96.0 105.0 112.0 43.20 1036.70 1.83 44.00 32.99 791.65 0.764 4-Apr 18:00 147.0 60Adj. 4.0 45.42 43.60 39.80 0.810 0,810 95.0 96.0 105.0 112.0 42.47 1019.27 1.82 43.60 32.99 791.65 0,777 25,500 4-Apr 19:00 148.0 60Adj. 4.0 44.17 42.40 90.0 104.0 :105.0 112.0. 41.63 999.15 1.77 42.40 33.43 802.29 0.803 , 4-Apr 20:00 149.0 60Adj. 4.0 64.58 62.00 41.70 90.0 104.0 105.0 112.0 60.38 1449.24 2.58 62.00 33.43 802.29 0.554 4~Apr 21:00 149.0 60 Adj. 4.0 32.92 31.60 90.0 104.0 105.0 110.0 31.05 745.20 1.32 31.60 33.43 802.29 1.077 4-Apr 22:00 149.0 60 Adj. 4.0 41.25 39.60 41.30 0,810 0.810 85.0 104.0 105.0! 110.0 38.61 926.64 1.65 39.60 32.48 779.58 0,841 4-Apr 23:00 150.0 60 Adj. 4.0 46.67 44.80 85.0 104.0 105.0 110.0 44.02 1056.46 1.87 44.80 32.48 779.58 0.738 5-Apr 00:00 150.0 60Adj. 4.5 47.92 45.76 40.90 85.0 104.0 108.0 110,0 44.62 1070.87 2.16 51.75 32.39 777.40 0,726 25,000 5-Apr 01:00 150.0 60 Adj. 4.0 43.75 42.00 85.0 105.0 108.0 110.0 41.27 990.36 1.75 42.00 32.55 781.19 0.789 5-Apr 02:00 148.0 60 Adj. 4.0 48.33 46.40 40.90 0.810 0.810 80.0 110.0 108.0 110.0 45.24 1085.69, 1.93 46.40 32.33 775.98 0.715 5-Apr 03:00 150.0 60Adj. 4.0 47.50 45.60 80.0 110.0 108.0 110.0 44.80 1075.25' 1.90 45.60 32.33 775.98 0,722 5-Apr 04:00 149.0 60Adj. 4.0 46.25 44.40 40.70 75.0 110.0 108.0 111.0 43.27 1038.43 1.85 44.40 31.31 751.36 0.724 5-Apr 05:00 150.0 60Adj. 3.5 45.83 44.23 77.0 111.0 114.0 111.0 43.44 1042.48 1.60 38.50 31.69 760.63 0.730 27,500 5-Apr 06:00 147.0 60Adj. 4.0 47.50 45.60 40.70 0.810 0.810 77.0 111.0 108.0 110.0 44.46 1067.04 1.90 45.60 31.87 764.81 0.717 ,_ 5-Apr 07:00 149.0 60 Adj. 4.0 50.00 48.00 73.0 114.0 108.0 110.0 47.16 1131.84 2.00 48.00 31.46 754.93 0.667 Page 3.16 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Eon Cookson Storage Tank Coeff: 1.6667 Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas ~ (dd-mmrn) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mrn) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) 5-Apr 08:00 148.0 60 Adj. 3.0 39.59 38.40 39.60 75.0 112.0 108.0 110.0 37.44 898.61 1.19 28.50 31.60 758.29 0.844 5-Apr 09:00 149.0 60 Adj. 3.0 46,67 45.27 75.0 112.0 108.0 110.0 44.48 1067.49 1.40 33.60 31.59 758.29 0.710 5-Apr 10:00 881.0 0 Adj. 5-Apr 10:30 815.0 24 Adj. 2.0 3.33 3.26 3.33 159.93 0.07 3.20 0.00 5-Apr 11:00 561.0 34 Adj. 2.0 26.67 26.14 26.69 1280.90 0.53 25.60 0.00 5-Apr 11:30 442.0 38Adj. 2.0 12.50 12.25 12.51 600.35 0.25 12.00 0.00 5-Apr 12:00 415.0 42 Adj. 2.0 16.67 16.34 40.10 16.83 807.69 0.33 16.00 0.00 5-Apr 12:30 323.0 60 Adj. 1.0 24.58 24.33 24.85 1192.57 0.25 11.80 0.00 5-Apr 13:00 336.0 60 Adj. 5.5 16.67 15.75 16.08 772.03 0.92 44.01 0.00 ?_ 5-Apr 13:30 196.0 60Adj. 4.0 31.25 30.00 90.0 92.0 92.0 102.0 29.56 1418.84 1.25 60.00 15.90 763.29 0.538 5-Apr 14:00 914.0 0 Adj. 2.50 2.50 0.810 0.810 2.55 122.52 0.00 0.00 0.00 5-Apr 14:30 24 Adj. 4.0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5-Apr 15:00 36 Adj. 4.5 14.58 13.92 14.22 682.38 0.66 31.49 0.00 5-Apr 15:30 427.0 36 Adj. 4.5 20.42 19.50 19.91 955.71 0.92 44.11 0.00 ....... 5-Apr 16:00 384.0 40 Adj. 3.0 22.08 21.42 90.0 40.0 67.0 67.0 21.37 1025.53 0.66 31.80 10.71 514.02 0.501 5~Apr 16:30 305.0 40 Adj. 4.0 24.58 23.60 24.09 1156.44 0.98 47.19 0.00 5-Apr 17:00 228.0 44 Adj. 2.0 22.08 21~64 85.0 76.0 64.0 65.0 21.60 1036.83 0.44 21.20 14.45 693.57 0.669 .... 5-Apr 17:30 212.0 48 Adj. 4.5 30.42 29.05 92.0 63.0 74.0 76.0 28.89 1386.65 1.37 65.71 13.49 647.48 0.467 Page 3.17 Final_Reports / Separator Reading Customer: ARCO Alaska, INC, Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Eon Cookson Storage Tank Coeff: 1,6667 Date/Time ii Wellhead Data Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas ~ (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) , , 5-Apr 18:00 169.0 60 Adj. 3.0 22.92 22.23 39.90 0.810 0.810 89.0 88,0 88.0 94.0 21.85 1049.02 0.69 33.00 15.52 744.97 0.710 5-Apr 18:30 150.0 60Adj. 2.0 26,25 2573 95.0 100.0 101.0 107.0 25.30 1214.49 0.53 25.20 16.90 811.26 0.668 , 5-Apr 19:00 160,0 60Adj. 2.0 21.67 21.24 90.0 94.0 102.0 108.0 20.88 1002.23 0.43 20.80 15.92 764.33 0.763 5-Apr 19:30 158.0 60Adj. 2.0 25.83 25.31 92.0 94.0 103.0 108,0 24.89 1194,63 0.52 24.80 16.09 772.12 0.646 5-Apr 20:00 158.0 60 Adj. 2.0 25.83 25.31 90.0 98.0 103.0 108.0 24.89 1194.63 0.52 24.80 16.25 779.92 0.653 27,500 5-Apr 20:30 165.0 60Adj. 2.5 23.75 23.16 92.0 95.0 104.0 108.0 22.77 1092.83 0.59 28.50 16.16 775.54 0.710 5-Apr 21:00 163.0 60Adj. 2.0 20.83 20.41 92.0 95.0 105.0 109.0 20.06 963.04 0.42 20.00 16.14 774.82 0.805 5-Apr 21:30 162.0 60Adj. 2.0 26.67 26.14 93.0 96.0 106.0 110.0 25.68 1232.60 0.53 25.60 16.30 782.46 0.635 5-Apr 22:00 162.0 60Adj. 2.0 22.92 22.46 40.10. 0.810 0,810 93.0 94.0 108.0 110.0: 21.90 1051.20 0.46 22.00 16.13 774.16 0.736 , 5-Apr 22:30 162.0 60Adj. 3.5 22.92 22.12 93.0 93.0 108.0 110.0 21.73 1043.08 0.80 38.51 16.01 768,54 0.737 5-Apr 23:00 162.0 60Adj. 3.5 26.67 25.74 90.0 93.0 107.0 110.0 25.29 1213.74 0.93 44.81 15.76 756.65 0.623 ,, 5-Apr 23:30 162.0 60 Adj. 3.0 25.00 24.25 90.0 95.0 107.0 110.0 23.83 :1143.63 0.75 36.00 16.20 777.59 0.680 6-Apr 00:00 162.0 60 Adj. 3.0 24.17 23.44 40.10 93.0 95.0 107.0 110.0 22.86 1097.22 0.73 34.80 15.93 764.85 0.697 27,000 6-Apr 00:30 162,0 60Adj. 3.0 23.33 22.63 90.0 98.0 107.0 110.0 22.23 1067.24 0.70 33.60 16.20 777.59 0,729 6-Apr 01:00 161.0 60Adj. 3.0 25.83 25.06 90.0 98.0 107.0 110.0 24.62 1181.60 0.77 37.20 16.19 777.01 0.658 6-Apr 01:30 160.0 60Adj. 3.0 24.58 23.84 90.0 98.0 107.0 110.0 23.43 1124.42 0.74 35.40 16,19 777.01 0.691 6-Apr 02:00 160.0 60Adj. 3,0 23.33 22.63 40.00 0.810 0.810 90.0 98.0 107.0 109.0 22.08 1059,63 0.70 33.60 16.19 777.01 0.733 r 6-Apr 02:30 159.0 60Adj. 3.0 25.83 25.06 90.0 98.0 106.0 109.0 24.63 1182.02 0.77 37.20 16.19 77731 0.658 Page 3.18 Final_Reports / Separator Reading Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Halliburton Energy Services Well Test Separator Summary Gas Meter Run ID: 3.826 Barton Recorder Range: 1500# X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 IDate/'l'ime I{ Wellhead Data [I Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas ii~ (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAV Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDE~ (hh:mm) (psig) (64ths) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) .(bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) ..... 6-Apr 03:00 160.0 60 Adj. 3.0 21.67 21.02 90.0 97.0 106.0; 109.0 20.66 991.65 0.65 31.20 16.12 773.70 0.780 ........... 6-Apr 03:30 159.0 60Adj. 3.0 22.08 21.42 90.0 97.0 106.0 109.0 21.05 1010.41 0.66 31.80 1612 773.70 0.766 6-Apr 04:00 160.0 60 Adj. 3.0 26.25 25.46 40.00 90.0 97.0 106.0 109.0 24.84 1192.26 0.79 37.80 16.12 773.70 0.649 27,000 J,, 6-Apr 04:30 159.0 60 Adj. 3.0 26.25 25.46 90.0 97.0 106.0 109.0 25.03 1201.24 0.79 37.80 16.12 773.70 0.644 6-Apr 05:00 161.0 60Adj. 3.0 22.08 21.42 90.0 98.0 106.0 108.0 21.06 1010.77, 0.66 31.80 16.19 777.31 0.769 6-Apr 05:30 159.0 60Adj. 3.0 24.17 23.44 90.0 98.0 107.0 110.0 23.03 1105.66! 0.73 34.80 16.19 777.01 0.703 6-Apr 06:00 159.0 60Adj. 3.0 22.92 22.23 90.0 98.0 106.0 108.0 21.86 1049.23 0.69 33.00 16.19 777.31 0.741 6-Apr 06:30 158.0 60Adj. 3.0 26.67 25.87 90.0 98.0 108.0 110.0 25.42 1220.02 0.80 38.40 16.17 776.28 0.636 6-Apr 07:00 160.0 60 Adj. 3.0 21.67 21.02 90.0 98.0 108.0 110.0 20.65 991.30 0.65 31.20 16.17 776.28 0.783 6-Apr 07:30 160.0 60Adj. 3.0 26.25 25.46 90.0 98.0 108.0 110.0 25.02 1200.81 0.79 37.80 16.17 776.28 0.646 6-Apr 08:00 159.0 60Adj. 4.0 22.92 22.00 90.0 98.0 108.0 110.0 21.62 1037.67 0.92 44.01 16.17 776.28 0.748 6-Apr 08:30 159.0 60Adj. 3.0 25.00 24.25 90.0 98.0 108.0 110.0 23.83 1143.63 0.75 36.00 16.17 776.28 0.679 6-Apr 09:00 158.0 60Adj. 3.0 25.42 24.66 90.0 98.0 108.0 110.0: 24.23 1162.84 0.76 36.60 16.17 776.28 0.668 6-Apr 09:30 160.0 60Adj. 3.0 22.50 21.83 90.0 98.0 108.01 110.0 21.44 1029.27 0.68 32.40 16.17 776.28 0.754 6-Apr 10:00 161.0 60 Adj. 3.0 24.17 23.44 40.10 0.810 0.810 90.0 98.0 108.0: 110.0 22.86 1097.22 0.73 34.80 16.17 776.28 0.707 6-Apr 10:30 160.0 60Adj. 3.0 25.00 24.25 90.0 98.0 108.0 110.0 23.83 1143.63 0.75 36.00 16.17 776.28 0.679 6-Apr 11:00 159.0 60Adj. 3.0 24.17 23.44 90.0 98.0 108.0 110.0 23.03 11105.66 0.73 34.80 16.17 776.28 0.702 6-Apr 11:30 159.0 60Adj. 3.0 24.17 23.44 90.0 98.0 108.0 110.0 23.03 1105.66 0.73 34.80 16.17 776.28 0.702 Page 3.19 Final_Reports / Separator Reading Halliburton Energy Services Well Test Separator Summary Customer: ARCO Alaska, INC. Well: Neve No.1 Test Number: Post Frac Flow Company Rep: Scott Weimer Gas Meter Run ID: 3.826 Barton Recorder Range: 1500~ X 200" WC H.E.S. Rep: Ron Cookson Storage Tank Coeff: 1.6667 Date/Time Wellhead Data Separator Readings Tubing Choke Choke Tank Oil Inc. OIL ORIFICE GAS Gas OIL Oil Oil Water Water Gas Gas .., (dd-mmm) Press Size BS&W Level Uncorr. GRAV SIZE GRAY Static Diff Temp TEMP Inc. Rate Inc. Rate Inc. Rate GOR CHLORIDES (hh:mm) (psig) (64tbs) (%) (bbls) (bbls) (~60F) (inches) (AIR=l) (psig) (inH20) (°F) (°F) (bbl) (bbl/d) (bbls) (bbl/d) (mscf) (mscf/d) (mscf/bbl) (ppm) ,, , 6-Apr 12:00 159.0 60Adj. 3.0 25.42 24.66 90.0 98.0 108.0 110.0 24.23 1162.84 0.76 36.60 16.17 776.28 0.668 ,, 6-Apr 12:30 160.0 60Adj. 3.0 22.92 22.23 90.0 97.0 108.0 110.0 21.84 1048.48 0.69 33.00 16.09 772.25 0.737 6-Apr 13:00 160.0 60Adj. 3.0 24.17 23.44 90.0 97.0 108.0 110.0 23.03 1105.66 0.73 34.80 16.09 772.25 0.698 ,, 6-Apr 13:30 , , 6-Apr 14:00 6-Apr 14:30 100.0 22.00 0.00 0.00 0.00 22.00 :1056.00 0.00 , ,, , Page 3.20 Final_Reports / Separator Reading Company: ARCO Alaska, INC. Well: Neve #1 Test Number: Pest Frac Clean Up Date: 28-Mar-96 Ha~ibuder~ Ener0y Services Weellhead Readir~9 vs Time IOO0 128 900 8OO 7OO 500 400 300 200 0 18:00 100 18:00 18:00 18:00 18:00 18:00 18:00 18:00 18:00 Time 112 98 80 m ~ 0 18:00 84 48 ~¢~ ~ 32 10 Tubing ~-~- Casing ---e,-- Choke ~ Temperature Plot Start Time:28-MarJg6 Ptfrac / Current Wellhead Plot Page no: 4.1 Plot End Time:6-Apt-96 18:00 Company: ARCO A~aska, ~NC Weth Neve #t Test Number: Post Frac Clean Up Date: 28-Mar-98 FJuid Rate History 2200 1200 2000 1800 1600 1400 12oo 1000 800 $00 4OO 2OO 0 ~ 8:00 18:00 I8:00 18:00 18:00 18:00 t8:00 I8:00 18:00 Time 1100 1000 9OO 8OO 7OO 60O 5OO 40O 3OO 2OO 100 0 t8:00 -,e-- Oil -*-~ Water/Diesel Fiat Star~ Time: 28-Mar-00 18:00 Ptfrac / Current Rate Plot Page no: 4.2 Plat End Time: 6,Apr-96 I8:00 Company: ARCO A~aske tNC Test Number: Post Frae C~ean Up Fluid Cures vs Time Well: Alpine Date: 28~Mar-96 6000 6000 5000 4000 3ooo 2000 1000 0 18:00 18:80 18:00 18:00 18:00 18:00 18:00 18:00 18:00 50OO 4000 3000 2O0O 1000 0 I8:00 -4~-0il ----e--Water/Diesel r--~' Gas Plot Star~ Time:28-Mar-96 18:00 Ptftac / Current Total Cum Plot Page no: 4~3 P~ot End Time:6-Apr-96 I8:043 Pressure/Temperature ¼'story Test i'qo: Two th Gouge No: 10220 Well No: Neve L 2.o _ 1.0 L 0.0~ 9.> Company: ARCO Alaska 200 R 1 J 4 '~o )>o Pressure Vs Del(a Time 3.4 -,rest Nb: Two ~ Gauge No: 10220 - Period No: 1 " We!l: Neve Company: ARCO Alaska Ana~st: RAR j - I II I I I IIII II I _. . I .l I I I 1.0 L._: ,_~._.L.__L ,_~..z...__~_~_ ; :-,~.. I _,_ ..... .~___L. 1 , , _, i- ........ , , , I _,_~__.z....___L.___L. , .-L_ , I :.Z.-. ~ _..Z.__ --'$ 0 4. 8 12 16 20 24 28 32 Delt~ Time (hours) Drewdown Period Pressure Vs Del~a Time Z 3.4- 3.0 2.6 2.2 1.8 1.4- 1.0 Test No: Two ga.uge No: 10220 Period No: 2 .' i Well: Neve I p = r Company: ARCO Alaskc i An~st~ PAR . I -10 10 30 50 70 90 110 1,30 150 170 Deltc Time (hours) Buildup Period Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot ., (dd-mmm hh:mm) (ft.) (in,) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (lt.) (in.) (bbls) Pre-Flow Strap 5.00 8.33 7.50 12.50 4.00 6.67 9.00 15.00 4.50 7.50 , 01-Apr 8:30 Q00 0,00 0.00 9.00 0.00 0.00 , ,,, , 01-Apr 9:00 0,00 0,00 0,00 9.00 0.00 0.00 0.00 ,, , ...... ,,, , 01-Apr 9:30 0,00 0.00 0.00 1,00 1.00 6.67 6.67 0.00 ,,,,,, , ,, 01-Apr 10:00 0.00 0.00 0.00 1.00 5.50 7.50 14.17 0.00 01-Apr 10:30 0.00 0.00 0.00 2.00 6.50 21.67 35.83 0.00 01-Apr 11:00 0.00 0.00 0.00 3.00 3.00 14.17 50.00 0.00 J 01-Apr 11:30 0.00 0.00 0.00 3.00 9.50 10.83 60.83 0.00 . 01-Apr 12:00 0.00 0.00 0.00 4.00 10.00 20.83 81.67 ......, 01-Apr 12:30 0.00 0.00 0.00 5.00 9.25 18.75 100.42 0.00 01-Apr 13:00 0.00 0.00 0.00 6.00 4.00 11.25 111.67 0.00 01-Apr 13:30 0.00 0.00 0.00 7.00 5.00 21.67 133.34 0.00 01-Apr 14:00 0.00 0.00 4.00 0.00 9.00 7.00 43.33 176.67 0.00 01-Apr 14:30 0.00 0.00 1.00 2.50 17.50 17.50 0.00 0.00 01-Apr 15:00 0.00 0.00 2.00 1.00 17.50 35.00 0.00 0.00 01-Apr 15:30 0.00 0.00 3.00 0.00 18.33 53.33 9.50 0.00 0.00 , . 01-Apr 16:00 0.00 0.00 0.00 1.00 6.00 14.17 14.17 0.00 Page no: 6.1.1 Ptfrac/Tank Farm I thru.5 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) 01-Apr 16:30 0.00 0.00 0.00 2.00 3.50 15.83 30.00 0.00.. 01-Apr 17:00 0.00 0.00 0.00 3.00 1.75 17.08 47.08 0.00:':,? 01-Apr 17:30 0.00 0.00 0,00 4.00 0.50 17.92 65.00 0.00' 01-Apr 18:00 0.00 0.00 0.00 4.00 10.00 15.83 80.83 0.00 01-Apr 18:30 0.00 0,00 0.00 5.00 9.00 18.33 99.17 0.00 , , _ 01-Apr 19:00 0.00 0.00 0.00 6.00 9.50 20.83 120.00 0.00 01-Apr 19:30 0.00 0.00 0.00 7.00 10.50 21.67 141.67 0.00 01-Apr 20:00 0.00 0.00 0.00 8.00 10.50 20.00 161.67 0.00 -- 01-Apr 20:30 0.00 0,00 0.00 9.00 11.00 20.83 182.50 0.00 _ 01-Apr 21:00 0.00 0.00 6.00 0.00 10.00 9.25 17.08 199.59 01-Apr 21:30 0.00 0.00 1.00 6.00 20.00 20.00 0.00 0.00 01-Apr 22:00 0.00 0.00 2.00 4.75 17.92 37.92 0.00 0.00 , 01-Apr 22:30 0.00 0.00 3.00 4.25 19.17 57.08 0.00 0.00 _ 01-Apr 23:00 0.00 0.00 4.00 4.25 20.00 77.08 0.00 0.00 01-Apr 23:30 0.00 0.00 5.00 4.00 19.58 96.67 0.00 0.00 02-Apr 0:00 0.00 0.00 6.00 1.00 15.00 111.67 6.00 0.00 0.00 02-Apr 0:30 0.00 0.00 0,00 1.00 9.00 25.00 25.00 0,00 02-Apr 1:00 0.00 0,00 0.00 2.00 5,00 13.33 38.33 0.00 Page no: 6.1.2 Ptfrac / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve No.1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (lt.) (in.) (bbls) 02-Apr 1:30 0.00 0.00 0.00 3,00 8.50 25.83 64.17 0,00 ..... 02-Apr 2:00 0,00 0,00 0,00 4,00 7.25 17.92 82.08 0,00 02-Apr 2:30 0.00 0.00 0.00 5,00 8.00 21.25 103.34 0.00 02-Apr 3:00 0.00 0.00 0.00 6.00 5.25 15.42 118.75 0,00 02-Apr 3:30 0.00 0.00 0.00 7.00 6.50 22.08 140,84 0.00 , 02-Apr 4:00 0.00 0.00 0.00 8.00 4.75 17,08 157.92 0.00 02-Apr 4:30 0,00 0.00 0.00 9.00 3.75 18.33 176.25 0.00 02-Apr 5:00 0.00 0.00 0.00 10,00 4.00 20.42 196.67 0.00 02-Apr 5:30 0.00 0.00 0.00 11.00 5.25 22.08 218.75 , 0.00 02-Apr 6:00 Q00 0.00 0.00 12.00 3.25 16.67 235.42 02-Apr 6:30 0.00 0.00 0.00 13.00 3.25 20.00 255.42 0.00 02-Apr 7:00 0.00 0.00 9.00 0.00 14.00 3.00 19.58 275.01 0.00 02-Apr 7:30 0.00 0.00 1.00 6.25 15.42 15.42 0.00 0.00 02-Apr 8:00 0.00 0.00 2.00 6.75 20.83 36.25 0.00 0.00 02-Apr 8:30 0.00 0.00 3,00 7.50 21.25 57.50 0.00 0.00 02-Apr 9:00 0.00 0.00 4,00 5.25 16.25 73.75 0.00 0.00 02-Apr 9:30 0.00 0.00 5.00 5.25 20.00 93.75 0.00 0.00 02-Apr 10:00 0.00 0.00 6.00 4.25 18.33 112.09 0.00 0.00 Page no: 6.1.3 Ptfrac / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve No, 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in,) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) 02-Apr 10:30 0,00 0.00 7.00 4.25 20.00 132.09 0.00 0.00 02-Apr 11:00 0.00 0.00 8.00 4.25 20.00 152.09 0.00 0.00 02-Apr 11:30 0.00 0.00 9.00 3.00 17.92 170.00 0.00 0.001 02-Apr 12:00 0.00 0.00 10.00 3.50 20.83 190.84 0.00 0.00 , 02-Apr 12:30 0.00 0.00 11.00 3.75 20.42 211.25 0.00 0.00 ,, 02-Apr 13:00 0.00 0.00 12.00 2.00 17.08 228.34 0.00 0.00 ,, , 02-Apr 13:30 0.00 0.00 13.00 1.25 18.75 247.09 0.00 0.00 02-Apr 14:00 0.00 0.00 14.00 0.00 17.92 265.01 11.75 0.00 0.00 ,,,,,, 02-Apr 14:30 0.00 0.00 0.00 1.00 11.50 19.58 19.58 0.00 02-Apr 15:00 0.00 0.00 0.00 2.00 11.75 20.42 40.00 0 r .t!,_ 02-Apr 15:30 0.00 0.00 0.00 3.00 11.25 19.17 59.17 0.00 02-Apr 16:00 0.00 0.00 0.00 4.00 10.25 18.33 77.50 0.00 , 02-Apr 16:30 0.00 0.00 0.00 5.00 10.25 20.00 97.50 0.130 02-Apr 17:00 0.00 0.00 0.00 6.00 10.25 20.00 117.50 0.00 02-Apr 17:30 0.00 0.00 0.00 7.00 10.50 20.42 137.92 0.130 02-Apr 18:00 0.00 0.00 0.00 8.00 10.25 19.58 157.50 0.00 __ 02-Apr 18:30 0.00 0.00 0.00 9.00 8.75 17.50 175.00 0.00 02-Apr 19:00 0.00 0.00 0.00 10.00 8,25 19.17 194.17 0.00 Page no: 6,1.4 Ptfrac I Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve No.1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No./5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot: Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (~ 02-Apr 19:30 0.00 0.00 0.00 11.00 9.00 21.25 215.42 0.00 02-Apr 20:00 0.00 0.00 0.00 12.00 9.25 20.42 235.84 0.00 02-Apr 20:30 0.00 0.00 0.00 13.00 7.25 16.67 252.51 0.00 02-Apr 21'00 0.00 0.00 0.00 14.00 7.50 20.42 272.92 0.00 02-Apr 21:30 0.00 0.00 5.50 0.00 15.00 4.50 15.00 287.92 0.00 02-Apr 22:00 0.00 0.00 1.00 7.00 22.50 22.50 0.00 0.00 02-Apr 22:30 0.00 0.00 2.00 7.00 20.00 42.50 0.00 0.00 02-Apr 23:00 0.00 0.00 3.00 6.00 18.33 60.83 0.00 0.00 02-Apr 23:30 0.00 0.00 4.00 6.25 20.42 81.25 0.00 0.00 03-Apr 0:00 0.00 0.00 5.00 5.00 17.92 99.17 0.00 03-Apr 0:30 0.00 0.00 6.00 4.25 18.75 117.92 0.00 0.00 03-Apr 1:00 0.00 0.00 7.00 5.25 21.67 139.59 0.00 0.00 .. 03-Apr 1:30 0.00 0.00 8.00 4.25 18.33 157.92 0.00 0.00 03-Apr 2:00 0.00 0.00 9.00 4.50 20.42 178.34 0.00 0.00 03-Apr 2:30 0.00 0.00 10.00 6.00 22.50 200.84 0.00 0.00 03-Apr 3:00 0.00 0.00 11.00~ 3.00 15.00 215.84 0.00 0.00 03-Apr 3:30 0.00 0.00 12.00 3.00 20.00 235.84 0.00 0.00 03-Apr 4:00 0.00 0.00 13.00 2.25 18.75 254.59 0.00 0.00 Page no: 6.1.5 Ptfrac / Tank Farm I thru 5 Company: ARCO AlaSka, INC. Well Number: Neve No, 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 i Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 , Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) I i i i iiiii I 03-Apr 4:30 0.00 0,00 14,00 3.00 21.25 275.84 0.00 0.00 , 03-Apr 5:00 0.00 0.00 15.00 2.00 18.33 294.17 0.00 0.00 03-Apr 5:30 0.00 0.00 16.00 1.00 18.33 312.51 9.00 0.00 0.00,:',' 03-Apr 6:00 0.00 0.00 0.00 1.00 8.75 19.58 19.58 0.00 ,, , 03-Apr 6:30 0.00 0.00 0.00 2.00 10.25 22.50 42.08 0.00 , 03-Apr 7:00 0.00 0.00 0.00 3.00 9.25 18.33 60.42 0.00 03-Apr 7:30 0.00 Q00 0.00 5.00 0.25 25.00 85.42 0.00 _ 03-Apr 8:00 0.00 0.00 0.00 6.00 2.75 24.17 109.59 0.00 ,, _ 03-Apr 8:30 0.00 0.00 0.00 7.00 3.75 21.67 131.25 0.00 03-Apr 9:00 0.00 0.00 0.00 8.00 5.25 22.50 153.75 03-Apr 9:30 0.00 0.00 0.00 9.00 7.00 22.92 176.67 0.00 03-Apr 10:00 0.00 0.00 0.00 10.00 9.00 23.33 200.00 0,00 03-Apr 10:30 0.00 0.00 0.00 11.00 8.75 19.58 219.59 0,00 ! 03-Apr 11'00 0.00 0.00 0.00 12.00 10.25 22.50 242.09 0.00 03-Apr 11'30 0.00 0.00 0.00 14.00 0.50 23.75 265.84 0.00 03-Apr 12:00 0.00 0.00 0.00 15.00 1.50 21.67 287.51 0,00 03-Apr 12:30 0.00 0.00 2.00 10.25: 0.00 16.00 2.25 21.25 308.76 0.00 03-Apr 13:00 0.00 0.00 4.00 0.50 23.75 23.75 0,00 0,00 Page no: 6,1,6 Ptfrac / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 , , Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in,) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) ~ i) 03-Apr 13:30 0.00 Q00 5.00 1.25 21.25 45.00 0.00 0.00 03-Apr 14:00 0.00 0.00 6.00 2.75 22.50 67.50 0.00 0.00 03-Apr 14:30 0.00 0.00 7.00 4.75 23.33 90.84 0.00 0.00 03-Apr 15:00 0.00 Q00 8.00 5.25 20.83 111.67 0.00 0.00 03-Apr 15:30 0.00 0.00 9.00 7.75 24.17 135.84 0.00 0.00 _ 03-Apr 16:00 Q00 0.00 10.00 8.25 20.83 156.67 0.00 0.00 , , 03-Apr 16:30 0.00 0.00 11.00 9.75 22.50 179.17 0.00 0.00 03-Apr 17:00 0.00 0.00 12.00 11.25 22.50 201.67 0.00 0.00 03-Apr 17:30 0.00 0.00 14.00 0.50 22.08 223.75 0.00 0,~ 03-Apr 18:00 0.00 0.00 15.00 1.50 21.67 245.42 0.00 it 03-Apr 18:30 0.00 0.00 16.00 2.25 21.25 266.67 1.00 7.50 0.00 0.00 03-Apr 19:00 0.00 0.00 0.00 2.00 9.50 23.33 23.33 0,00 03-Apr 19:30 0.00 0.00 0.00 3.00 11.25 22.92 46.25 0.00 03-Apr 20:00 0.00 0.00 0.00 5.00 1.00 22.92 69.17 0.00 03-Apr 20:30 0.00 0.00 0.00 6.00 2.25 22.08 91.25 0.00 03-Apr 21'00 0.00 0.00 0.00 7.00 2.50 20.42 111.67 0.00 03-Apr 21:30 0.00 0.00 0.00 8.00 6.00 25.83 137.50 0.00 03-Apr 22:00 0.00 0.00 0.00 9.00 6.00 20.00 157.50 0.00 Page no: 6.1.7 Ptfrac / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve No.1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 ,, Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (fl:.) (in.) (bbls) 'i)''~ 03-Apr 22:30 0.00 0.00 0.00 10.00 9.25 25.42 182.92 0.00 , , 03-A@r 23:00 0.00 0.00 0.00 11.00 10.25 21.67 204.59 0;00 , , 03-Apr 23:30 Q00 0.00 0.00 12.00 11.00' 21.25 225.84 0.00 , ,, 04-Apr 0:00 0.00 0.00 0.00 14.00 1.00 23.33 249,17 0.00 ..... 04~Apr 0:30 0.00 0.00 0.00 15.00 1.00 20.00 269.17 0.00, 04-Apr 1:00 0.00 0.00 1.00 8.00 0.00 16.00 1.50 20.83 290.01 0.00 , ,,, ....... 04-Apr 1:30 0,00 0.00 2.00 10.00 23.33 23.33 0.00 0.00 04-Apr 2:00 0.00 0.00 4.00 0.50 24.17 47.50 0.00 0.00 04-Apr 2:30 0.00 0.00 5.00 2.00 22.50 70.00 0.00 0.00 04-Apr 3:00 0.00 0.00 6.00 4.50 24.17 94.17 0.00 .,i~ 04-Apr 3:30 0.00 0.00 7.00 5.75 22.08 116.25 0.00 0,00 04-Apr 4:00 0.00 0.00 8.00 7.00 22.08 138.34 0.00 0.00 04-Apr 4:30 0.00 0.00 9.00 8.50 22.50 160.84 0.00 0.00 04-Apr 5:00 0.00 0.00 10.00 10.25 22.92 183.75 0.00 0.00 .. 04-Apr 5:30 0.00 0.00 11.00 11.75 22.50 206.25 0.00 0.00 04-Apr 6:00 0.00 0.00 13.00 0.50 21.25 227.50 0.00 0.00 04-Apr 7:00 0.00 0.00 15.00 5.25 47.92 275.42 3.00 0.25 0.00 0.00 04-Apr 8:00 0,00 0.00 0.00 5,00 3.00 44,58 44.58 0.00 , Page no' 6.1.8 Ptfrac / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Neve No, 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 , Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (lt.) (in.) (bbls) 04-Apr 9:00 0.00 0.00 0.00 7.00 6.75 46.25 90.84 0.00 , 04-Apr 10:00 0.00 0.00 0.00 9.00 9.25 44.17 135,00 0.00 04-Apr 11:00 0.00 0.00 0.00 12,00 3.00 49.58 184.59 0.00 04-Apr 12:00 0.00 0.00 0.00 14.00 4.25 42.08 226.67 0.00 , , 04-Apr 13:00 0.00 0.00 2.00 0.25 0.00 16.00 7.25 45.00 271.67 0.00 04-Apr 14:00 0.00 0.00 4.00 3.25 45.00 45.00 0.00 0.00 04-Apr 15:00 0.00 0.00 6.00 9.00 49.58 94.59 0.00 04-Apr 16:00 0.00 0.00 8.00 11.50 44.17 138.75 0.00 0.00 04-Apr 17:00 0.00 0.00 11.00 3.00 45.83 184.59 0.00 0.00 04-Apr 18:00 0.00 0.00 13.00 6.25 45.42 230.00 0.00 04-Apr 19:00 0.00 0.00 15.00 8.75 44.17 274.17 3.00 3.00 0.00 0.00 04-Apr 20:00 0,00 0.00 0.00 6.00 5.75 64.58 64.58 0.00 04-Apr 21:00 0,00 0.00 0.00 8.00 1.50 32.92 97.50 0.00 04-Apr 22:00 0.00 0.00 0.00 10.00 2.25 41.25 138.75 0.00 04-Apr 23:00 0.00 0.00 0.00 12.00 6.25 46.67 185.42 0.00 ,.. 05-Apr 0:00 0.00 0.00 0.00 14.00 11.00 47.92 233.34 0.00 05-Apr 1'00 0.00 0.00 1.00 0.75 0.00 17.00 1.25 43.75 277.09 0.00 .. 05-Apr 2:00 0.00 0.00 3.00 5.75 48.33 48.33 0.00 0.00 Page no: 6,1.9 Ptfrac / Tank Farm 1 thru 5 Company: ARCO Alaska, INC. Well Number: Neve No.1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 i Date/Time Tank No. 1 Tank No, 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ff.) (in.) (bbls) 05-Apr 3:00 0,00 0.00 5.00 10.25 47.50 95.84 Q00 0.00 05-Apr 4:00 0.00 0.00 8.00 2.00 46.25 142.09 0.00 0.00 , 05-Apr 5:00 0.00 0.00 10.00 5.50 45.83 187.92 0.00 0.00 05-Apr 6:00 0,00 0.00 12.00 10.00 47,50 235,42 0.00 0.00 , 05-Apr 7:00 0.00 0,00 15.00 4.00 50.00 285.42 2.00 7.00 0.00 0.00 05-Apr 8:00 0.00 0.00 16.00 2.75 17.92 303.34 3.00 8.00 21.67 21.67 0,00 .... , _ 05-Apr 9:00 0.00 0.00 0.00 6.00 0.00 46.67 68.33 0.00 05-Apr 10:25 0.00 0.00 0.00 6.00 0.00 0.00 68.33 0.00 05-Apr 10:30 0.00 0.00 0.00 6.00 2.00 3,33 71.67 0.00 05-Apr 11:00 0.00 0.00 0.00 7.00 6.00 26.67 98.34 05-Apr 11:30 0.00 0.00 0.00 8.00 1.50 12.50 110.84 0.{30 __ 05-Apr 12:00 0.00 0.00 0.00 8.00 11.50 16.67 127.50 0.00 __ 05-Apr 12:30 0.00 0.00 0,00 10.00 2.25 24.58 152.09 0.00 05-Apr 13:00 0,00 0.00 0.00 11.00 0.25 16.67 168.75 0.00 05-Apr 13:30 0.00 0.00 0.00 12.00 7.00 31.25 200.00 0.00 05-Apr 14:00 0.00 0.00 5.00 0.00 12.00 8.50 2.50 202.50 0.00 05-Apr 14:30 0.00 0.00 5,00 0.00 0.00 0.00 0.00 05-Apr 15:00 0.00 0,00 1.00 1.75 14.58 14.58 0.00 0.00 Page no: 6.1.10 Ptfrac / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 , , Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot: (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (t,,~ 05-Apr 15:30 0.00 0.00 2.00 2.00 20.42 35.00 0.00 0.00 05-Apr 16:00 0.00 0,00 3.00 3.25 22.08 57.08 0.00 ', 0.00 05-Apr 16:30 0.00 0.00 4.00 6.00 24.58 81.67 0.00 , 0,00 , 05-Apr 17:00 0.00 0.00 5.00 7.25 22.08 103.75 0.00 0.00 05-Apr 17:30 0.00 0,00 7.00 1.50 30.42 134.17 0.00 0,00 05-Apr 18:00 0.00 0.00 8.00 3.25 22.92 157.09 0.00 0.00 r 05-Apr 18:30 0.00 0.00 9.00 7.00 26.25 183.34 0.00 0.00 05-Apr 19:00 0.00 0.00 10.00 8.00 21.67 205.00 0.00 0.00 05-Apr 19:30 0.00 0.00 11.00 11.50 25.83 230.84 0.00 0.00 05-Apr 20:00 0.00 0.00 13.00 3.00 25.83 256.67 0.00 6. ~ 05-Apr 20:30 0.00 0.00 14.00 5.25 23.75 280.42 0.00 0.00 05-Apr 21:00 0.00 0.00 15.00 5.75 20.83 301.26 9.50 0.00 0.00 ,, 05-Apr 21'30 0.00 0.00 0.00 2.00 1.50 26.67 26.67 0.00 05-Apr 22:00 0.00 0.00 0.00 3.00 3.25 22.92 49.58 0.00 05-Apr 22:30 0.00 0.00 0.00 4.00 5.00 22.92 72.50 0.00 05-Apr 23:00 0.00 0.00 0.00 5.00 9.00 26.67 99.17 0.00 ., 05-Apr 23:30 0.00 0.00 0.00 7.00 0.00 25.00 124.17 0.00 06-Apr 0:00 0.00 0.00 0.00 8.00 2.50 24.17 148.34 0.00 Page no: 6.1.11 Ptfrac / Tank Farm I thru 5 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. 1 Tank No. 2 Tank No. 3 Tank No. 4 Tank No./5 .... Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cur,, Tot (dd-mmm hh:mm) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) 06-Apr 0:30 0.00 0.00 0.00 9.00 4.50 23.33 171.67 0.00 , , 06-A@r 1:00 0.00 0.00 0.00 10.00 8.00 25.83 197.50 0.00 ,, , 06-Apr 1:30 0.00 0.00 0.00 11.00 10.75 24.58 222.09 0.00 ..... 06-Apr 2:00 0.00 0.00 0.00 =13.00 0.75 23.33 245.42 0.00 06-Apr 2:30 0.00 0.00 0.00 14.00 4.25 25.83 271.26 0.00 06-Apr 3:00 0.00 0.00 0.00 15.00 5.25 21.67 292.92 0.00 06-Apr 3:30 0.00 0.00 1.00 0.00 16.00 6.50 22.08 315.01 0.00 06-Apr 4:00 0.00 0.00 2.00 3.75 26.25 26.25 0.00 0.00 06-Apr 4:30 0.00 0.00 3.00 7.50 26.25 52.50 0.00 0 06-Apr 5:00 0.00 0.00 4.00 8.75 22.08 74.58 0.00 06-Apr 5:30 0.00 0.00 5.00 11.25 24.17 98.75 0.00 0.00 06-Apr 6:00 0.00 0.00 7.00 1.00 22.92 121.67 0.00 0.00 06-Apr 6:30 0.00 0.00 8.00 5.00 26.67 148.34 0.00 0.00 06-Apr 7:00 0.00 0.00 9.00 6.00 21.67 170.00 0.00 0.00 06-Apr 7:30 0.00 0.00 10.00 9.75 26.25 196.25 0.00 0.00 06-Apr 8:00 0.00 0.00 11.00 11.50 22.92 219.17 0.00 0.00 06-Apr 8:30 0.00 0.00 13.00 2.50 25.00 244.17 0.00 0.00 06-Apr 9:00 0.00 0.00 14.00 5.75 25.42 269.59 0.00 0.00 , Page no: 6.1.12 Ptfrac / Tank Farm I thru 5 Company: ARCO Alaska, INC, Well Number: Neve No.1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date/Time Tank No. I Tank No. 2 Tank No. 3 Tank No. 4 Tank No. 5 Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot Inc. Cum Tot (dd-mmm hh:mm) (ff,) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft.) (in.) (bbls) (bbl) (ft,) (in,) (bbls) t,. ~ i i ii i i i i 06-Apr 9:30 0.00 0.00 15.00 7.25 22.50 292.09 0,00 0.00 06-Apr 10:00 0.00 0.00 16.00 9.75 24.17 316.26 2.00 2.00 0.00 0.00 06-Apr 10:30 0.00 0.00 0.00 3.00 5.00 25.00 25.00 0.00 06-Apr 11:00 0.00 0.00 0.00 4.00 7.50 24.17 49.17 0.00 06-Apr 11:30 0.00 0,00 0,00 5.00 10.00 24.17 73.33 0.00 06-Apr 12:00 0.00 0.00 0.00 7.00 1.25 25.42 98.75 0.00 I, 06-Apr 12:30 0.00 0.00 0.00 8.00 3.00 22.92 121.67 0.00 ,, 06-Apr 13:00 0.00 0.00 0.00 9.00 5.50 24.17 145.84 0.00 06-Apr 14:30 0.00 0.00 0.00 22.00 0.00 ,, ~ Post-Flow Strap 8.00 13.33 9.00 15.00 5.00 8.33 6.50 10.83 4.00 6.67 Page no: 6.1.13 Ptfrac / Tank Farm I thru 5 This Section Left Intentionally Blank. Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ro'n Cookson Company Rep: Scott Weimer Tank Coefficient: N/A Date/Time Frac I Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) Pre-Flow Strap 10.00 0.00 26.00 , , 29-Mar-96 0:34 ,, 29-Mar-96 0:54 10.00 20.00 0.00 0.00 , , 29-Mar-96 1:18 4.00 24.00 0.00 0.00 , 29-Mar-96 1:45 4.00 28.00 0.00 0.00 29-Mar-96 2:03 2.00 30.00 0.00 0.00 29-Mar-96 2:45 1.50 31.50 0.00 0.00 29-Mar-96 4:00 6.50 38.00 0.00 0.00 29-Mar-96 6:20 9.00 47.00 0.00 0.00 29-Mar-96 6:50 1.00 48.00 0.00 0.00 29-Mar-96 7:20 1.00 49.00 0.00 0.00 29-Mar-96 7:50 1.00 50.00 0.00 0.00 29-Mar-96 8:20 1.00 51.00 0.00 0.00 29-Mar-96 8:50 1.00 52.00 0.00 0.00 29-Mar-96 9:30 0.00 52.00 0.00 0.00 29-Mar~96 10:30 0.00 52.00 0.00 0.00 Page no: 6.3.1 Ptfrac / Tank Farm Frac 1 thru 3 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: N/A Date/Time Frac 1 Frac 2 Frac 3 , ............ Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) 29-Mar-96 11'30 0.50 52.50 0.00 0.00 ..... 29-Mar-96 12:30 0,00 52.50 0.00 0.00 29-Mar-96 13:30 0.50 53,00 0.00 0.00 . , , 29-Mar-96 14:30 1,00 54.00 0.00 0.00 , ,, 29-Mar-96 15:30 1.00 55.00 0.00 0.00 29-Mar-96 16:30 1.00 56.00 0.00 0.00 29-Mar-96 17:30 1.00 57.00 0.00 0.00 29-Mar-96 18:30 1.00 58.00 0.00 0.00 29-Mar-96 19:30 1.00 59.00 0.00 0.00 29-Mar-96 20:30 1,00 60.00 0.00 0.00 29-Mar-96 21:30 0.50 60.50 0.00 0.00 29-Mar-96 22:30 0.50 61.00 0.00 0.00 29-Mar-96 23:30 0.50 61.50 0.00 0.00 30-Mar-96 2:00 0.50 62.00 0.00 0.00 30-Mar-96 3:00 0.50 62.50 0.00 0.00 30-Mar-96 4:00 0.50 63.00 0.00 0.00 30-Mar-96 5:00 0.00 63.00 0.00 0.00 Page no: 6.3.2 Ptfrac / Tank Farm Frac 1 thru 3 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: N/A Date/Time Frac 1 Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) I i i i i i i i i iii i I ii 30-Mar-96 6:00 0.00 63.00 0.00 0.00 , , , ,, ,, ,,,, ,, 30-Mar-96 7:00 0.00 63.00 0.00 Q00 ,, ,, , , 30-Mar-96 8:00 0.00 63.00 0.00 0.00 30-Mar-96 9:00 0.00 63.00 0.00 0.00 30-Mar-96 10:00 0.00 63.00 0.00 0.00 30-Mar-96 11:00 0.00 63.00 0.00 0.00 30-Mar-96 11:30 0,00 63.00 0.00 0.00 , 31-Mar-96 6:15 0.00 63.00 0.00 0.00 31oMar-96 6:35 4.00 67.00 0.00 0.00 31-Mar-96 7:00 15.00 82.00 0.00 0.00 31-Mar-96 7:30 5.00 87.00 0.00 0.00 31-Mar-96 8:10 15.00 10200 0.00 0.00 31-Mar-96 8:35 10.00 112.00 0.00 0.00 31-Mar-96 9:00 15,00 127.00 0.00 0.00 31-Mar-96 9:30 8.00 135.00 0.00 0.00 31 -Mar-96 10:00 13.00 148 00 0.00 0.00 31-Mar-96 10:30 17.00 165.00 0.00 0.00 Page no: 6.3,3 Ptfrac / Tank Farm Frac 1 thru 3 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: R0n Cookson Company Rep: Scott Weimer Tank Coefficient: N/A Date/Time Frac 1 Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) 31-Mar-96 11:00 14.00 179.00 0.00 0.00 31-Mar-96 11:32 14.00 193.00 0.00 0.00 , 31-Mar-96 11:45 7.00 200.00 0.00 0.00 , , , , , 31-Mar-96 12:00 10.00 210.00 0.00 0.00 31-Mar-96 13:00 20.00 230.00 0,00 0.00 31-Mar-96 13:30 20.00 250.00 0.00 0.00 ,,, 31-Mar-96 14:00 20.00 270.00 0.00 0.00 ,,, 31-Mar-96 14:30 13.00 283.00 0.00 0.00 31-Mar-96 15:00 16.00 299.00 0.00 0.00 31-Mar-96 15:30 11.00 310.00 0.00 0.00 31-Mar-96 16:00 15.00 325.00 0.00 0.00 , 31-Mar-96 16:30 15.00 340.00 0.00 0.00 31-Mar-96 17:00 12.00 352.00 0.00 0.00 31-Mar-96 17:30 18.00 370.00 0.00 0.00 31-Mar~96 18:00 10.00 380.00 0.00 0.00 31-Mar-96 18:30 0.00 380.00 0.00 0.00 31-Mar-96 19:15 13.00 393.00 0.00 0.00 Page no: 6.3.4 Ptfrac / Tank Farm Frac I thru 3 Company: ARCO Alaska, INC. Well Number: Neve No. 1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: N/A Date/Time Frac 1 Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) iii i 31-Mar-96 19:25 10.00 403.00 0.00 0.00 31-Mar-96 20:00 15.00 418.00 0.00 0.00 , ,, 31-Mar-96 20:30 12.00 430.00 0.00 0.00 ......... 31-Mar-96 21:00 13.00 443.00 0.00 0.00 ,, ,, ,, 31-Mar-96 21:30 0.00 0.00 16.00 16.00 31-Mar-96 22:00 0.00 0.00 7.30 23.30 31-Mar-96 22:30 0.00 0.00 15.20 38.50 31-Mar-96 23:00 0.00 0.00 19.00 57.50 31-Mar-96 23:21 0.00 0.00 12.00 69.50 01-Apr-96 0:00 0.00 0.00 19.00 88.50 01-Apr-96 0:30 0.00 0.00 17.10 105.60 01-Apr-96 1:00 0.00 0.00 9.80 115.40 01-Apr-96 1'30 0.00 0.00 18.70 134.10 01-Apr-96 2:00 0.00 0.00 19.00 153.10 01-Apr-96 2:30 0.00 0.00 13.20 166.30 01-Apr-96 3:00 0.00 0.00 15.20 181.50 01-Apr-96 3:30 0.00 0.00 29.50 211.00 Page no: 6.3.5 Ptfrac / Tank Farm Frac 1 thru 3 Company: ARCO Alaska, INC. Well Number: Neve No.1 Test Number: Post Frac Flow Halliburton Energy Services Tank Farm Strap Sheet HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: N/A Date/Time Frac I Frac 2 Frac 3 Inc. Inc Tot Inc. Inc Tot Inc. Inc Tot (mm/dd/yy hh:mm) (bbls) (bbl) (bbls) (bbl) (bbls) (bbl) 0 l-Apr-96 4:00 0.00 0.00 18.60 229.60 01-Apr-96 4:30 0.00 0.00 14.50 244.10 01-Apr-96 5:00 0.00 0.00 14.50 258.60 01-Apr-96 5:40 0.00 0.00 18.60 277.20 01-Apr-96 6:00 0.00 0.00 12.40 289.60 01-Apr-96 7:00 0.00 0.00 31.00 320.60 01-Apr-96 8:30 0.00 0.00 56.90 377.50 , Post Flow Strap 10.00 0.00 8.30 Page no: 6.3.6 Ptfrac / Tank Farm Frac 1 thru 3 Halliburton Energy Services Tank Farm Transfer Sheet Company: ARCO Alaska, INC. Well Number: Neve No.1 Test Number: Post Frac Flow HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date / Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred Volumn (dd-mmm hh:mm) (ft) (in) (bbls) (fi) (in) (bbls) (bbt) (bbl) 29--Mar 4:00 143-014 Fracl 38.00 38.00 30-Mar 13:30 Fracl 25.00 63.00 31-Mar 3:00 Fracl 81.00 144.00 31-Mar 11:30 Fracl 124.00 268.00 31-Mar 23:00 Fracl 290.00 558.00 01-Apr 8:00 Frac3 290.00 848.00 01-Apr 16:00 2018 Frac3 60.00 908.00 01-Apr 16:00 2018 4 9.00 7.00 191.67 9.50 15.83 175.84 1083.84 01-Apr 16:00 2018 3 3.00 60.00 6.00 10.00 50.00 1133.84 02-Apr 1:30 2018 4 10.00 8.25 213.75 6.00 10.00 203.75 1337.59 02-Apr 1:30 2018 3 6.00 1.00 121.67 2.00 40.00 81.67 1419.26 02-Apr 9:15 2018 3 2.00 2.00 43.33 9.00 15.00 28.33 1447.59 02-Apr 9:15 2018 4 14.00 3.00 285.01 11.75 19.58 265.42 1713.02 02-Apr 18:00 2018 3 14.00 280.01 5.25 8.75 271.26 1984.27 03-Apr 0:30 2018 4 15.00 4.50 307.51 9.00 15.00 292.51 2276.78 03-Apr 9:00 2005 3 16.00 1.00 321.67 2.00 10.25 57.08 264.59 2541.37 03-Apr 16:00 2018 4 16.00 2.25 323.76 1.00 7.50 32.50 291 26 2832.62 03-Apr 21:30 2018 3 16.00 2.25 323.76 1.00 8.00 33.33 290.42 3123.04 04-Apr 4:00 2005 4 16.00 1.50 322.51 3.00 0.25 60.42 262.09 3385.13 04-Apr 9:30 2005 3 15.00 5.25 308.76 2.00 0.25 40,42 268.34 3653.47 04-Apr 14:20 2005 4 16.00 7.25 332.09 3.00 3.00 65.00 267.09 3920.56 04-Apr 22:30 2018 3 15.00 8.75 314.59 1.00 0.75 21.25 293.34 4213.90 05-Apr 4:00 2018 4 17.00 1.25 342.09 2.00 7.00 51.67 290.42 4504.32 05-Apr 10:00 2018 3 16.00 2.75 324.59 1.00 10.25 37.08 287,51 4791.83 05-Apr 16:00 2018 3 1.00 10.25 37.08 5.00 8.33 28.75 4820.58 05-Apr 16:00 2018 4 12.00 8.50 254.17 9.50 15.83 238.34 5058.92 06-Apr 0:00 2018 3 15.00 5.75 309.59 1.00 20.00 289.59 5348.51 06-Apr 5:30 2018 4 16.00 6.50 330.84 2.00 2.00 43.33 287.51 5636.01 06-Apr 16:00 2018 3 16.00 9.75 336.26 7.00 11.00 158.34 177.92 5813.93 , , Page 7.1 Ptfrac / Tank Transfer Data Halliburton Energy Services Tank Farm Transfer Sheet Company: ARCO Alaska, INC. Well Number: Neve No.1 Test Number: Post Frac Flow HES Rep: Ron Cookson Company Rep: Scott Weimer Tank Coefficient: 1.6667 Date / Time Truck Tank Starting Strap Ending Strap Vol Cum Number Number Transferred ¥olumn (dd-mmm hh:mm) (ft) (in) (bbls) {ft) (in) (bbls) (bbl) (bbl) 06-Apr 23:00 2005 5 6.00 10.00 4.00 6.67 3.33 5817.26 06-Apr 23:00 2005 4 10.00 2.75 204.59 6.50 10.83 193.75 6011.02 07-Apr 15:00 2005 3 8.00 0.25 160.42 5.00 8.33 152.09 6163.11 07-Apr 15:00 2005 2 9.00 15.00 9.00 15.00 0.00 6163.11 07-Apr 15:00 2005 1 8.00 13.33 8.00 13.33 0.00 6163.11 , ,, Page 7.2 Ptfrac / Tank Transfer Data Halliburton Energy Services Tank Farm Totals Summary Company: ARCO Alaska, INC. H.E.S. Rep: Ron Cookson Well Number: Neve No.1 Company Rep: Scott Weimer Test Number: Post Frac Flow Tank Coefficient: 1.6667 Date / Time Tank Pre-Flow Total Flow Total Vacuum Post-Vac Volume3 Number Volume (A) Volume (B) Volume (C) Volume (D) (A+B)-(C+D) (dd-mm-yy hh:mm) (bbl) (bbl) (bbl) (bbl) (bbl) 08-Mar-96 10:00 1 8.33 0.00 0.00 13.33 (5.00) 08-Mar-96 10:00 2 12.50 0.00 0.00 15.00 (2.50) 08-Mar-96 10:00 3 6.67 2479.63 2483.80 8.33 (5.83) 08-Mar-96 10:00 4 15.00 2772.06 2767.97 10.83 8.25 08-Mar-96 10:00 5 7.50 0.00 3.33 6.67 (2.50) 6 0.00 0.00 0.00 0.00 0.00 7 0.00 0.00 0.00 0.00 0.00 8 0.00 0.00 0.00 0.00 0.00 9 0.00 0.00 0.00 0.00 0.00 10 0.00 0.00 0.00 0.00 0.00 08-Mar-96 10:00 Fracl 10.00 554.00 558.00 10.00 (4.00) Frac2 0.00 0.00 0.00 0.00 0.00 08-Mar-96 10:00 Frac3 26.00 377.50 350.00 8.30 45.20 Fluid Splits At Recorded Conditions To Correlate To Tank Volumes. Oil (bbl) 5334.10 Fluid Split Water2 (bbl) 6191.72 536.62 Diesel1 (bbl) 321.00 Notes: ~ Estimated By Customer. 2 Includes solids and gel fluids.(BS&W) 3 Volume Difference Due To Measurment, Expansion or Contraction of Fluids. Page 8.1 Ptfrac/Tank Farm Summary X Pressure;/Temperc]ture, ,~st0ry 4.0 2.ok_ 1..0¢ ? · i Test No: Gauge No: Well No: Neve Company: r ........ -T ................. T~ ........ T ........ 1- ......... r .......... ~T Two 10220 T J ~ 0.0 L ........... L.'_ ....... ~ ............. J. ........... ~- .............. 0 0 0)> O::;U ::::CIO ! _L ........... 1. .L .......... ! ........... !. ARCO Pressure Vs Delta Time X 3.0 2.6 2.2 1.8 1.0 ,.o. Two 10220 Test .No; Gauge No: PeriSd No: ,.J" : !Well:. Neve 3 · ' j Compqny: ARCO Alaska J-' ~ , Anal~sf~ RAR [ LJ_L_iL ' ' LLI I '.J.. L l [~L~J...J..~LL.J....L_L I___l _[_L.I..LLL I [.IiI ~,,,,~.~.~.~Lu_[, ~ ~, ,,,, ,_,,,.:,I_LI_ L[J L...L~LL ! I I J -30.0 0.0 50.0 60.0 90.0 120.0 150.0 180.0 2!0.0 2~0.0 Delt~ Time (hours) Dr~wdown/Buildup Date: 28-Mar-96 Ticket No: 693463 Test Period Summary Page No: 2.1 Gauge No.: 10220 / 20223 Period Time 1 5-Apr-96 12:53:14 5-Apr-96 14:41:10 2 5-Apr-96 14:41:10 6-Apr-96 13:04:28 3 6-Apr-96 13:04:28 13-Apr-96 09:03:40 4 13-Apr-96 09:03:40 13-Apr-96 10:15:40 Description Start W/L Operations End W/L Operations Start Draw-down End Draw-down Start Build-up End Build-up Start W/L Operations End W/L Operations Pressure (psi) 16.095 2988.07 2988.07 1067.47 1067.47 3197.39 3197.39 16.183 Depth: 7113.72 ft Duration (hrs) 1.79 1343.30 9839.20 1.18 Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 693463 Pressure vs Time Page No: 2.1.1 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) Comments 5-Apr-96 12:53:14 13:04:10 13:15:10 13:25:10 13:36:10 13:39:10 13:46:10 13:51:10 13:55:10 13:58:10 14:01:10 14:04:10 14:07:10 14:09:10 14:11:10 14:15:10 14:25:10 14:36:10 16.095 15.946 16.079 15.320 6.700 257.812 463.194 691.031 934.751 1149.479 1395.487 1670.419 1967.923 2170.994 2378.542 2627.127 2840.895 2969.450 68.620 68.946 69.200 64.027 47.721 47.393 71.038 87.948 101.922 112.485 122.679 133.486 143.896 150.164 155.755 162.539 163.823 163.598 W/L Operations Date: 28-Mar-96 Ticket No: 693463 Page No: 2.1.2 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 5-Apr-96 Start Period 1 14:41:10 0.0000 2988.074 163.436 14:42:10 0.0167 2963.724 163.403 14:43:10 0.0333 2908.310 163.288 14:44:10 0.0500 2862.285 163.173 14:45:10 0.0667 2810.332 163.062 14:46:10 0.0833 2768.032 162.951 14:47:10 0.1000 2731.835 162.952 14:49:10 0.1333 2677.575 162.954 14:51:10 0.1667 2641.521 162.940 14:53:10 0.2000 2574.893 162.912 14:54:10 0.2167 2521.316 162.860 14:55:10 0.2333 2478.715 162.808 14:56:10 0.2500 2448.304 162.756 14:58:10 0.2833 2409.812 162.754 15:02:10 0.3500 2376.116 162.806 15:07:10 0.4333 2344.633 162.894 15:09:10 0.4667 2295.583 162.929 15:11:10 0.5000 2257.160 162.909 15:14:10 O. 5500 2216.499 162.880 15:18:10 0.6167 2181.815 162.840 15:21:10 0.6667 2140.178 162.810 15:23:10 0.7000 2106.602 162.790 15:26:10 0.7500 2065.568 162.770 15:29:10 0.8000 2034.882 162.756 15:34:10 0.8833 1990.798 162.748 15:36:10 0.9167 1958.869 162.745 15:39:10 0.9667 1920.239 162.727 15:43:10 1.0333 1883.633 162.744 15:49:10 1.1333 1852.251 162.830 15:55:10 1.2333 1836.474 162.917 16:01:10 1.3333 1832.996 163.005 16:07:10 1.4333 1830.780 163.069 16:13:10 1.5333 1794.829 163.054 16:15:10 1.5667 1754.907 162.960 16:17:10 1.6000 1721.259 162.866 16:19:10 1.6333 1691.225 162.836 16:22:10 1.6833 1657.200 162.806 16:26:10 1.7500 1622.923 162.806 16:31:10 1.8333 1600.296 162.814 16:37:10 1.9333 1595.380 162.867 16:43:10 2.0333 1605.493 162.920 16:49:10 2.1333 1615.262 162.973 16:52:10 2.1833 1584.749 162.919 16:54:10 2.2167 1545.552 162.820 16:56:10 2.2500 1511.497 162.721 Comments Drawdown Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.3 Halliburton Gauge No.' 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 5-Apr-96 16:58:10 2.2833 1481.209 ~ ~, 17:01:10 2.3333 1442.022 17:04:10 2.3833 1410.547 17:08:10 2.4500 1375.995 17:13:10 2.5333 1350.093 r_ 17:19:10 2.6333 1326.844 17:25:10 2.7333 1308.893 17:31:10 2.8333 1276.654 17:37:10 2.9333 1240.916 17:43:10 3.0333 1218.199 17:49:10 3.1333 1203.533 17:55:10 3.2333 1194.287 ~--- 18:01:10 3.3333 1163.907 18:07:10 3.4333 1131.326 18:13:10 3.5333 1113.772 18:19:10 3.6333 1104.711 18:25:10 3.7333 1098.187 18:31:10 3.8333 1093.601 18:37:10 3.9333 1089.743 ,-~ 18:43:10 4.0333 1089.531 18:49:10 4.1333 1089.888 18:55:10 4.2333 1089.246 19:01:10 4.3333 1089.355 19:07:10 4.4333 1088.039 19:13:10 4.5333 1088.445 19:19:10 4.6333 1087.388 ~-. 19:25:10 4.7333 1086.735 19:31:10 4.8333 1086.172 19:37:10 4.9333 1087.098 19:43:10 5.0333 1084.906 19:49:10 5.1333 1083.872 19:55:10 5.2333 1083.077 20:01:10 5.3333 1082.972 ~ ~ 20:07:10 5.4333 1081.734 20:13:10 5.5333 1082.037 20:19:10 5.6333 1082.068 20:25:10 5.7333 1080.861 20:31:10 5.8333 1082.051 20:37:10 5.9333 1081.098 20:43:10 6.0333 1079.455 ~-- 20:49:10 6.1333 1078.448 20:55:10 6.2333 1078.71 9 21:01:10 6.3333 1078.575 21:07:10 6.4333 1078.312 21:13:10 6.5333 1079.364 21:19:10 6.6333 1081.536 Comments 162.623 162.537 162.482 162.444 162.411 162.375 162.339 162.255 162.137 162.077 162.019 161.965 161.881 161.739 161.685 161.648 161.612 161.575 161.539 161.513 161.500 161.486 161.473 161.459 161.445 161.432 161.421 161.409 161.402 161.395 161.389 161.383 161.377 161.371 161.365 161.359 161.353 161.348 161.342 161.336 161.332 161.331 161.330 161.329 161.328 161.329 Date: 28~Mar-96 Ticket No: 69346 Page No: 2.1.4 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 5-Apr-96 21:25:10 6.7333 1081.628 21:31:10 6.8333 1081.911 21:37:10 6.9333 1082.177 21:43:10 7.0333 1082.541 21:49:10 7.1333 1082.926 21:55:10 7.2333 1083.393 22:01:10 7.3333 1083.362 22:07:10 7.4333 1082.945 22:13:10 7.5333 1083.064 22:19:10 7.6333 1082.654 22:25:10 7.7333 1082.975 22:31:10 7.8333 1083.416 22:37:10 7.9333 1083.297 22:43:10 8.0333 1082.910 22:49:10 8.1333 1082.742 22:55:10 8.2333 1082.397 23:01:10 8.3333 1082.298 23:07:10 8.4333 1079.817 23:13:10 8.5333 1080.244 23:19:10 8.6333 1079.918 23:25:10 8.7333 1078.520 23:31:10 8.8333 1077.982 23:37:10 8.9333 1078.063 23:43:10 9.0333 1078.377 23:49:10 9.1333 1079.173 23:55:10 9.2333 1079.448 6-Apr-96 00:01:10 9.3333 1079.390 00:07:10 9.4333 1079.485 00:13:10 9.5333 1079.405 00:19:10 9.6333 1079.170 00:25:10 9.7333 1078.922 00:31:10 9.8333 1079.122 00:37:10 9.9333 1078.618 00:43:10 10.0333 1077.437 00:49:10 10.1333 1074.985 00:55:10 10.2333 1074.045 01:01:10 10.3333 1073.523 01:07:10 10.4333 1072.765 01:13:10 10.5333 1072.583 01:19:10 10.6333 1072.374 01:25:10 10.7333 1072.102 01:31:10 10.8333 1072.039 01:37:10 10.9333 1072.366 01:43:10 11.0333 1072.256 01:49:10 11.1 333 1071.892 Comments 161.330 161.331 161.332 161.333 161.334 161.333 161.331 161.331 161.331 161.331 161.330 161.331 161.332 161.331 161.328 161.325 161.323 161.320 161.317 161.315 161.312 161.310 161.311 161.311 161.312 161.313 161.314 161.315 161.315 161.313 161.311 161.309 161.308 161.3O6 161.304 161.303 161.301 161.299 161.297 161.297 161.296 161.296 161.296 161.295 161.295 Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.5 Halliburton Gauge No.: 10220 Memory Recorder No.' 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 01:55:10 11.2333 1071.765 02:01:10 11.3333 1072.033 02:07:10 11.4333 1071.990 02:13:10 11.5333 1072.000 02:19:10 11.6333 1071.516 02:25:10 11.7333 1071.292 02:31:10 11.8333 1071.361 02:37:10 11.9333 1071.374 02:43:10 12.0333 1071.236 02:49:10 12.1333 1071.063 02:55:10 12.2333 1070.714 03:01:10 12.3333 1070.640 03:07:10 12.4333 1070.328 03:13:10 12.5333 1070.032 03:19:10 12.6333 1070.081 03:25:10 12.7333 1070.280 03:31:10 12.8333 1070.429 03:37:10 12.9333 1070.514 03:43:10 13.0333 1070.399 03:49:10 13.1333 1070.328 03:55:10 13.2333 1070.055 04:01:10 13.3333 1070.099 04:07:10 13.4333 1069.955 04:13:10 13.5333 1069.716 04:19:10 13.6333 1069.983 04:25:10 13.7333 1069.873 04:31:10 13.8333 1070.036 04:37:10 13.9333 1070.252 04:43:10 14.0333 1070.162 04:49:10 14.1333 1070.060 04:55:10 14.2333 1069.968 05:01:10 14.3333 1069.774 05:07:10 14.4333 1069.915 05:13:10 14.5333 1069.911 05:19:10 14.6333 1070.126 05:25:10 14.7333 1070.036 05:31:10 14.8333 1069.782 05:37:10 14.9333 1069.620 05:43:10 15.0333 1069.419 05:49:10 15.1333 1068.991 05:55:10 15.2333 1068.838 06:01:10 15.3333 1068.837 06:07:10 15.4333 1068.709 06:13:10 15.5333 1068.494 06:19:10 15.6333 1068.691 06:25:10 15.7333 1068.715 Comments 161.294 161.294 161.293 161.293 161.293 161.293 161.294 161.294 161.294 161.295 161.295 161.296 161.296 161.297 161.297 161.297 161.297 161.297 161.297 161.297 161.297 161.297 161.296 161.296 161.296 161.296 161.297 161.298 161.299 161.299 161.300 161.301 161.302 161.303 161.303 161.304 161.305 161.305 161.305 161.305 161.305 161.305 161.305 161.305 161.305 161.305 Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.6 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 06:31:10 15.8333 1068.579 06:37:10 15.9333 1068.313 06:43:10 16.0333 1067.984 06:49:10 16.1333 1067.766 06:55:10 16.2333 1067.842 07:01:10 16.3333 1067.966 07:07:10 16.4333 1068.258 07:13:10 16.5333 1068.590 07:19:10 16.6333 1068.491 07:25:10 16.7333 1068.398 07:31:10 16.8333 1068.351 07:37:10 16.9333 1068.412 07:43:10 17.0333 1068.715 07:49:10 17.1333 1068.765 07:55:10 17.2333 1068.716 08:01:10 17.3333 1068.456 08:07:10 17.4333 1068.635 08:13:10 17.5333 1069.154 08:19:10 17.6333 1067.734 08:25:10 17.7333 1067.561 08:31:10 17.8333 1067.585 08:37:10 17.9333 1067.773 08:43:10 18.0333 1067.682 08:49:10 18.1333 1067.790 08:55:10 18.2333 1067.818 09:01:10 18.3333 1067.719 09:07:10 18.4333 1067.691 09:13:10 18.5333 1067.843 09:19:10 18.6333 1068.077 09:25:10 18.7333 1068.106 09:31:10 18.8333 1067.868 09:37:10 18.9333 1067.692 09:43:10 19.0333 1067.600 09:49:10 19.1333 1067.354 09:55:10 19.2333 1067.523 10:01:10 19.3333 1067.585 10:07:10 19.4333 1067.617 10:13:10 19.5333 1067.364 10:19:10 19.6333 1067.079 10:25:10 19.7333 1066.965 10:31:10 19.8333 1066.813 10:37:10 19.9333 1067.204 10:43:10 20.0333 1067.368 10:49:10 20.1333 1067.249 10:55:10 20.2333 1067.152 11:01:10 20.3333 1067.401 Comments 161.305 161.305 161.306 161.306 161.307 161.307 161.308 161.308 161.309 161.310 161.310 161.311 161.312 161.312 161.313 161.314 161.315 161.316 161.316 161.317 161.318 161.319 161.319 161.320 161.320 161.320 161.321 161.321 161.321 161.322 161.322 161.322 161.323 161.323 161.324 161.325 161.325 161.326 161.327 161.328 161.328 161.329 161.330 161.330 161.331 161.332 Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Gauge Depth' Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 11:07:10 20.4333 1067.330 11:13:10 20.5333 1067.098 11:19:10 20.6333 1067.039 11:25:10 20.7333 1067.228 11:31:10 20.8333 1067.149 11:37:10 20.9333 1067.083 11:43:10 21.0333 1067.071 11:49:10 21.1333 1067.148 11:54:12 21.2172 1067.343 11:59:16 21.3017 1067.311 12:04:20 21.3861 1067.225 12:09:24 21.4706 1066.991 12:14:28 21.5550 1066.864 12:19:28 21.6383 1067.226 12:24:32 21.7228 1067.224 12:29:32 21.8061 1067.281 12:34:36 21.8906 1067.268 12:39:40 21.9750 1067.081 12:44:40 22.0583 1067.152 12:49:44 22.1428 1067.319 12:54:44 22.2261 1067.105 12:59:48 22.3106 1067.246 13:04:24 22.3872 1067.499 13:04:28 22.3883 1067.467 End of Period 1 161.333 161.334 161.335 161.336 161.337 161.338 161.339 161.340 161.341 161.336 161.336 161.339 161.337 161.339 161.335 161.338 161.336 161.340 161.342 161.338 161.341 161.343 161.365 161.366 Page No: 2.1.7 7113.72 ft Comments Date: 28-Mar-96 Ticket No' 69346 Page No: 2.1.8 Halliburton Gauge No.' 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm'ss) (hr) (psi) (F) 6-Apr-96 Start Period 2 13:04:36 0.0022 1115.734 161.367 13:04:40 0.0033 1146.565 161.368 13:04:44 0.0044 1177.279 161.392 13:04:48 0.0056 1208.136 161.416 13:04:52 0.0067 1239.286 161.440 13:04:56 0.0078 1270.738 161.464 13:05:00 0.0089 1302.482 161.488 13:05:04 0.0100 1334.324 161.539 13:05:08 0.0111 1366.375 161.590 13:05:12 0.0122 1398.564 161.641 13:05:16 0.0133 1430.980 161.693 13:05:20 0.0144 1463.773 161.771 13:05:24 0.0156 1496.812 161.850 13:05:28 0.0167 1530.182 161.928 13:05:32 0.0178 1563.708 162.007 13:05:36 0.0189 1597.623 162.085 13:05:40 0.0200 1631.774 162.184 13:05:44 0.0211 1666.127 162.283 13:05:48 0.0222 1700.840 162.382 13:05:52 0.0233 1735.691 162.481 13:05:56 0.0244 1770.748 162.580 13:06:00 0.0256 1805.764 162.678 13:06:04 0.0267 1841.188 162.777 13:06:08 0.0278 1876.935 162.876 13:06:12 0.0289 1912.848 162.980 13:06:16 0.0300 1947.714 163.083 13:06:20 0.0311 1985.326 163.186 13:06:24 0.0322 2026.174 163.290 13:06:28 0.0333 2074.256 163.393 13:06:32 0.0344 2132.817 163.497 13:06:36 0.0356 2195.978 163.600 13:06:40 0.0367 2260.845 163.704 13:06:44 0.0378 2323.874 163.807 13:06:48 0.0389 2378.299 163.911 13:06:52 0.0400 2422.411 164.014 13:06:56 0.0411 2458.056 164.118 13:07:00 0.0422 2487.478 164.221 13:07:04 0.0433 2512.624 164.324 13:07:08 0.0444 2535.011 164.428 13:07:12 0.0456 2555.053 164.531 13:07:20' 0.0478 2589.200 164.669 13:07:28 0.0500 2617.346 164.808 13:07:36 0.0522 2641.393 164.929 13:07:44 0.0544 2661.967 165.033 13:07:56 0.0578 2688.202 165.189 Comments Build Up Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Gauge Depth: Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 13:08:08 0.0611 2710.242 165.297 13:08:24 0.0656 2734.504 165.442 13:08:44 0.0711 2758.834 165.574 13:09:08 0.0778 2782.055 165.689 13:09:36 0.0856 2803.412 165.769 -- 13:10:12 0.0956 2824.669 165.818 13:11:00 0.1089 2845.971 165.839 13:12:04 0.1267 2866.555 165.821 13:13:36 0.1522 2886.839 165.734 13:15:08 0.1778 2901.133 165.592 13:16:40 0.2033 2911.867 165.420 13:18:12 0.2289 2920.307 165.232 ~-, 13:19:44 0.2544 2927.186 165.026 13:21:16 0.2800 2932.956 164.819 13:22:48 0.3056 2937.921 164.606 13:24:20 0.3311 2942.169 164.403 13:25:52 0.3567 2945.898 164.200 13:27:24 0.3822 2949.219 164.009 13:28:56 0.4078 2952.244 163.837 · ~ 13:30:28 0.4333 2955.018 163.665 13:32:00 0.4589 2957.527 163.497 13:33:32 0.4844 2959.873 163.333 13:35:04 0.5100 2962.068 163.169 -- 13:36:36 0.5356 2964.091 163.020 13:38:08 0.5611 2966.000 162.872 13:39:40 0.5867 2967.764 162.733 ~-~ 13:41:12 0.6122 2969.433 162.610 13:42:44 0.6378 2970.961 162.487 13:44:16 0.6633 2972.505 162.370 13:45:48 0.6889 2973.947 162.272 13:47:20 0.7144 2975.323 162.176 13:48:52 0.7400 2976.632 162.090 13:50:24 0.7656 2977.934 162.013 ~-- 13:51:56 0.7911 2979.169 161.939 13:53:28 0.8167 2980.325 161.865 13:55:00 0.8422 2981.451 161.798 13:56:32 0.8678 2982.574 161.737 ~-- 13:58:04 0.8933 2983.673 161.674 13:59:36 0.9189 2984.717 161.617 14:01:08 0.9444 2985.711 161.560 -- 14:02:40 0.9700 2986.677 161.504 14:04:12 0.9956 2987.619 161.455 14:05:44 1.0211 2988.571 161.405 14:07:16 1.0467 2989.492 161.360 -- 14:08:48 1.0722 2990.350 161.318 14:10:20 1.0978 2991.181 161.280 Page No: 2.1.9 7113.72 ft Comments Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Page No: 2.1.10 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 2992.032 2992.849 2993.651 2994.443 2995.206 2995.965 2996.733 2997.501 2998.186 2998.892 2999.591 3000.252 3000.901 3001.546 3002.206 3002.822 3003.436 3004.049 3004.615 3005.219 3005.797 3006.372 3006.935 3007.492 3008.027 3008.554 3009.102 3OO9.635 3010.159 3010.682 3011.165 3011.671 3012.154 3012.614 3013.086 3013.548 3014.011 3014.482 3014.932 3015.375 3015.829 3016.279 3016.696 3017.118 3017.544 3017.975 6-Apr-96 14:11:52 1.1233 14:13:24 1.1489 14:14:56 1.1744 14:16:28 1.2000 14:18:00 1.2256 14:19:32 1.2511 14:21:04 1.2767 14:22:36 1.3022 14:24:08 1.3278 14:25:40 1.3533 14:27:12 1.3789 14:28:44 1.4044 14:30:16 1.4300 14:31:48 1.4556 14:33:20 1.4811 14:34:52 1.5067 14:36:24 1.5322 14:37:56 1.5578 14:39:28 1.5833 14:41:00 1.6089 14:42:32 1.6344 14:44:04 1.6600 14:45:36 1.6856 14:47:08 1.7111 14:48:40 1.7367 14:50:12 1.7622 14:51:44 1.7878 14:53:16 1.8133 14:54:48 1.8389 14:56:20 1.8644 14:57:52 1.8900 14:59:24 1.91 56 15:00:56 1.9411 15:02:28 1.9667 15:04:00 1.9922 15:05:32 2.0178 15:07:04 2.0433 15:08:36 2.0689 15:10:08 2.0944 15:11:40 2.1200 15:13:12 2.1456 15:14:44 2.1711 15:16:16 2.1967 15:17:48 2.2222 15:19:20 2.2478 15:20:52 2.2733 Comments 161.241 161.207 161.173 161.144 161.116 161.089 161.062 161.036 161.011 160.989 160.967 160.944 160.923 160.901 160.879 160.858 160.838 160.820 160.803 160.786 160.767 160.749 160.732 160.718 160.701 160.684 160.667 160.654 160.640 160.625 160.611 160.597 160.585 160.571 160.556 160.542 160.527 160.514 160.501 160.488 160.473 160.464 160.449 160.434 160.420 160.409 Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Page No: 2.1.11 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 15:22:24 2.2989 3018.401 160.397 15:23:56 2.3244 3018.846 160.385 15:25:28 2.3500 3019.270 160.372 15:27:00 2.3756 3019.681 160.364 15:28:32 2.4011 3020.078 160.350 15:30:04 2.4267 3020.460 160.340 15:31:36 2.4522 3020.877 160.327 15:33:08 2.4778 3021.283 160.314 15:34:40 2.5033 3021.682 160.302 15:36:12 2.5289 3022.052 160.289 15:37:44 2.5544 3022.427 160.281 15:39:16 2.5800 3022.824 160.271 15:40:48 2.6056 3023.213 160.262 15:42:20 2.6311 3023.610 160.252 15:43:52 2.6567 3023.970 160.242 15:45:24 2.6822 3024.359 160.230 15:46:56 2.7078 3024.728 160.219 15:48:28 2.7333 3025.093 160.208 15:50:00 2.7589 3025.460 160.198 15:51:32 2.7844 3025.819 160.190 15:53:04 2.8100 3026.171 160.182 15:54:36 2.8356 3026.539 160.172 15:56:08 2.8611 3026.871 160.163 15:57:40 2.8867 3027.218 160.154 15:59:12 2.9122 3027.567 160.146 16:00:44 2.9378 3027.890 160.139 16:02:16 2.9633 3028.228 160.126 16:03:48 2.9889 3028.558 160.115 16:05:20 3.0144 3028.893 160.105 16:06:52 3.0400 3029.234 160.097 16:08:24 3.0656 3029.583 160.088 16:09:56 3.0911 3029.906 160.079 16:11:28 3.1167 3030.215 160.072 16:13:00 3.1422 3030.533 160.065 16:14:32 3.1678 3030.857 160.057 6:16:04 3.1933 3031.191 160.049 6:17:36 3.2189 3031.504 160.041 6:19:08 3.2444 3031.832 160.032 6:20:40 3.2700 3032.145 160.026 6:22:12 3.2956 3032.462 160.017 6:23:44 3.3211 3032.774 160.010 6:25:16 3.3467 3033.064 160.001 6:26:48 3.3722 3033.373 159.998 6:28:20 3.3978 3033.670 159.991 6:29:52 3.4233 3033.960 159.984 6:31:24 3.4489 3034.242 159.976 Comments Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.12 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth' 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 16:32:56 3.4744 3034.512 159.968 16:34:28 3.5000 3034.799 159.960 16:36:00 3.5256 3035.095 159.953 16:37:32 3.5511 3035.397 159.946 16:39:04 3.5767 3035.679 159.939 16:40:36 3.6022 3035.967 159.931 16:42:08 3.6278 3036.263 159.924 16:43:40 3.6533 3036.552 159.916 16:45:12 3.6789 3036.832 159.909 16:46:44 3.7044 3037.102 159.903 16:48:16 3.7300 3037.377 159.898 16:49:48 3.7556 3037.656 159.893 16:51:20 3.7811 3037.928 159.888 16:52:52 3.8067 3038.190 159.882 16:54:24 3.8322 3038.462 159.875 16:55:56 3.8578 3038.725 159.869 16:57:28 3.8833 3038.992 159.862 16:59:00 3.9089 3039.258 159.854 17:00:32 3.9344 3039.516 159.847 17:02:04 3.9600 3039.777 159.842 17:03:36 3.9856 3040.033 159.837 17:05:08 4.0111 3040.297 159.829 17:06:40 4.0367 3040.558 159.824 17:08:12 4.0622 3040.808 159.819 17:09:44 4.0878 3041.061 159.811 17:11:16 4.1133 3041.312 159.805 17:12:48 4.1389 3041.569 159.800 17:14:20 4.1644 3041.807 159.795 17:15:52 4.1900 3042.056 159.789 17:17:24 4.2156 3042.303 159.784 17:18:56 4.2411 3042.553 159.778 17:20:28 4.2667 3042.807 159.772 17:22:00 4.2922 3043.045 159.767 17:23:32 4.3178 3043.272 159.760 17:25:04 4.3433 3043.524 159.753 17:26:36 4.3689 3043.775 159.747 17:28:08 4.3944 3044.009 159.741 17:29:40 4.4200 3044.241 159.735 17:31:12 4.4456 3044.474 159.728 17:32:44 4.4711 3044.699 159.722 17:34:16 4.4967 3044.931 159.716 17:35:48 4.5222 3045.157 159.710 17:37:20 4.5478 3045.389 159.707 17:38:52 4.5733 3045.642 159.700 17:40:24 4.5989 3045.848 159.694 17:41:56 4.6244 3046.086 159.688 Comments Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.13 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 3046.325 3046.550 3046.782 3047.009 3047.230 3047.457 3O47.679 3047.894 3048.114 3048.328 3048.528 3048.736 3048.940 3049.152 3049.364 3049.565 3049.772 3049.986 3050.213 3050.415 3050.625 3050.822 3051.019 3051.217 3051.413 3051.608 3051,803 3052.003 3052.200 3052.397 3052.594 3052.796 3052.984 3053,178 3053.377 3053.577 3O53,76O 3053.949 3054.137 3054.334 3054.518 3054.703 3O54.878 3055.063 3055.247 3055.430 6-Apr-96 17:43:28 4.6500 17:45:00 4.6756 17:46:32 4.7011 17:48:04 4.7267 17:49:36 4.7522 17:51:08 4.7778 17:52:40 4.8033 17:54:12 4.8289 17:55:44 4.8544 17:57:16 4.8800 17:58:48 4.9056 18:00:20 4.9311 18:01:52 4.9567 18:03:24 4.9822 18:04:56 5.0078 18:06:28 5.0333 18:08:00 5.0589 18:09:32 5.0844 18:11:04 5.1100 18:12:36 5.1356 18:14:08 5.1611 18:15:40 5.1867 18:17:12 5.2122 18:18:44 5.2378 18:20:16 5.2633 18:21:48 5.2889 18:23:20 5.3144 18:24:52 5.3400 18:26:24 5.3656 18:27:56 5.3911 18:29:28 5.4167 18:31:00 5.4422 18:32:32 5.4678 18:34:04 5.4933 18:35:36 5.5189 18:37:08 5.5444 18:38:40 5.5700 18:40:12 5.5956 18:41:44 5.6211 18:43:16 5.6467 18:44:48 5.6722 18:46:20 5.6978 18:47:52 5.7233 18:49:24 5.7489 18:50:56 5.7744 18:52:28 5.8000 Comments 159.683 159.677 159.673 159.668 159.663 159.656 159.650 159.647 159.642 159.636 159.630 159.625 159.621 159.616 159.612 159.609 159.604 159.598 159.593 159.589 159.584 159.580 159.578 159.573 159.568 159.563 159.559 159.554 159.549 159.544 159.539 159.534 159.529 159.527 159.518 159.517 159.512 159.508 159.503 159.499 159.494 159.489 159.485 159.482 159.474 159.472 Date' 28-Mar-96 Ticket No: 69346 Page No: 2.1.14 Halliburton Gauge No.: 10220 Memory Recorder No.' 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 18:54:05 5.8269 3055.621 18:55:41 5.8536 3055.813 18:57:17 5.8803 3055.993 18:58:53 5.9069 3056.190 19:00:29 5.9336 3056.374 19:02:05 5.9603 3056.557 19:03:41 5.9869 3056.748 19:05:17 6.0136 3056.936 19:06:53 6.0403 3057.110 19:08:35 6.0686 3057.302 19:10:11 6.0953 3057.482 19:11:47 6.1219 3057.664 19:13'17 6.1469 3057.834 19:14:53 6.1736 3058.015 19:16:29 6.2003 3058.196 19:18:05 6.2269 3058.375 19:19:41 6.2536 3058.559 19:21:17 6.2803 3058.746 19:22:53 6.3069 3058.918 19:24:29 6.3336 3059.093 19:26:05 6.3603 3059.266 19:27:47 6.3886 3059.453 19:29:17 6.4136 3059.612 19:30:53 6.4403 3059.784 19:32:29 6.4669 3059.961 19:34:05 6.4936 3060.139 19:35:41 6.5203 3060.318 19:37:17 6.5469 3060.501 19:38:53 6.5736 3060.675 19:40:29 6.6003 3060.847 19:42:11 6.6286 3061.022 19:43:47 6.6553 3061.193 19:45:29 6.6836 3061.371 19:47:05 6.7103 3061.537 19:48:41 6.7369 3061.705 19:50:23 6.7653 3061.874 19:51:59 6.7919 3062.037 19:53:35 6.8186 3062.197 19:55:11 6.8453 3062.352 19:56:53 6.8736 3062.531 19:58:29 6.9003 3062.691 20:00:11 6.9286 3062.865 20:01:47 6.9553 3063.028 20:03:23 6.9819 3063.187 20:04:53 7.0069 3063.339 20:06:29 7.0336 3063.499 Comments 159.463 159.459 159.454 159.450 159.445 159.440 159.436 159.431 159.426 159.422 159.417 159.413 159.408 159.404 159.399 159.394 159.389 159.384 159.379 159.374 159.373 159.368 159.364 159.360 159.356 159.352 159.348 159.344 159.341 159.337 159.331 159.326 159.320 159.315 159.311 159.306 159.302 159.299 159.296 159.292 159.289 159.285 159.281 159.277 159.274 159.271 Date: 28-Mar-96 Ticket No: 69346 Page No' 2.1.15 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 6-Apr-96 20:08:11 7.0619 3063.342 20:09:47 7.0886 3063.644 20:11:23 7.1153 3063.838 20:12:59 7.1419 3064.004 20:14:35 7.1686 3064.097 20:16:11 7.1953 3064.330 20:17:47 7.2219 3064.493 20:19:23 7.2486 3064.652 20:20:59 7.2753 3064.802 20:22:35 7.3019 3064.962 20:24:05 7.3269 3065.099 20:25:41 7.3536 3065.258 20:27:17 7.3803 3065.399 20:28:47 7.4053 3065.541 20:30:23 7.4319 3065.695 20:31:59 7.4586 3065.852 20:33:35 7.4853 3065.983 20:35:11 7.5119 3066.140 20:36:47 7.5386 3066.297 20:38:29 7.5669 3066.459 20:40:05 7.5936 3066.607 20:41:41 7.6203 3066.751 20:43:23 7.6486 3066.904 20:44:59 7.6753 3067.050 20:46:35 7.7019 3067.200 20:48:17 7.7303 3067.363 20:49:53 7.7569 3067.508 20:51:29 7.7836 3067.659 20:53:05 7.8103 3067.814 20:54:35 7.8353 3067.944 20:56:17 7.8636 3068.089 20:57:59 7.8919 3068.249 20:59:41 7.9203 3068.401 21:01:17 7.9469 3068.548 21:02:53 7.9736 3068.691 21:04:35 8.0019 3068.838 21:06:11 8.0286 3068.978 21:07:47 8.0553 3069.121 21:09:23 8.0819 3069.272 21:10:59 8.1086 3069.415 21:12:35 8.1353 3069.542 21:14:17 8.1636 3069.694 21:15:53 8.1903 3069.827 21:17:29 8.2169 3069.960 21:19:11 8,2453 3070.095 21:20:47 8.2719 3070,247 Comments 159.268 159.266 159.263 159.260 159.257 159.254 159.250 159.246 159.242 159.237 159.233 159.229 159.225 159.220 159.215 159.209 159.205 159.202 159.198 159.194 159.190 159.185 159.181 159.176 159.172 159.169 159.165 159.162 159.158 159.155 159.152 159.149 159.147 159.144 159.142 159.138 159.135 159.131 159.128 159.125 159.121 159.118 159.114 159.111 159.109 159.107 Date' 28-Mar-96 Ticket No: 69346 Page No: 2.1.16 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh'mm:ss) (hr) (psi) (F) 6-Apr-96 21:22:29 8.3003 3070.414 159.105 21:24:05 8.3269 3070.554 159.103 21:25:41 8.3536 3070.687 159.100 21:27:23 8.3819 3070.834 159.097 21:28:59 8.4086 3070.990 159.093 21:30:35 8.4353 3071.131 159.088 21 '32:17 8.4636 3071.268 159.086 21:33:59 8.4919 3071.405 159.084 21:35:35 8.5186 3071.538 159.080 21:37:11 8.5453 3071.667 159.075 21:38:53 8.5736 3071.830 159.071 21:40:29 8.6003 3071.971 159.067 21:42:11 8.6286 3072.097 159.063 21:43:47 8.6553 3072.182 159.059 21:45:23 8.6819 3072.332 159.055 21:46:59 8.7086 3072.471 159.051 21:48:35 8.7353 3072.574 159.047 21:50:11 8.7619 3072.734 159.042 21:51:47 8.7886 3072.863 159.038 21:53:29 8.8169 3072.982 159.041 21:55:11 8.8453 3073.131 159.038 21:56:47 8.8719 3073.249 159.035 21:58:29 8.9003 3073.383 159.031 22:00:05 8.9269 3073.518 159.029 22:01:41 8.9536 3073.649 159.026 22:03:17 8.9803 3073.789 159.023 22:04:53 9.0069 3073.904 159.020 22:06:29 9.0336 3074.029 159.018 22:08:05 9.0603 3074.164 159.015 22:09:41 9.0869 3074.293 159.012 22:11:17 9.1136 3074.408 159.009 22:12:53 9.1403 3074.541 159.006 22:14:29 9.1669 3074.664 159.003 22:16:05 9.1936 3074.784 159.000 22:17:41 9.2203 3074.903 158.997 22:19:23 9.2486 3075.044 158.994 22:20:59 9.2753 3075.173 158.991 22:22:41 9.3036 3075.296 158.987 22:24:17 9.3303 3075.418 158.984 22:25:53 9.3569 3075.538 158.981 22:27:29 9.3836 3075.661 158.977 22:29:05 9.4103 3075.785 158.974 22:30:41 9.4369 3075.910 158.970 22:32:23 9.4653 3076.035 158.967 22:33:59 9.4919 3076.160 158.965 22:35:35 9.5186 3076.278 158.963 Comments Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Page No: 2.1.17 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 158.961 158.958 158.955 158.952 158.950 158.947 158.944 158.941 158.938 158.936 158.934 158.932 158.930 158.928 158.926 158.923 158.921 158.920 158.916 158.912 158.908 158.905 158.901 158.900 158.900 158.897 158.894 158.891 158.888 158.885 158.882 158.879 158.876 158.873 158.870 158.868 158.866 158.864 158.862 158.861 158.859 158.857 158.855 158.853 158.850 158.847 6-Apr-96 22:37:11 9.5453 3076.398 22:38:53 9.5736 3076.528 22:40:29 9.6003 3076.640 22:42:05 9.6269 3076.768 22:43:41 9.6536 3076.890 22:45:17 9.6803 3077.008 22:46:53 9.7069 3077.130 22:48:29 9.7336 3077.244 22:50:05 9.7603 3077.364 22:51:41 9.7869 3077.476 22:53:17 9.8136 3077.599 22:54:53 9.8403 3077.719 22:56:29 9.8669 3077.834 22:58:05 9.8936 3077.952 22:59:41 9.9203 3078.071 23:01:17 9.9469 3078.189 23:02:53 9.9736 3078.295 23:04:23 9.9986 3078.404 23:05:59 10.0253 3078.514 23:07:41 10.0536 3078.632 23:09:17 10.0803 3078.740 23:10:59 10.1086 3078.831 23:12:35 10.1353 3078.972 23:14:17 10.1636 3079.092 23:15:53 10.1903 3079.201 23:17:35 10.2186 3079.322 23:19:11 10.2453 3079.442 23:20:53 10.2736 3079.558 23:22:29 10.3003 3079.680 23:24:05 10.3269 3079.795 23:25:41 10.3536 3079.908 23:27:17 10.3803 3080.020 23:28:53 10.4069 3080.138 23:30:29 10.4336 3080.250 23:32:05 10.4603 3080.368 23:33:41 10.4869 3080.487 23:35:17 10.5136 3080.593 23:36:53 10.5403 3080.703 23:38:29 10.5669 3080.813 23:40:05 10.5936 3080.681 23:41:41 10.6203 3081.022 23:43:17 10.6469 3081.134 23:44:53 10.6736 3081.242 23:46:29 10.7003 3081.349 23:47:59 10.7253 3081.448 23:49:35 10.7519 3081.552 Comments Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.18 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 3081.658 3081.765 3081.873 3081.983 3082.093 3082.196 3082.233 3082.250 3082.585 3082.922 3083.236 3083.581 3083.899 3084.222 3084.545 3084.858 3085.190 3085.505 3085.815 3086.124 3086.422 3086.722 3087.028 3087.333 3087.629 3087.942 3088.237 3088.538 3088.838 3089.127 3089.405 3089.686 3089.984 3090.268 3090.553 3090.839 3091.118 3091.405 3091.667 3091.940 3092.203 3092.491 3092.762 3093.033 3093.294 6-Apr-96 23:51:11 10.7786 23:52:47 10.8053 23:54:23 10.8319 23:55:59 10.8586 23:57:41 10.8869 23:59:17 10.9136 23:59:53 10.9236 7-Apr-96 00:00:05 10.9269 00:05:11 11.0119 00:10:17 11.0969 00:15:17 11.1803 00:20:29 11.2669 00:25:29 11.3503 00:30:41 11.4369 00:35:41 11.5203 00:40:47 11.6053 00:45:59 11.6919 00:51:05 11.7769 00:56:11 11.8619 01:01:11 11.9453 01:06:23 12.0319 01:11:23 12.1153 01:16:35 12.2019 01:21:35 12.2853 01:26:41 12.3703 01:31:53 12.4569 01:36:53 12.5403 01:41:59 12.6253 01:47:11 12.7119 01:52:11 12.7953 01:57:23 12.8819 02:02:23 12.9653 02:07:35 13.0519 02:12:41 13.1369 02:17:41 13.2203 02:22:53 13.3069 02:27:53 13.3903 02:33:05 13.4769 02:38:05 13.5603 02:43:17 13.6469 02:48:17 13.7303 02:53:40 13.8200 02:58:52 13.9067 03:04:04 13.9933 03:09:16 14.0800 Comments 158.844 158.841 158.838 158.835 158.832 158.831 158.830 158.830 158.824 158.818 158.812 158.806 158.798 158.790 158.784 158.778 158.769 158.762 158.755 158.748 158.740 158.735 158.730 158.725 158.720 158.712 158.707 158.701 158.695 158.689 158.684 158.679 158.673 158.666 158.662 158.658 158.652 158.645 158.639 158.634 158.630 158.622 158.618 158.613 158.607 Date: 28-Mar-96 Ticket No: 69346 Page No' 2.1.19 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 7-Apr-96 03:14:28 14.1667 3093.533 03:19:28 14.2500 3093.785 03:24:40 14.3367 3094.039 03:29:52 14.4233 3094.278 03:35:04 14.5100 3094.529 03:40:16 14.5967 3094.816 03:45:28 14.6833 3095.090 03:50:52 14.7733 3095.365 03:56:04 14.8600 3095.622 04:01:28 14.9500 3095.878 04:06:40 15.0367 3096.143 04:11:52 15.1233 3096.390 04:17:04 15.2100 3096.636 04:22:16 15.2967 3096.906 04:27:28 15.3833 3097.153 04:32:40 15.4700 3097.413 04:37:52 15.5567 3097.647 04:42:52 15.6400 3097.891 04:48:04 15.7267 3098.137 04:53:16 15.8133 3098.379 04:58:28 15.9000 3098.625 05:03:40 15.9867 3098.863 05:08:52 16.0733 3099.113 05:14:04 16.1600 3099.348 05:19:16 16.2467 3099.593 05:24:28 16.3333 3099.826 05:29:40 16.4200 3100.068 05:35:04 16.5100 3100.303 05:40:16 16.5967 3100.538 05:45:16 16.6800 3100.756 05:50:28 16.7667 3100.990 05:55:28 16.8500 3101.208 06:00:40 16.9367 3101.434 06:05:52 17.0233 3101.665 06:11:04 17.1100 3101.884 06:16:16 17.1967 3102.121 06:21:28 17.2833 3102.345 06:26:40 17.3700 3102.568 06:31:52 17.4567 3102.790 06:37:04 17.5433 3103.009 06:42:28 17.6333 3103.240 06:47:40 17.7200 3103.450 06:52:52 17.8067 3103.669 06:57:52 17.8900 3103.871 07:03:04 17.9767 3104.085 07:08:16 18.0633 3104.301 Comments 158.602 158.595 158.588 158.582 158.575 158.568 158.565 158.561 158.555 158.550 158.545 158.540 158.535 158.530 158.524 158.519 158.513 158.509 158.505 158.501 158.498 158.494 158.490 158.486 158.481 158.477 158.473 158.465 158.459 158.455 158.454 158.451 158.448 158.444 158.441 158.437 158.432 158.427 158.421 158.416 158.406 158.403 158.402 158.399 158.395 158.392 Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.20 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth' 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 7-Apr-96 07:13:28 18.1500 3104.518 158.388 07:18:40 18.2367 3104.734 158.385 07:23:52 18.3233 3104.942 158.382 07:29:04 18.4100 3105.155 158.380 07:34:16 18.4967 3105.363 158.377 07:39:28 18.5833 3105.572 158.375 07:44:40 18.6700 3105.789 158.372 07:49:52 18.7567 3105.988 158.365 07:54:52 18.8400 3106.185 158.359 08:00:04 18.9267 3106.391 158.355 08:05:16 19.0133 3106.586 158.352 08:10:28 19.1000 3106.783 158.348 08:15:40 19.1867 3106.975 158.344 08:20:52 19.2733 3107.160 158.340 08:26:04 19.3600 3107.361 158.336 08:31:16 19.4467 3107.576 158.331 08:36:28 19.5333 3107.750 158.327 08:41:40 19.6200 3107.942 158.322 08:47:04 19.7100 3108.145 158.318 08:52:16 19.7967 3108.349 158.316 08:57:28 19.8833 3108.529 158.313 09:02:40 19.9700 3108.714 158.310 09:07:52 20.0567 3108.903 158.308 09:13:04 20.1433 3109.102 158.305 09:18:16 20.2300 3109.290 158.301 09:23:28 20.3167 3109.482 158.298 09:28:40 20.4033 3109.659 158.295 09:33:52 20.4900 3109.861 158.292 09:39:04 20.5767 3110.046 158.289 09:44:16 20.6633 3110.238 158.287 09:49:28 20.7500 3110.430 158.285 09:54:40 20.8367 3110.604 158.283 09:59:52 20.9233 3110.796 158.281 10:05:04 21.0100 3110.988 158.279 10:10:28 21.1000 3111.166 158.276 10:15:40 21.1867 3111.331 158.274 10:20:52 21.2733 3111.506 158.272 10:26:04 21.3600 3111.685 158.269 10:31:16 21.4467 3111.870 158.267 10:36:28 21.5333 3112.057 158.264 10:41:40 21.6200 3112.235 158.261 10:46:52 21.7067 3112.407 158.258 10:52:04 21.7933 3112.584 158.255 10:57:16 21.8800 3112.757 158.251 11:02:28 21.9667 3112.948 158.249 11:07:40 22.0533 3113.125 158.246 Comments Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Page No' 2.1.21 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 7-Apr-96 11:12:52 22.1400 3113.308 158.243 11:18:04 22.2267 3113.490 158.240 11:23:16 22.3133 3113.648 158.238 11:28:28 22.4000 3113.813 158.234 11:33:52 22.4900 3113.992 158.232 11:39:04 22.5767 3114.162 158.230 11:44:04 22.6600 3114.325 158.229 11:49:16 22.7467 3114.488 158.226 11:54:28 22.8333 3114.668 158.224 11:59:40 22.9200 3114.844 158.221 12:04:52 23.0067 3115.014 158.219 12:10:04 23.0933 3115.182 158.216 12:15:16 23.1800 3115.350 158.214 12:20:28 23.2667 3115.512 158.211 12:25:40 23.3533 3115.675 158.209 12:30:52 23.4400 3115.840 158.206 12:36:04 23.5267 3116.007 158.204 12:41:16 23.6133 3116.174 158.203 12:46:28 23.7000 3116.332 158.202 12:51:40 23.7867 3116.502 158.200 12:56:52 23.8733 3116.662 158.199 13:02:04 23.9600 3116.827 158.196 13:07:16 24.0467 3116.999 158.190 13:12:16 24.1300 3117.149 158.186 13:17:28 24.2167 3117.298 158.185 13:22:40 24.3033 3117.475 158.183 13:27:52 24.3900 3117.640 158.182 13:33:04 24.4767 3117.798 158.181 13:38:16 24.5633 3117.955 158.179 13:43:28 24.6500 3118.115 158.177 13:48:40 24.7367 3118.270 158.174 13:53:52 24.8233 3118.433 158.172 13:59:04 24.9100 3118.592 158.169 14:04:16 24.9967 3118.751 158.167 14:09:28 25.0833 3118.905 158.165 14:14:40 25.1700 3119.065 158.163 14:19:52 25.2567 3119.225 158.161 14:25:04 25.3433 3119.361 158.159 14:30:16 25.4300 3119.516 158.157 14:35:28 25.5167 3119.665 158.156 14:40:40 25.6033 3119.819 158.154 14:45:52 25.6900 3119.972 158.152 14:51:04 25.7767 3120.120 158.150 14:56:16 25.8633 3120.273 158.148 15:01:28 25.9500 3120.431 158.146 15:06:40 26.0367 3120.564 158.143 Comments Date: 28-Mar-96 Halliburton Gauge No.' 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Page No: 2.1.22 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 7-Apr-96 15:11:40 26.1200 3120.711 158.142 15:16:52 26.2067 3120.864 158.142 15:22:04 26.2933 3121.014 158.141 15:27:28 26.3833 3121.167 158.137 15:32:52 26.4733 3121.319 158.133 15:38:16 26.5633 3121.468 158.132 15:43:28 26.6500 3121.620 158.132 15:48:40 26.7367 3121.756 158.131 15:53:52 26.8233 3121.903 158.130 15:59:04 26.91 O0 3122.051 158.130 16:04:16 26.9967 3122.199 158.128 16:09:28 27.0833 3122.332 158.126 16:14:40 27.1700 3122.476 158.123 16:19:52 27.2567 3122.618 158.120 16:25:04 27.3433 3122.761 158.117 16:30:16 27.4300 3122.907 158.115 16:35:28 27.5167 3123.049 158.113 16:40:40 27.6033 3123.192 158.111 16:45:52 27.6900 3123.337 158.109 16:51:04 27.7767 3123.490 158.107 16:56:16 27.8633 3123.621 158.105 17:01:28 27.9500 3123.764 158.103 17:06:40 28.0367 3123.904 158.102 17:11:52 28.1233 3124.050 158.1 O0 17:17:04 28.21 O0 3124.187 158.098 17:22:16 28.2967 3124.326 158.097 17:27:28 28.3833 3124.459 158.095 17:32:40 28.4700 3124.604 158.093 17:38:04 28.5600 3124.752 158.091 17:43:28 28.6500 3124.890 158.088 17:48:40 28.7367 3125.028 158.089 17:53:40 28.8200 3125.161 158.087 17:58:52 28.9067 3125.292 158.086 18:04:04 28.9933 3125.427 158.084 18:09:28 29.0833 3125.568 158.083 18:14:40 29.1700 3125.706 158.082 18:20:04 29.2600 3125.848 158.080 18:25:16 29.3467 3125.989 158.078 18:30:28 29.4333 3126.117 158.075 18:35:52 29.5233 3126.253 158.075 18:41:16 29.6133 3126.392 158.074 18:46:28 29.7000 3126.524 158.073 18:51:40 29.7867 3126.656 158.071 18:56:52 29.8733 3126.784 158.070 19:02:04 29.9600 3126.915 158.068 19:07:16 30.0467 3127.039 158.066 Comments Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.23 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth' 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 7-Apr-96 19:12:28 30.1333 3127.172 19:17:40 30.2200 3127.303 19:22:52 30.3067 3127.430 19:28:04 30.3933 3127.564 19:33:16 30.4800 3127.690 19:38:28 30.5667 3127.815 19:43:40 30.6533 3127.943 19:48:52 30.7400 3128.053 19:54:04 30.8267 3128.197 19:59:16 30.9133 3128.331 20:04:28 31.0000 3128.458 20:09:40 31.0867 3128.585 20:14:52 31.1733 3128.706 20:20:04 31.2600 3128.829 20:25:16 31.3467 3128.957 20:30:28 31.4333 3129.080 20:35:40 31.5200 3129.209 20:40:52 31.6067 3129.325 20:46:04 31.6933 3129.447 20:51:28 31.7833 3129.576 20:56:40 31.8700 3129.699 21:02:04 31.9600 3129.827 21:07:16 32.0467 3129.951 21:12:28 32.1333 3130.072 21:17:52 32.2233 3130.193 21:23:04 32.3100 3130.315 21:28:28 32.4000 3130.444 21:33:40 32.4867 3130.569 21:38:52 32.5733 3130.693 21:44:04 32.6600 3130.809 21:49:16 32.7467 3130.930 21:54:28 32.8333 3131.046 21:59:40 32.9200 3131.167 22:04:52 33.0067 3131.287 22:10:04 33.0933 3131.403 22:15:16 33.1800 3131.524 22:20:28 33.2667 3131.642 22:25:40 33.3533 3131.759 22:30:52 33.4400 3131.874 22:36:04 33.5267 3131.993 22:41:16 33.6133 3132.107 22:46:28 33.7000 3132.225 22:51:40 33.7867 3132.345 22:56:53 33;8736 3132.462 23:02:13 33.9625 3132.584 23:07:33 34.0514 3132.703 Comments 158.065 158.063 158.061 158.059 158.058 158.057 158.056 158.055 158.053 158.052 158.050 158.049 158.047 158.046 158.045 158.043 158.042 158.041 158.039 158.036 158.034 158.032 158.030 158.028 158.027 158.025 158.023 158.021 158.018 158.015 158.012 158.010 158.009 158.008 158.007 158.005 158.004 158.004 158.003 158.003 158.002 158.001 157.998 157.996 157.992 157.991 Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.24 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressu re Temperature (hh:mm:ss) (hr) (psi) (F) 7-Apr-96 23:12:53 34.1403 3132.821 157.990 23:17:57 34.2247 3132.935 157.988 23:23:17 34.3136 3133.051 157.985 23:28:37 34.4025 3133.171 157.983 23:33:41 34.4869 3133.281 157.981 23:39:01 34.5758 3133.391 157.980 23:44:21 34.6647 3133.512 157.979 23:49:41 34.7536 3133.628 157.978 23:55:01 34.8425 3133.746 157.976 23:59:49 34.9225 3133.846 157.975 8-Apr-96 00:00:21 34.9314 3133.860 157.975 00:05:41 35.0203 3133.973 157.974 00:11:01 35.1092 3134.089 157.973 00:16:21 35.1981 3134.194 157.971 00:21:41 35.2869 3134.307 157.969 00:27:01 35.3758 3134.421 157.968 00:32:21 35.4647 3134.538 157.966 00:37:41 35.5536 3134.650 157.965 00:43:01 35.6425 3134.765 157.962 00:48:21 35.7314 3134.870 157.960 00:53:41 35.8203 3134.981 157.957 00:59:01 35.9092 3135.092 157.954 01:04:21 35.9981 3135.203 157.951 01:09:41 36.0869 3135.314 157.948 01:15:01 36.1758 3135.422 157.946 01:20:21 36.2647 3135.526 157.945 01:25:41 36.3536 3135.635 157.945 01:31:01 36.4425 3135.746 157.944 01:36:21 36.5314 3135.849 157.943 01:41:25 36.6158 3135.954 157.943 01:46:45 36.7047 3136.057 157.940 01:51:49 36.7892 3136.163 157.938 01:57:09 36.8781 3136.274 157.941 02:02:13 36.9625 3136.380 157.941 02:07:17 37.0469 3136.479 157.939 02:12:37 37.1358 3136.591 157.936 02:17:57 37.2247 3136.701 157.934 02:23:17 37.3136 3136.807 157.931 02:28:37 37.4025 3136.914 157.929 02:33:57 37.4914 3137.025 157.926 02:39:17 37.5803 3137.133 157.924 02:44:37 37.6692 3137.244 157.922 02:49:57 37.7581 3137.346 157.921 02:55:17 37.8469 3137.452 157.920 03:00:37 37.9358 3137.555 157.919 Comments Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.25 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 8-Apr-96 03:05:57 38.0247 3137.652 157.919 03:11:17 38.1136 3137.761 157.918 03:16:37 38.2025 3137.869 157.917 03:21:57 38.2914 3137.970 157.916 03:27:17 38.3803 3138.074 157.916 03:32:37 38.4692 3138.175 157.916 03:37:57 38.5581 3138.279 157.915 03:43:17 38.6469 3138.383 157.915 03:48:37 38.7358 3138.485 157.915 03:53:57 38.8247 3138.590 157.913 03:59:17 38.9136 3138.689 157.911 04:04:37 39.0025 3138.796 157.909 04:09:57 39.0914 3138.899 157.907 04:15:17 39.1803 3139.001 157.905 04:20:37 39.2692 3139.102 157.903 04:25:57 39.3581 3139.203 157.901 04:31:01 39.4425 3139.300 157.899 04:36:21 39.5314 3139.401 157.899 04:41:25 39.6158 3139.493 157.898 04:46:45 39.7047 3139.589 157.896 04:52:05 39.7936 3139.690 157.894 04:57:25 39.8825 3139.792 157.893 05:02:29 39.9669 3139.885 157.892 05:07:49 40.0558 3139.984 157.891 05:13:09 40.1447 3140.081 157.890 05:18:13 40.2292 3140.175 157.888 05:23:33 40.3181 3140.278 157.886 05:28:37 40.4025 3140.373 157.885 05:33:57 40.4914 3140.467 157.884 05:39:17 40.5803 3140.565 157.883 05:44:21 40.6647 3140.655 157.882 05:49:41 40.7536 3140.754 157.880 05:55:01 40.8425 3140.855 157.878 06:00:05 40.9269 3140.946 157.877 06:05:25 41.01 58 3141.041 157.877 06:10:45 41.1 047 3141.1 39 157.877 06:16:05 41.1936 3141.236 157.877 06:21:09 41.2781 3141.330 157.875 06:21:09 41.2781 3141.330 157.875 06:26:29 41.3669 3141.426 157.874 06:31:49 41.4558 3141.522 157.872 06:37:09 41.5447 3141.612 157.870 06:42:13 41.6292 3141.703 157.868 06:47:33 41.71 81 3141.799 157.867 06:52:53 41.8069 3141.893 157.866 06:57:57 41.8914 3141.983 157.864 Comments Date- 28-Mar-96 Ticket No: 69346 Page No: 2.1.26 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 8-Apr-96 07:03:17 41.9803 3142.079 07:08:21 42.0647 3142.168 07:13:25 42.1492 3142.258 07:18:45 42.2380 3142.352 07:24:05 42.3269 3142.445 07:29:25 42.4158 3142.540 07:34:29 42.5003 3142.629 07:39:49 42.5892 3142.723 07:44:53 42.6736 3142.814 07:50:13 42.7625 3142.903 07:55:33 42.8514 3143.002 08:00:53 42.9403 3143.094 08:05:57 43.0247 3143.183 08:11:01 43.1092 3143.272 08:16:21 43.1981 3143.366 08:21:41 43.2869 3143.460 08:26:45 43.3714 3143.547 08:31:49 43.4558 3143.631 08:37:09 43.5447 3143.722 08:42:13 43.6292 3143.807 08:47:33 43.7181 3143.896 08:52:37 43.8025 3143.985 08:57:57 43.8914 3144.077 09:03:17 43.9803 3144.171 09:08:37 44.0692 3144.260 09:13:57 44.1581 3144.351 09:19:17 44.2469 3144.443 09:24:37 44.3358 3144.532 09:29:57 44.4247 3144.623 09:35:17 44.5136 3144.717 09:40:37 44.6025 3144.806 09:45:57 44.6914 3144.897 09:51:17 44.7803 3144.982 09:56:37 44.8692 3145.071 10:01:57 44.9581 3145.162 10:07:17 45.0469 3145.249 1 O: 12:37 45.1358 3145.336 1 O: 17:57 45.2247 3145.423 10:23:17 45.3136 3145.514 10:28:37 45.4025 3145.600 10:33:57 45.4914 3145.682 10:39:17 45.5803 3145.767 10:44:37 45.6692 3145.860 10:49:57 45.7581 3145.948 10:55:17 45.8469 3146.036 11:00:37 45.9358 3146.123 Comments 157.862 157.861 157.86O 157.858 157.856 157.854 157.852 157.851 157.851 157.851 157.850 157.850 157.846 157.844 157.843 157.843 157.841 157.836 157.839 157.841 157.840 157.839 157.837 157.834 157.832 157.830 157.828 157.825 157.824 157.823 157.821 157.820 157.819 157.817 157.817 157.818 157.818 157.818 157.819 157.819 157.819 157.818 157.816 157.815 157.814 157.812 Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Page No: 2.1.27 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 8-Apr-96 11:05:57 46.0247 3146.202 157.811 11:11:17 46.1136 3146.292 157.811 11:16:37 46.2025 3146.376 157.811 11:21:57 46.2914 3146.458 157.810 11:27:17 46.3803 3146.542 157.810 11:32:37 46.4692 3146.628 157.810 11:37:57 46.5581 3146.710 157.810 11:43:17 46.6469 3146.799 157.809 11:48:37 46.7358 3146.879 157.808 11:53:57 46.8247 3146.963 157.807 11:59:17 46.9136 3147.054 157.806 12:04:37 47.0025 3147.139 157.805 12:09:57 47.0914 3147.226 157.804 12:15:17 47.1803 3147.312 157.803 12:20:37 47.2692 3147.398 157.800 12:25:41 47.3536 3147.473 157.799 12:31:01 47.4425 3147.558 157.799 12:36:21 47.5314 3147.642 157.799 12:41:41 47.6203 3147.730 157.799 12:46:45 47.7047 3147.805 157.798 12:52:05 47.7936 3147.890 157.797 12:57:25 47.8825 3147.972 157.796 13:02:30 47.9672 3148.051 157.793 13:08:30 48.0672 3148.142 157.793 13:14:30 48.1672 3148.239 157.793 13:20:00 48.2589 3148.323 157.785 13:26:00 48.3589 3148.416 157.786 13:32:00 48.4589 3148.506 157.786 13:37:30 48.5506 3148.592 157.786 13:42:30 48.6339 3148.667 157.785 13:48:30 48.7339 3148.760 157.784 13:54:30 48.8339 3148.847 157.783 14:00:30 48.9339 3148.941 157.782 14:06:00 49.0256 3149.023 157.780 14:11:00 49.1089 3149.104 157.779 14:17:00 49.2089 3149.191 157.777 14:22:30 49.3006 3149.277 157.777 14:27:30 49.3839 3149.352 157.778 14:33:00 49.4756 3149.436 157.777 14:38:00 49.5589 3149.511 157.777 14:44:00 49.6589 3149.597 157.776 14:50:00 49.7589 3149.686 157.775 14:56:00 49.8589 3149.778 157.774 15:02:00 49.9589 3149.869 157.773 15:08:00 50.0589 3149.958 157.771 15:14:00 50.1589 3150.047 157.770 Comments Date: 28-Mar-96 Ticket No' 69346 Page No: 2.1.28 Halliburton Gauge No.: 10220 Memory Recorder No.' 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 8-Apr-96 15:20:00 50.2589 3150.134 157.769 15:26:00 50.3589 3150.230 157.768 15:32:00 50.4589 3150.317 157.767 15:38:00 50.5589 3150.403 157.767 15:44:00 50.6589 3150.492 157.766 15:50:00 50.7589 3150.583 157.765 15:56:00 50.8589 3150.672 157.765 16:02:00 50.9589 3150.757 157.764 16:08:00 51.0589 3150.848 157.764 16:14:00 51.1589 3150.934 157.763 16:20:00 51.2589 3151.025 157.763 16:26:00 51.3589 3151.114 157.762 16:31:30 51.4506 3151.187 157.762 16:36:30 51.5339 3151.261 157.761 16:42:30 51.6339 3151.352 157.760 16:48:30 51.7339 3151.434 157.759 16:54:30 51.8339 3151.521 157.757 17:00:30 51.9339 3151.607 157.756 17:06:30 52.0339 3151.692 157.755 17:12:30 52.1339 3151.776 157.754 17:18:30 52.2339 3151.864 157.752 17:24:30 52.3339 3151.949 157.751 17:30:30 52.4339 3152.035 157.750 17:36:30 52.5339 3152.122 157.749 17:42:30 52.6339 3152.204 157.747 17:48:30 52.7339 3152.292 157.747 17:54:30 52.8339 3152.376 157.747 18:00:30 52.9339 3152.460 157.746 18:06:30 53.0339 3152.545 157.746 18:12:30 53.1339 3152.631 157.746 18:18:30 53.2339 3152.715 157.745 18:24:30 53.3339 3152.800 157.745 18:30:30 53.4339 3152.886 157.745 18:36:30 53.5339 3152.968 157.744 18:42:00 53.6256 3153.045 157.744 18:47:00 53.7089 3153.110 157.740 18:52:30 53.8006 3153.187 157.737 18:57:30 53.8839 3153.256 157.736 19:03:30 53.9839 3153.342 157.734 19:09:30 54.0839 3153.426 157.733 19:15:30 54.1839 3153.494 157.731 19:21:30 54.2839 3153.578 157.730 19:27:30 54.3839 3153.659 157.728 19:33:30 54.4839 3153.742 157.727 19:39:30 54.5839 3153.818 157.725 19:45:30 54.6839 3153.905 157.724 Comments Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.29 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth' 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 8-Apr-96 19:51:30 54.7839 3153.982 157.722 19:57:30 54.8839 3154.066 157.721 20:03:30 54.9839 3154.143 157.720 20:09:30 55.0839 3154.226 157.719 20:15:30 55.1839 3154.308 157.719 20:21:30 55.2839 3154.385 157.718 20:27:30 55.3839 3154.465 157.717 20:33:30 55,4839 3154.546 157.716 20:39:30 55.5839 3154.628 157,715 20:45:30 55.6839 3154.705 157.714 20:51:30 55.7839 3154.784 157.713 20:57:30 55.8839 3154.861 157,712 21:03:30 55.9839 3154.942 157.712 21:09:30 56.0839 3155.019 157.712 21:15:30 56.1839 3155.101 157.711 21:21:30 56.2839 3155.177 157.711 21:27:30 56.3839 3155.259 157.711 21:33:30 56.4839 3155.336 157.711 21:39:30 56.5839 3155.326 157.711 21:45:30 56.6839 3155.485 157.710 21:51:30 56.7839 3155.564 157.710 21:57:30 56.8839 3155.643 157.710 22:03:30 56.9839 3155.718 157.709 22:09:30 57.0839 3155.797 157.708 22:15:30 57.1839 3155.872 157.707 22:21:30 57.2839 3155.949 157.706 22:27:30 57.3839 3156.028 157.704 22:33:30 57.4839 3156.102 157.703 22:39:30 57.5839 3156.181 157.702 22:45:30 57.6839 3156.258 157.701 22:51:30 57.7839 3156.332 157.699 22:57:30 57.8839 3156.410 157.698 23:03:30 57.9839 3156.486 157.697 23:09:30 58.0839 3156.565 157.696 23:15:30 58.1839 3156.638 157.696 23:21 '3O 58.2839 3156.716 157.695 23:27:00 58.3756 3156.782 157.695 23:32:00 58.4589 3156.848 157.694 23:38:00 58.5589 3156.921 157.693 23:44:00 58.6589 3156.997 157.692 23:50:00 58.7589 3157.072 157.691 23:56:00 58.8589 3157.146 157.690 24:00:00 58.9255 3157.199 157.690 9-Apr-96 00:01:00 58.9422 3157.209 157.690 00:11:00 59.1089 3157.331 157.688 Comments Date: 28-Mar-96 Ticket No' 69346 Page No: 2.1.30 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth' 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 9-Apr-96 00:22:00 59.2922 3157.470 157.686 00:32:00 59.4589 3157.590 157.685 00:43:00 59.6422 3157.723 157.683 00:53:00 59.8089 3157.849 157.681 01:04:00 59.9922 3157.982 157.679 01:14:00 60.1589 3158.104 157.677 01:25:00 60.3422 3158.234 157.675 01:35:00 60.5089 3158.354 157.673 01:46:00 60.6922 3158.488 157.672 01:56:00 60.8589 3158.612 157.671 02:07:00 61.0422 3158.749 157.670 02:17:00 61.2089 3158.852 157.669 02:28:00 61.3922 3158.985 157.668 02:38:00 61.5589 3159.116 157.667 02:49:00 61.7422 3159.243 157.668 02:59:00 61.9089 3159.354 157.668 03:10:00 62.0922 3159.485 157.668 03:20:00 62.2589 3159.594 157.669 03:31:00 62.4422 3159.721 157.669 03:41:00 62.6089 3159.833 157.670 03:52:00 62.7922 3159.975 157.668 04:02:00 62.9589 3160.099 157.667 04:13:00 63.1422 3160.226 157.666 04:23:00 63.3089 3160.316 157.665 04:34:00 63.4922 3160.450 157.663 04:44:00 63.6589 3160.591 157.662 04:55:00 63.8422 3160.685 157.660 05:05:00 64.0089 3160.785 157.658 05:16:00 64.1922 3160.910 157.656 05:26:00 64.3589 3161.028 157.654 05:37:00 64.5422 3161.138 157.652 05:47:30 64.7172 3161.256 157.652 05:57:30 64.8839 3161.365 157.653 06:08:30 65.0672 3161.471 157.653 06:19:00 65.2422 3161.598 157.653 06:29:00 65.4089 3161.709 157.651 06:40:00 65.5922 3161.833 157.650 06:50:30 65.7672 3161.939 157.649 07:00:30 65.9339 3162.049 157.647 07:11:00 66.1089 3162.173 157.646 07:22:00 66.2922 3162.289 157.646 07:32:00 66.4589 3162.398 157.646 07:43:00 66.6422 3162.513 157.646 07:53:00 66.8089 3162.628 157.645 08:04:00 66.9922 3162.725 157.645 08:14:00 67.1589 3162.828 157.645 Comments Date: 28-Mar-96 Ticket No: 69346 Page No: 2.1.31 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth' 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 9-Apr-96 08:25:00 67.3422 3162.959 157.644 08:35:00 67.5089 3163.057 157.643 08:46:00 67.6922 3163.172 157.642 08:56:00 67.8589 3163.271 157.641 09:07:00 68.0422 3163.388 157.640 09:17:00 68.2089 3163.487 157.639 09:28:00 68.3922 3163.601 157.638 09:38:00 68.5589 3163.582 157.638 09:49:00 68.7422 3163.810 157.638 09:59:00 68.9089 3163.915 157.637 10:10:00 69.0922 3164.028 157.637 10:20:00 69.2589 3164.129 157.636 10:31:00 69.4422 3164.244 157.635 10:41:00 69.6089 3164.347 157.633 10:52:00 69.7922 3164.457 157.632 11:02:00 69.9589 3164.560 157.630 11:13:00 70.1422 3164.670 157.629 11:23:00 70.3089 3164.770 157.628 11:34:00 70.4922 3164.880 157.627 11:44:00 70.6589 3164.981 157.625 11:55:00 70.8422 3165.089 157.624 12:05:00 71.0089 3165.190 157.623 12:16:00 71.1922 3165.298 157.622 12:26:00 71.3589 3165.396 157.621 12:37:00 71.5422 3165.515 157.620 12:47:00 71.7089 3165.613 157.619 12:58:00 71.8922 3165.721 157.619 13:08:00 72.0589 3165.822 157.618 13:19:00 72.2422 3165.910 157.618 13:29:00 72.4089 3166.013 157.617 13:40:00 72.5922 3166.124 157.617 13:50:00 72.7589 3166.226 157.617 14:01:00 72.9422 3166.334 157.617 14:11:00 73.1089 3166.428 157.617 14:22:00 73.2922 3166.530 157.617 14:32:00 73.4589 3t 66.628 157.617 14:43:00 73.6422 3166.736 157.616 14:53:00 73.8089 3166.832 157.615 15:04:00 73.9922 3166.937 157.614 15:14:00 74.1589 3167.030 157.613 15:25:00 74.3422 3167.124 157.612 15:35:00 74.5089 3167.212 157.611 15:46:00 74.6922 3167.313 157.611 15:56:00 74.8589 3167.409 157.610 16:07:00 75.0422 3167.509 157.610 16:17:00 75.2089 3167.588 157.609 Comments Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 69346 Pressure vs Time Page No: 2.1.32 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) ~ 9-Apr-96 16:28:00 75.3922 3167.701 16:38:00 75.5589 3167.794 16:49:00 75.7422 3167.895 16:59:00 75.9089 3167.981 17:10:00 76.0922 3168.084 17:20:00 76.2589 3168.172 ~-- 17:31:00 76.4422 3168.273 17:41:00 76.6089 3168.363 17:52:00 76.7922 3168.462 18:02:30 76.9672 3168,560 18:13:00 77.1422 3168.650 18:23:00 77.3089 3168.739 18:34:00 77.4922 3168.840 ,- 18:44:30 77.6672 3168.931 18:54:30 77.8339 3169.019 19:05:30 78.0172 3169.119 19:16:00 78.1922 3169.212 19:26:30 78.3672 3169.306 19:36:30 78.5339 3169.395 19:47:30 78.7172 3169.488 · .-~ 19:57:30 78,8839 3169,579 20:08:00 79,0589 3169,670 20:19:00 79,2422 3169,765 20:29:00 79,4089 3169,847 '~' 20:39:30 79.5839 3169.944 20:50:30 79.7672 3170.040 21:00:30 79.9339 3170.121 ,-~ 21:11:00 80.1089 3170.213 21:22:00 80.2922 3170.308 21:32:30 80.4672 3170.396 21:43:00 80.6422 3170.485 ~- 21:53:00 80.8089 3170.571 22:04:00 80.9922 3170.664 22:14:00 81.1589 3170.748 ~, 22:24:30 81.3339 3170.836 22:35:30 81.5172 3170.935 22:45:30 81.6839 3171.014 22:56:00 81.8589 3171.097 ~--' 23:07:00 82,0422 3171,190 23:17:00 82,2089 3171,272 23:27:30 82,3839 3171,360 ,- 23:38:30 82.5672 3171.446 23:48:30 82.7339 3171.530 23:59:00 82.9089 3171.614 24:00:00 82.9255 3171.625 '-~ 10-Apr-96 00:01:00 82.9422 3171.632 157.609 157.609 157.608 157.608 157.608 157.608 157.608 157.607 157.609 157.609 157.608 157.608 157.608 157.607 157.607 157.607 157.606 157.604 157.604 157.604 157.604 157.604 157.604 157.605 157.603 157.601 157.599 157.596 157.596 157.597 157.597 157.595 157.593 157.590 157.589 157.590 157.591 157.592 157.592 157.592 157.591 157.591 157.590 157.589 157.589 157.589 Comments Date: 28-Mar-96 Ticket No: 69346 Page No' 2.1.33 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 3 71.893 3 72.144 3' 72.393 3' 72.632 3' 72.878 3' 73.124 3; 73.362 3; 73.595 3173.836 3174.065 3174.301 3174.533 3174.765 3174.982 3175.209 3175.436 3175.658 3175.880 3176.104 3176.312 3176.531 3176.753 3176.957 3177.169 3177.382 3177.591 3177.797 3178.002 3178.217 3178.419 3178.622 3178.828 3179.030 3179.230 3179.424 3179.628 3179.829 3180.022 3180.223 3180.420 3180.609 3180.807 3181.007 3181.190 3181.386 3181.581 10-Apr-96 00:32:00 83.4589 01:03:00 83.9756 01:34:00 84.4922 02:04:00 84.9922 02:35:00 85.5089 03:06:00 86.0256 03:37:00 86.5422 04:07:00 87.0422 04:38:00 87.5589 05:08:00 88.0589 05:39:00 88.5756 06:10:00 89.0922 06:41:00 89.6089 07:11:00 90.1089 07:42:00 90.6256 08:13:00 91.1422 08:43:00 91.6422 09:14:00 92.1589 09:45:00 92.6755 10:15:00 93.1756 10:46:00 93.6922 11:17:00 94.2089 11:47:00 94.7089 12:18:00 95.2256 12:49:00 95.7422 13:19:35 96.2519 13:50:35 96.7686 14:21:35 97.2853 14:53:35 97.8186 15:24:35 98.3353 15:55:35 98.8519 16:26:35 99.3686 16:57:35 99.8853 17:28:35 100.4019 17:58:35 100.9019 18:30:35 101.4353 19:02:35 101.9686 19:32:35 102.4686 20:04:35 103.0019 20:36:35 103.5353 21:06:35 104.0353 21:38:35 104.5686 22:10:35 105.1019 22:40:35 105.6019 23:12:35 106,1353 23:44:35 106.6686 Comments 157.589 157.589 157.586 157.583 157.584 157.585 157.584 157.582 157.584 157.586 157.587 157.588 157.584 157.579 157.578 157.580 157.580 157.577 157.575 157.573 157.572 157.571 157.570 157.568 157.566 157.560 157.561 157.561 157.559 157.554 157.556 157.556 157.561 157.563 157.563 157.564 157.565 157.562 157.558 157.554 157.551 157.550 157.552 157.553 157.555 157.556 Date: 28-Mar-96 Ticket No: 69346 Page No' 2.1.34 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Pressure vs Time Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 11 -Ap r-96 00:14:35 107.1686 3181.762 157.557 00:46:35 107.7019 3181.955 157.557 01:16:35 108.2019 3182.127 157.557 01:48:35 108.7353 3182.348 157.557 02:20:35 109.2686 3182.560 157.557 02:50:35 109.7686 3182.756 157.557 03:22:35 110.3019 3182.963 157.556 03:54:35 110.8353 3183.154 157.556 04:24:35 111.3353 3183.337 157.556 04:56:35 111.8686 3183.525 157.556 05:28:35 112.4019 3183.711 157.556 05:58:35 112.9019 3183.887 157.556 06:30:35 113.4353 3184.062 157.554 07:02:35 113.9686 3184.240 157.552 07:32:35 114.4686 3184.404 157.550 08:04:35 115.0019 3184.578 157.548 08:36:35 115.5353 3184.745 157.546 09:06:35 116.0353 3184.905 157.545 09:38:35 116.5686 3185.072 157.543 10:10:35 117.1019 3185.241 157.542 10:40:35 117.6019 3185.407 157.545 11:12:35 118.1353 3185.567 157.548 11:44:35 118.6686 3185.731 157.552 12:14:35 119.1686 3185.886 157.555 12:46:35 119.7019 3186.055 157.554 13:16:35 120.2019 3186.204 157.554 13:48:35 120.7353 3186.369 157.553 14:20:35 121.2686 3186.538 157.553 14:50:35 121.7686 3186.681 157.552 15:22:35 122.3019 3186.849 157.552 15:54:35 122.8353 3186.997 157.552 16:24:35 123.3353 3187.154 157.551 16:56:35 123.8686 3187.309 157.551 17:28:35 124.4019 3187.464 157.550 17:58:35 124.9019 3187.611 157.550 18:30:35 125.4353 3187.761 157.549 19:02:35 125.9686 3187.920 157.549 19:32:35 126.4686 3188.072 157.549 20:04:35 127.0019 3188.211 157.549 20:36:35 127.5353 3188.361 157.549 21:06:35 128.0353 3188.498 157.549 21:38:35 128.5686 3188.650 157.549 22:10:35 129.1019 3188.796 157.549 22:40:35 129.6019 3188.938 157.549 23:12:35 130.1353 3189.079 157.551 23:44:35 130.6686 3189.226 157.556 Comments Date: 28-Mar-96 Halliburton Gauge No.: 10220 Memory Recorder No.: 20223 Ticket No: 693463 Pressure vs Time Page No: 2.1.35 Gauge Depth: 7113.72 ft Time Delta Time Pressure Temperature (hh:mm:ss) (hr) (psi) (F) 157.561 157.566 157.567 157.565 157.562 157.559 157.557 157.557 157.556 157.555 157.555 157.556 157.556 157.557 157.558 157.558 157.559 157.559 157.560 157.560 157.561 157.561 157.561 157.564 157.566 157.571 157.568 157.568 157.570 157.572 157.570 157.568 157.572 157.574 157.577 157.573 157.568 157.565 157.567 157.571 157.574 157.578 157.576 157.577 157.577 157.578 3189.364 3189.511 3189.646 3189.789 3189.922 3190.056 3190.198 3190.338 3190.469 3190.610 3190.748 3190.874 3191.012 3191.147 3191.278 3191.418 3191.544 3191.670 3191.807 3191.928 3192.050 3192.180 3192.307 3192.430 3192.561 3192.684 3192.803 3192.928 3193.052 3193.176 3193.308 3193.420 3193.544 3193.669 3193.781 3193.905 3194.029 3194.143 3194.261 3194.382 3194.489 3194.608 3194.731 3194.840 3194.949 3195.071 12-Apr-96 00:14:35 131.1686 00:46:35 131.7019 01:16:35 132.2019 01:48:35 132.7353 02:20:35 133.2686 02:50:35 133.7686 03:22:35 134.3019 03:54:35 134.8353 04:24:35 135.3353 04:56:35 135.8686 05:28:35 136.4019 05:58:35 136.9019 06:30:35 137.4353 07:02:35 137.9686 07:32:35 138.4686 08:04:35 139.0019 08:36:35 139.5353 09:06:35 140.0353 09:38:35 140.5686 10:10:35 141.1019 10:40:35 141.6019 11:12:35 142.1353 11:44:35 142.6686 12:14:35 143.1686 12:46:35 143.7019 13:17:40 144.2200 13:47:40 144.7200 14:19:40 145.2533 14:51:40 145.7867 15:23:40 146.3200 15:55:40 146.8533 16:25:40 147.3533 16:57:40 147.8867 17:29:40 148.4200 17:59:40 148.9200 18:31:40 149.4533 19:03:40 149.9867 19:33:40 150.4867 20:05:40 151.0200 20:37:40 151.5533 21:07:40 152.0533 21:39:40 152.5867 22:11:40 153.1200 22:41:40 153.6200 23:13:40 154.1533 23:45:40 154.6867 Comments Time (hh:mm:ss) 13-Apr-96 00:15:40 00:47:40 01:19:40 01:49:40 02:21:40 02:51:40 03:23:40 03:55:40 04:25:40 04:57:40 05:29:40 05:59:40 06:31:40 07:03:40 07:33:40 08:05:40 08:37:40 09:03:40 End Period 2 09:05:40 09:17:40 09:25:40 09:29:40 09:31:40 09:33:40 09:35:40 09:37:40 09:39:40 09:41:40 09:43:40 09:47:40 09:59:40 10:11:40 10:15:40 Delta Time (hr) 155.1867 155.7200 156.2533 156.7533 157.2867 157.7867 158.3200 158.8533 159.3533 159.8867 160.4200 160.9200 161.4533 161.9867 162.4867 163.0200 163.5533 163.9867 Pressure (psi) 3195.179 3195.291 3195.405 3195.514 3195.630 3195.731 3195.844 3195.958 3196.058 3196.169 3196.281 3196.386 3196.494 3196.601 3196.705 3196.812 3196.911 3197.388 3198.430 3197.473 2962.346 2573.091 2333.254 2077.762 1815.586 1556.318 1290.847 1009.728 771.825 13.849 8.979 16.026 16.183 Temperature (F) 157.578 157.578 157.578 157.578 157.578 157.578 157.579 157.579 157.580 157.580 157.581 157.581 157.581 157.582 157.585 157.590 157.595 157.600 157.600 157.602 150.269 127.186 113.519 99.945 85.006 70.488 59.645 52.681 52.957 44.132 20.048 16.272 16.720 Comments W/L Operations per AOGCC reg. 20 AAC 25.537 WELL SUMMARY Well Name: ARCO Neve #1 ~ -- ~'i ~ APl #: 50-103-20231-00 Location: WKE 92-02, sp. 1258 ASP: x=370,251 y=5,965,357 zone:4 Lat.: 70.313528 N Long: 151.051560 W S/T/R: 465' FNL, 2440' FWL, sec 14, T11 N, R4E Lease Number: ADL 380075 Rig: Elevation: Spud Date: Total Depth: TD Date: Pool 6 G.L.= 12' February 14, 1996 7700' MD (-7656' SS) dril~:~e March 5, 1996 RECEIVED Completion Date: Completion Status: Formation @-TD: March 16, 1996 Plugged & Abandoned Jurassic Kingak AUG 1 9 1996 Alaska Oil & Gas Cons. ~rnmi~c,n Production Tests: Cased hole DST Perfed interval from 7268' to 7376' MD. Pre-frac flowed 249 BOPD at 190 psi FTP with a GOR of 616 SCF/STB. Oil gravity was 41° APl and gas gravity was 0.84. Neve was frac'd with 100 Klbs of sand. Post-frac flow was 1110 BOPD at 160 psi FTP and a GOR of 776 SCF/STB. Oil gravity was 40° APl and gas gravity was 0.81. Geological Tops: MD SS Base Permafrost 717' -687' Top West Sak 970' -940' Top Shale Wall 2396' -2366' Top Albian 4076' -4036' Top Albian B 5313' -5283' Top Albian C 5673' -5643' HRZ 6750' -6720' K-1 7014' -6984' LCU 7002' -6972' Top Jurassic 7264' -7234' Total Depth (driller) 7700' -7670' Alpine 441 page 2 Conventional Cores: Aluminum barrel 4" inner diameter Core #1 - Cut 7259'-7266' Recovered 7159'-7165.5' Core #2 - Cut 7276'-7336' Recovered 7276'-7335.0' Attempted core #3, but lost circulation prior to coring. (7'/6.5') (60'/59') Logging Runs: Two attempts were made and wireline could not make it past 2600'. Open hole logs were abandoned and the well was cased. Cased hole GFI/Neuton: 6830' to TD MWD gamma ray/resistivity: surface to 7200' Mudlog: surface to TD Sidewall Cores: none ' '00NF!DENT!AL " ABCO /tJaska, Inc." Core Chip Description ,,' per A06CC ~. 20 AAC 25.537 ARCO Neve #1 Ci '~"-'" ~, } S-'U i i ~~ '~ L) [ v I 1 1 Location: Date Colville, North Slope August 16, 1996 Core#: I Recovered: 7259'-7265.5 (6.5') Cored: 7259'-7267' Depth Description Oil Oil Fluor Cut Cut Show ft. Stain Ocbr % IntensityColor color fluor color sum 7259 Mudstone: med gray, brownish, firm, slightly none none 0 none none none none None silty, micaceous, non-calcareous, presence possible ripple laminations, minor burrows 7262 Siltstone: dk brown, grayish, 5% glauconite, none none 0 none none none none None micaceous, slightly calcareous, firm, well developed chondrities burrows, some pyritized 7265 Siltstone: brownish-gray, 5% glauconite, none none 0 none none none none None micaceous, slightly calcareous, firm, very fine grained ss filled burrows, chondrities 7265.5 Sandy siltstone; brownish-gray, 10% none none 20 bright yellow none none None glauconite, sandy, slightly calcareous, firm, presence very fine grained ss filled burrows Remarks Described by Renee C. Hannon AR3B-2389-B Date~ RECEIVED AUG 1 9 1996 Alsska 0il & Gas Cons. Commission Anchorage ". Core Chip Description ,riCO Alaska, inc. ,, ~_. ~_.~ ? ,~-.~ ~, Operatorand Well Name: ARCO Neve #1 ~'~'-~ ~,"~ Location: Date Colville, North Slope August 16, 1996 Core#: 2 Recovered: 7276'-7335.5' Cut: 7276'-7336' Depth Description I Oil Oil Fluor Cut Cut Show ft.I Stain Ocb' % Intensity Color color fluor color sum 7276' Sandstone: It brn, gry, quartz, 2% It bm slight 70 dull to yellow pale very slow Poor glauconite, 10-15% matrix, v.fn L, sub rdd, bright green straw stream well sorted, non-calc, firm, bioturbated milky wh 7279' Sandstone: It brn, gry, quartz, 2-5% It bm mod 90 bright yellow pale slow Fair glauconite, 5-10% matdx, v.fn L-v.fn U, sub strng green straw stream rdd, well sorted, non-calc, silica cemented, milky wh firm, highly burrowed 7282' Sandstone: It brn, gry, quartz, tr glauconite, It bm strng 95 bright yellow pale slow Fair <5% matdx, v.fn L-v.fn U, sub rdd, well green straw stream sorted, non-calc, firm, burrowed milky wh 7285' Sandstone: It bm, quartz, 2% glauconite, 5- It bm mod 90 bright yellow pale slow Fair 10% matrix, v.fn L-v.fn U, sub rdd, well strng green straw stream sorted, non-calc, firm, bioturbated milky wh 7288' Sandstone: It brn, quartz, 2-5% glauconite, It bm mod 90 bright yellow pale slow- Fair 5-10% matrix, v.fn U-v.fn L, sub rdd, well strng green straw mod sorted, silica cemented, non-calc, firm, stream bioturbated milky wh 7291' Sandstone: it brn, quartz, 2-5% glauconite, It bm strng 95 bright yellow pale slow Fair <5% matdx, v.fn U-v.fn L, sub rdd, well green straw stream sorted, silica cemented, non-calc, firm, milky wh burrowed 7294' Sandstone: It brn, quartz, 2-5% glauconite, It brn mod 95 bright yellow pale slow Fair 2-5% matdx, v.fn U-v.fn L, sub rdd, well green straw stream sorted, silica cemented, non-calc, firm, milky wh burrowed 7297' Sandstone: It brn, quartz, 2-5% glauconite, It brn strng 95 bright yellow pale v. slow Fair <5% matrix, v.fn U, sub rdd, well sorted, silica green straw stream cemented, 2% pyrite, non-calc, firm, milky wh burrowed 7300' Sandstone: It brn, quartz, 2-5% glauconite, It bm mod 85 bright yellow pale slow- Fair 5% matrix, v.fn U-v.fn L, sub rdd, well sorted, strng green straw mod silica cemented, tr pyrite, firm, burrowed stream milky wh 7303' Sandstone: It brn, quartz, 2% glauconite, 5- It bm mod 75 dull to yellow pale slow- Fair 10% matdx, v.fn U, sub rdd, well sorted, silica strng bright green straw mod cemented, tr pyr, firm, burrowed stream milky wh Remarks Described by Renee Hannon, Harold Davis, Bob Sperandio AR3B-2389-B AUG 1 0 199 ---...----- Atsst (31 & Gas Cons. Commissi Animate Dar / - Depth Description Oil Oil FluOr Cut Cut Show ft. Stain QJor % IntensityColor color fluor color sum 7305.5' Sandstone: It brn, gry, quartz, tr glauconite, It bm weak 90 dull to yellow pale slow- Fair 10% matrix, v.fn U, sub rdd, well sorted, non- bright green straw mod calc, firm, burrowed, Helmonthopis, tr pyrite stream milky wh 7308' Sandstone: It brn, gry, quartz, tr glauconite, It brn weak 85 dull to yellow pale slow Fair 10% matrix, v.fn U, sub rdd, well sorted, non- bright green straw stream calc, silica cemented, tr pyrite, firm, burrowed milky wh 7311' Sandstone: It bm, gry, quartz, 2-5% It bm mod 95 bright yellow pale mod Fair- glauconite, 5% matdx, v.fn U, sub rdd, well green straw stream Good sorted, non-calc, firm, burrowed milky wh 7314' Sandstone: It brn, quartz, 2% glauconite, 5% It brn mod 97 bright yellow pale mod-fast Good matdx, v.fn U, sub rdd, well sorted, non-calc, strng green straw stream firm, burrowed milky wh 7317' Sandstone: It brn, quartz, 2% glauconite, 5% It brn mod 95 bright yellow pale mod Fair- matrix, v.fn U-v.fn L, sub rdd, well sorted, strng green straw stream Good silica cemented, non-calc, firm, burrowed, milky wh Helmonthopis 7320' Sandstone: It brn, quartz, tr glauconite, 10% It bm mod 90 bright yellow pale mod Fair- matrix, v.fn U-v.fn L, sub rdd, well sorted, green straw stream Good non-calc, firm, burrowed milky wh 7323' Sandstone: It brn, quartz, tr glauconite, 10% It brn weak 85 bright yellow pale slow Fair matrix, v.fn L, sub rdd, well sorted, silica -mod -dull green straw stream cemented, non-calc, firm, burrowed strng milky wh 7326' Sandstone: It brn, quartz, tr glauconite, 5% It bm weak 90 bright yellow pale slow Fair matrix, v.fn L, sub rdd, well sorted, silica green straw stream cemented, tr pyrite, firm, burrowed milky wh 7329' Sandstone: It brn, quartz, tr glauconite, 5% It bm mod 90 bright yellow pale mod Fair matdx, v.fn U, sub rdd, well sorted, silica green straw stream cemented, 2% pyrite, non-calc, firm, milky wh burrowed 7332' Sandstone: It brn, quartz, tr glauconite,10% It bm weak 85 dull yellow pale slow Fair- matrix, v.fn U-v.fn L, sub rdd, well sorted, green straw stream Poor silica cemented, firm, burrowed milky wh 7335.5' Sandstone: It brn, quartz, tr glauconite,5% It bm mod 95 bright yellow pale slow Fair matrix, v.fn L, sub rdd, well sorted, silica green straw stream cemented, firm, burrowed milky wh Remarks Described by Renee Hannon, Harold Davis, Bob Sperandio AR3B-2389~B CORE REPORT ~v~_ ~- ~-;~- COMPANY: ARCO Alaska, Inc NAME: Renee Harmon DEPTHS DRILLERS FEET % RECOVERY % RECOVERY CORE # RECOVERED BIT CORING TIME DATE DEPTHS CUT RECOVERED PER CORE CUMMALTIVE CORE 1 7259-7267' 7259-7265.5' 6.5' 75% ARC 412 w/ 8 hrs 02/28/96 motor 2 7276'-7336' 7276'-7335.5' 59.5' 99 ARC 412 3 hrs 02/29/96 ,. ~EmGEIVED ~v9 1 9 kat 08/16/96 CORE LABORATORIES CORE ANALYSIS REPORT C~!~O ALASKA, INC. ~,~~~ ~0. I WELL CO LVIL[.~i~ ~'~ EXPLORATION FINAL REPORT Performed for: ARCO ALASKA, INC. 700 G Street Rm: ATO1450 Anchorage, Alaska 99501 July 1, 1996 Performed by: CORE LABORATORIES ADVANCED TECHNOLOGY CENTER 1875 Monetary Lane Carrollton, Texas 75006 RECEIVED JUL 1 2 t99G Al~k~ Oil & r~,s con~, Gommi~sioD AHch0rD, ge File' DAL-96063 PETROLEUM SERVICES July 1, 1996 ARCO ALASKA, INC. 700 G Street Rm: ATO1450 Anchorage,Alaska 99501 Attention: Ms. Rene Hannon Reference: Neve No.1 Well Colville Delta Exploration Core Analysis Study File: DAL-96063 Ms. Hannon: Core Laboratories' Advanced Technology Center in Carrollton (Dallas), Texas is pleased to present the final report for a core analysis study performed on 66.0 feet of core material recovered from the referenced well. Preliminary information was provided to the client as it became available. A project summary, description of laboratory procedures, and presentation of results are provided within. Ten copies of this final report have been issued. Large format, table shot white light and ultraviolet photographs of all slabbed whole core material were taken. Copies of all photographs and CD-ROM formats have been provided under separate cover previous to this final reporting. The slabs are currently in storage at Arco's core storage facility in Anchorage, Alaska. The remaining core material (3/4 butt ends) are in storage at our Carrollton, Texas facility. We appreciate this opportunity to have been of service to Arco Alaska, Inc. Please contact us at (214) 466-2673 if you should have any questions regarding this report, or if we may be of further assistance. Sincerely yours, Daniel J Scott Petrophysics Group Core Laboratories, Inc. 1875 Monetary Lane, Carrollton, Texas 75006-7012, (214) 466-2673, Telex 163166, CORDAL UT, Fax (214) 323-3930 ARCO ALASKA, INC. File: DAL-96063 Field Core Retrieval and Shipping Basic Properties Core Photography PROJECT PARTICIPANTS David Sutton Basic Properties Chloride Sample Preparation Dean-Stark Fluid Saturations Dean-Stark and Chloride Calculations and Data Evaluation Basic Properties, Data Evaluation and Report Preparation Jol~Kieschnick Ste[~ . ' Melanie F. Dunn ~ Daniel J. Scot~! Final Review Melanie F. Dunn Core Laboratories ARCO ALASKA, INC. File: DAL-96063 TABLE OF CONTENTS SECTION 1: PROJECT SUMMARY SECTION 2: LABORATORY PROCEDURES SECTION 3: HORIZONTAL PLUG AND TRACER SAMPLE DATA 800 psi Net Overburden SECTION 4: SECTION $: VERTICAL PLUG DATA 800 psi Net Overburden SPECTRAL CORE GAMMA AND CORRELATION COREGRAPH APPENDIX: TRACER ANALYSIS and CHLORIDE CONCENTRATION PROCEDURES Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 1 PROJECT SUMMARY Core Laboratories ARCO ALASKA, INC. File: DAL-96063 PROJECT SUMMARY Core Retrieval and Shipping - Prudhoe Bay, Alaska (Colville Delta Exploration) A Core Laboratories' representative from Anchorage was at the wellsite for initial core handling and transportation. The first conventional core was recovered in the field on February 27, 1996. The core barrel liner containing the core was cautiously laid down on the catwalk and was stdped with red and black markers along its length to maintain uphole orientation. The liner was depth marked (top to bottom), then cut into three foot lengths with a chop saw. End caps were placed on each end of the tubes containing the core and placed into specially constructed wooden shipping crates. The well was drilled to the second core point on February 29, 1996 and the above procedure was repeated. The client selected seven locations in Core 2 for tracer wafers to be cut out and preserved in Saran Wrap and ProtecCoreTM as outlined in the wellsite core handling procedures. The tubes containing core and the tracer samples were placed in the shipping crates and air-freighted to our Carrollton facility for core processing. Core Reception and Processing-Carrollton, Texas The core processing was performed according to a procedural protocol outlined by Arco Alaska, Inc. Two cores totaling 66.0 feet in length were uncrated and laid out, oriented, labeled, marked, and sectioned for routine and special core analysis plug sampling. The cores were then run through Core Laboratories' spectral gamma logger to measure, total gamma counts, and uranium, thodum, and potassium isotopes. Routine horizontal and vertical core plugs were ddlled with Isopar-M. The horizontal plugs were immediately loaded into Dean-Stark glassware for saturation measurements. SCAL plugs were ddlled using humidified nitrogen as the plugging coolant and then were Saran Wrapped, aluminum foiled, CoreSealed, and preserved in aluminum laminate ProtecCoreTM. Routine plug end pieces (tdm ends), special core analysis plug end pieces (trim ends), and wafers were preserved in ProtecCoreTM. Concurrently, a 1/4 slab was taken dudng the core processing. Core chips from each foot were taken for shipment to the State of Alaska..All remaining core material was preserved in Saran Wrap, aluminum foil and CoreSeal. In addition, four mud samples were taken at the wellsite during codng and sent to the Carrrollton laboratory for filtration and analyzed for tracer concentration. All core material (butt ends and slabs), plug samples, and end pieces/wafers were boxed and prepared for distribution. Special additional plugging required three core pieces from Core No.1 to be depreserved (one foot at a time) and 1-1/2 inch horizontal and vertical plugs were taken from the selected pieces. These plugs were Saran Wrapped, aluminum foiled, and placed into an individual ProtecCoreTM pouch. These plugs were delivered to Arco Oil and Gas in Piano, Texas. Laboratory Program Routine plug samples were analyzed in strict accordance with Arco Alaska's protocol described in the laboratory procedures. The horizontal plugs and tracer samples were subjected to Dean-Stark saturation determination, cleaning and drying, permeability, porosity and grain density measurements, and crushing and leaching for bromide and chlodde concentrations. Vertical plug samples were batch cleaned and tested for permeability and porosity. The tracer samples followed Core Laboratories ARCO ALASKA, INC. File: DAL-96063 the same test protocol as the routine horizontal plugs. Laboratory procedures are described in Section 2 and test results are presented in Sections 3 through 5. A summary of sample selection is !isted below: Horizontal Plugs 1 inch dia. Routine Vertical Plugs I inch Special Core Analysis Plugs I 1/2 inch dia. Tracer Sample Cut Out Cubes Additional 1-1/2 inch dia. Plugs Horizontal Additional 1-1/2 inch dia. Plugs Vertical I 6 0 0 0 3 2 2 59 29 101 7 . 0 0 As noted, 101 SCAL plugs, end pieces, and wafers were taken at the Carrollton laboratory. Preliminary data results were provided to the client on a regular basis. A preliminary core analysis report provided on May 13, 1996 included all horizontal plug permeability and porosity, grain density, water and filtrate saturation data. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 2 LABORATORY PROCEDURES Core Laboratories ARCO ALASKA, INC. File: DAL-96063 LABORATORY PROCEDURES Laboratory analytical and quality control procedures used dudng the analysis of the core from the Neve No. 1 well followed the procedural guidelines set forth by Arco Alaska, Inc. and under the supervision of AEPT representatives. Any modifications or additions to the wdtten protocol were by request or by approval of Arco Alaska, Inc. · Surface Core Gamma Logging Before the commencement of spectral gamma logging of each core run, the equipment was checked with a calibration cylinder. The check cylinder contains known concentrations of the following elements: K = 4.0%, Th --' 24 ppm, U = 12 ppm, with a total gamma ray count of 200 APl units.. If the equipment was observed to measure values outside the tolerance limits, then a recalibration routine was initiated using individual standard calibration tubes. The core spectral gamma logger utilizes a Na-I detector of similar configuration to downhole log detectors, and an anti-coincidence shield around the detector to greatly reduce background radiation and reduce Compton scattering to improve the signal to noise ratio. The core travels over the detector under the protection of lead shielding at a slow rate of two minutes per foot. A multi-channel analyzer is interfaced with a PC for digitized data acquisition. Core gamma data was processed and plotted in depth versus total and uranium-free gamma (APl units), potassium (%), and thodum and uranium (ppm), at a vertical scale of 5" = 100 feet and is presented in Section 5 of this report. Preliminary plots were sent to the client as soon as they became available. · Slabbing Following the core gamma logging process, a 1/4 slab was trimmed in our Carrollton Laboratory using a slab saw cooled with liquid nitrogen mist. Slabbing was performed relative to the yellow and white orientation lines drawn on the up dip side of the core. The 1/4 section was then carefully cleaned, labeled and placed in core slab presentation boxes (about nine feet of core per box) with styrofoam liners. The 1/4 slab section was prepared for core photography. · Plugging Routine horizontal and vertical core plugs were ddlled with Isopar-M. The horizontal plugs were immediately loaded into Dean-Stark glassware for saturation measurements. SCAL plugs were ddlled using humidified nitrogen as the plugging coolant and then were Saran Wrapped, aluminum foiled, CoreSealed, and preserved in aluminum laminate ProtecCoreTM. Routine plug end pieces (trim ends), special core analysis plug end pieces (trim ends), and wafers were preserved in ProtecCoreTM. Core chips from each foot were taken for shipment to the State of Alaska. All remaining core material was preserved in Saran Wrap, aluminum foil and CoreSeal. All core matedal (butt ends and slabs), plug samples, and end pieces/wafers were boxed and prepared for distribution. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 · Core Photography The 1/4 longitudinal cuts of core were used for white light and ultraviolet core photography after careful cleaning and preparation of the rock. Large format (approximately 18 feet per frame) shots were taken and photographs were provided in both white light and UV 8x10 inch prints. CD-ROM formats were also provided of the core photos. Following photography the 1/4 slabbed core was shipped to Arco Alaska's core storage facility in Anchorage on March 4, 1996. · Plug Samples The preserved special core analysis plug samples, end pieces and wafers were submitted to AEPT representatives along with core processing data sheets, and routine plug samples were retained for analysis by Core Laboratories. The horizontal plug and tracer samples were then forwarded to the extraction room for Dean-Stark analysis. The vertical plugs were batch cleaned using toluene followed by chloroform. · Dean-Stark Analysis Each Dean-Stark flask and associated glassware were cleaned and dded before use. The condenser, core chamber and flask were rinsed 5 times with 20cc of fresh reagent grade toluene before adding toluene to the apparatus for pre-boiling. The sidearm was checked for water and pure toluene was transferred from sidearm to flask, the sidearm was then dried. Each core plug sample was removed from its Saran Wrap seal, then weighed to 0.001 g, placed in a predded and prelabelled thimble and weighed again. Each plug and thimble was then loaded into the Dean-Stark apparatus. The system was sealed with Teflon tape to prevent leakage and capped with desiccant to prevent the introduction of condensed atmospheric water. Water volume in each Dean-Stark receiving tube was monitored during the toluene refluxing until stabilization. A wire was used to swab off any water droplets from the neck of the condenser. A record of time and water volumes was kept for each sample. Extraction time for each sample was approximately 48 hours. After extraction, the flask and contents were removed. The toluene in the side arm was removed and added to the flask. The water recovered in the side arm was poured into a storage bottle, sealed, and labeled for possible tracer analysis. · Sample Drying Each core plug and thimble was dded in a convection oven at 180°F for four hours, followed by 24 hours drying in a vacuum oven at 180°F. Sample weights were monitored approximately every 4 to 24 hours until weight stabilization (+/- .01 g) was achieved. After drying, each plug and thimble was allowed to cool in a desiccator and then weighed to 0.001 g. Each plug was removed from its thimble and carefully brushed to remove fines, labeled and reweighed. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 · Grain Volume Determination Grain volumes were measured using the Boyle's law AutoporosimeterTM which was calibrated and checked with a known volume steel disk and Berea Sandstone (2.65 g/cc) check plug before each run. Plug samples and tracer samples were kept in a desiccator until ready for grain volume measurement. After every five samples, the steel check disk was measured to ensure correct equipment operation. Equipment recalibration was performed a minimum of twice a day or as needed. Grain densities (gm/cc) were calculated using the dry sample weight (gm) and grain volume (cc). · Mercury Bulk Volume Determination Bulk volumes of the tracer samples were determined by mercury immersion. Pore volume and porosity of the tracer samples were calculated as follows: PV = BV - GV CD = PV/BV x 100 Where: PV = Pore volume, cc . CD = Porosity, percent BV = Mercury bulk volume, cc GV = Grain volume, cc · Plug Porosity and Permeability Measurements by CMS-300TM Horizontal plug samples were measured for permeability and porosity by the CMS-300TM at 800 psi net overburden. Before each group of samples was run, a standard system leak test was performed to ensure correct equipment operation. Calibrated, known volume check cylinders were run before and with each carousel suite of samples. The Klinkenberg (slip corrected) permeability for each plug sample was determined as a function of pressure decay (helium blow-down). A reference cell of known volume charged the sample with helium. A downstream valve vented the sample to atmosphere, and the change in pressure with time was monitored. The multiple flow regime data allowed the determination of Klinkenberg permeability of the sample, a calculated air permeability, along with parameters helium slip factor (b) and the inertial resistance factor (g) beta. Any plug with permeability to air of 3000 md or more was remeasured using the Autopermeameter (a steady-state device), which has greater accuracy in measuring higher permeability samples, and the Autopermeameter data was reported. Porosity for each plug sample was calculated using Boyle's law by the CMS-300TM with grain volume and pore volume by: Where: CD = PV · 100 PV + GV CD = Porosity, percent PV = Pore volume at net confining pressure, cc GV = Grain volume, cc Core Laboratories ARCO ALASKA, INC. File: DAL-96063 Data was downloaded to diskette, imported to the core analysis report software, and preliminary data printouts were provided to the client regularly. Samples unsuitable for CMS-300TM testing were subjected to ambient condition porosity and profile (probe) permeability testing and are noted in the tabular data. The horizontal plug data is presented with the fluid saturation data in tabular format in Section 3. · Vertical Plugs A vertical plug was taken every other foot on an odd depth mark just below the horizontal plug. The slabbed four inch routine core section adjacent to the horizontal plug sampling points were used to obtain vertical plug samples. Testing of vertical plug samples included permeability and porosity by CMS-300TM at 800 psi confining pressure and grain density measurements. The results are found in Section 4. · Tracer Analysis Following permeability and porosity measurements, all horizontal samples, as well as the designated tracer sections, were crushed and leached as outlined in the Appendix. Bromide and chloride analyses on the extracts were performed by subcontractor Peak Analytical, Inc. using ion chromatography. Bromide and Chloride concentrations were provided by Peak Analytical, Inc. to Core Laboratories for filtrate saturation calculations. Drilling mud filtrate concentrations were also measured by Peak Analytical, Inc. for core filtrate calculations. Filtrate saturation calculation equations used were provided by the client and are found in the Appendix of this report. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 3 HORIZONTAL PLUG AND TRACER SAMPLE DATA 800 psi NOB Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Dean Stark Dean Stark Dean Stark Dean Stark Dean Stark Net Permeability, Water Oil Total Chlodde Bromide Grain Depth, Confining millidarcys Porosity, Saturation, Saturation, Saturation,:Conc., Conc., Density, Core Number feet Pressure Klinkenberg.ij . .t° Air percent ._ perce.nt % pv .... % pv ..... ppm. ppm .... II/CC 1 I 7259.15 800 0.015 0.029 11.7 100.0 0.0 100.0 11689. 124.76 2.70 1 2 7260.05 800 0,086 0.116 11.1 100.0 0.0 100.0 5547. 84.50 2.69 I 3 7261.05 800 0.016 0.034 11.1 100.0 0.0 100.0 8312. 114.58 2.69 1 4 7262.05 800 0.031 0.045 9.2 100.0 0.0 100.0 4572. 96.17 2.68 1 5 7263.05 800 1.56 1.60 9.4 100.0 0.0 100.0 4508. 96.64 2.66 I 6 7263.95 800 0.691 0.734 9.0 100.0 0.0 100.0 4251. 84.71 2.69 2 I 7276.25 800 0.136 0.253 14.5 56.4 36.6 93.0 22539. 161.64 2.66 2 2 7277.05 800 0.108 0.204 16.7 43.1 38.4 81.5 sample broke 2.67 2 3 7277.95 800 0.031 0.066 11.5 70.3 24.4 94.7 14460. 62.33 2.67 2 4 7279.30 800 0.790 1.13 17.8 36.9 39.9 76.8 21365. 141.62 2.66 2 5 7280.05 800 4.37 5.36 20.8 22.6 51.1 73.7 19498. 173.13 2.66 2 6 7281.05 800 1.77 2.31 17.4 29.2 19.2 48.4 18951. 52.37 2.66 2 7 7282.10 800 1.54 2.07 19.3 26.5 51.6 78.1 17587. 63.20 2.66 2 8 7283.05 800 1.43 1.93 18.7 27.6 54.0 81.6 18307. 47.06 2.65 2 9 7284.05 800 4.48 5.49 20.2 21.2 54.4 75.6 18866. 60.91 2.66 2 10 7285.05 800 6.20 7.45 19.9 24.0 56.1 80.1 16883. 106.62 2.65 2 11 7286.05 800 2.04 2.60 17.2 43.0 37.2 80.2 19874. 341.71 2.68 2 12 7287.05 800 2.87 3.60 18.3 29.4 48.1 77.5 15632. 123.55 2.66 2 13 7288.15 800 9.76 11.4 20.5 19.8 68.1 87.9 20517. 76.94 2.65 2 14 7289.05 800 5.04 6.15 20.6 24.2 47.4 71.6 13149. 123.24 2.66 2 15 7290.05 800 7.62 9.09 18.0 28.9 52.0 80.9 23275. 149.48 2.66 2 16 7291.05 800 10.6 12.4 21.0 18.2 64.7 82.9 17049. 113.00 2.65 2 17 7292.05 800 1.45 1.65 20.9 18.6 57.3 75.8 17233. 104.54 2.65 2 18 7293.05 800 3.99 4.95 18.7 25.5 55.1 80.6 17035. 144.76 2.66 2 19 7294.05 800 7.89 9.32 20.3 24.9 51.0 75.9 15715. 89.94 2.66 2 20 7295.05 800 1.81 2.37 18.6 30.1 77.0 107.1 18392. 59.04 2.66 Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Dean Stark Dean Stark Dean Starkl Dean Stark Dean Stark Net Permeability, Water Oil Total Chlodde Bromide Grain Depth, Confining millidarcys Porosity, Saturation, Saturation, Saturation, Conc., Conc., Density, Core Number feet Pressure Klinkenberg I to Air pement percent % pv % pv ppm PPm g/cc 2 21 7296.05 800 5.77 6.94 19.8 27.4 52.8 80.2 19542. 346.26 2.66 2 22 7297.15 800 1.83 2.49 19.4 23.7 42.6 66.3 18160. 81.43 2.65 2 23 7298.05 800 3.76 4.66 18.9 27.1 51.6 78.7 15209. 88.53 2.66 2 24 7299.05 800 3.69 4.60 20.2 24.2 53.2 77.4 15512. 66.60 2.66 2 25 7300.05 800 0.057 0.110 12.9 55.1 32.5 87.6 17806. 0.00 2.67 2 26 7301.05 800 0.570 0.766 16.3 34.8 41.6 76.4 17634. 36.43 2.66 2 27 7302.05 800 2.13 2.77 20.2 23.9 19.6 43.4 17974. 55.40 2.66 2 28 7302.95 800 0.53 0.73 16.4 32.2 48.4 80.6 19855. 45.79 2.66 2 29 7304.05 800 1.66 2.19 19.2 27.9 49.3 77.2 13256. 79.21 2.66 2 30 7305.05 800 0.708 1.02 18.6 30.5 48.4 78.9 12152. 45.51 2.66 2 31 7306.05 800 2.73 3.49 21.0 28.5 46.4 75.0 15794. 70.85 2.65 2 32 7307.05 800 11.7 13.4 21.1 24.3 69.3 93.6 13626. 63.49 2.65 2 33 7308.05 800 1.50 2.06 18.9 30.2 44.2 74.4 17827. 58.84 2.66 2 34 7309.05 800 0.022 0.042 11.3 41.2 34.5 75.7 15315. 120.05 2.73 2 35 7310.05 800 0.0035 0.0087 7.3 59.7 18.9 78.6 12073. 74.89 2.75 2 36 7311.05 800 2.96 3.81 19.9 28.3 51.1 79.4 25312. 123.99 2.65 2 37 7312.05 800 2.58 3.28 19.5 28.7 44.4 73.1 15493. 60.13 2.65 2 38 7313.05 800 1.87 2.46 18.1 30.3 51.0 81.3 17532. 98.93 2.65 2 39 7314.10 800 0.622 0.895 16.9 35.0 38.8 73.8 10987. 37.72 2.65 2 40 7315.05 800 0.696 0.994 16.6 36.2 41.6 77.8 16042. 73.95 2.65 2 41 7316.05 800 3.51 4.36 19.3 25.7 48.0 73.7 16466. 71.88 2.65 2 42 7317.05 800 4.42 5.42 19.9 25.0 56.7 81.7 16842. 78.77 2.65 2 43 7318.05 800 8.97 10.5 20.7 21.8 58.9 80.8 11066. 56.47 2.65 2 44 7319.05 800 1.83 2.39 18.9 26.3 54.4 80.7 17352. 69.86 2.66 2 45 7320.20 800 1.11 1.50 17.6 33.2 42.6 75.8 14394. 78.87 2.66 2 46 7321.05 800 6.82 8.13 20.9 20.6 60.1 80.7 17370. 72.43 2.65 Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Dean Stark Dean Stark Dean Stark Dean Stark Dean Stark Net Permeability, Water Oil Total Chlodde Bromide Groin Depth, Confining millidarcys Porosity, Saturation, Saturation, Saturation, Conc., Conc., Density, Core Number feet Pressure Klinkenberg I to Air percent percent % pv % pv ppm ppm g/cc 2 47 7322.05 800 1.42 1.89 18.9 27.8 52.6 80.4 17791. 98.94 2.65 2 48 7323.10 800 1.88 2.47 19.1 28.0 47.6 75.7 15974. 75.32 2.65 2 49 7324.05 800 2.30 2.94 19.5 27.2 45.4 72.6 15085. 85.60 2.65 2 50 7325.05 800 1.63 2.17 19.1 25.6 52.2 77.9 16528. 83.60 2.65 2 51 7326.10 800 1.51 2.02 18.4 28.1 46.9 75.0 14226. 70.25 2.66 2 52 7327.05 800 5.84 7.03 20.9 22.0 58.0 80.0 14729. 97.48 2.65 2 53 7328.05 800 1.18 1.59 18.0 28.4 47.7 76.1 16726. 92.02 2.65 2 54 7329.05 800 1.48 1.97 17.7 28.4 50.1 78.5 15092. 115.29 2.65 2 55 7330.05 800 1.60 2.12 19.1 27.7 49.3 77.0 13652. 107.45 2.66 2 56 7331.05 800 2.24 2.86 19.1 27.8 49.4 77.2 15092. 74.46 2.66 2 57 7332.05 800 2.43 3.09 19.2 29.6 47.3 76.9 12644. 76.32 2.65 2 58 7333.05 800 2.08 2.68 19.7 29.9 47.2 77.1 13911. 57.29 2.65 2 59 7334.05 800 1.07 1.42 17.1 36.2 40.8 77.0 14506. 62.76 2.67 Average Values at 800 psi net confining stress: 2.69 3.32 17.7 36.8 43.4 80.1 15652. 92.96 2.66 Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS Salt and Filtrate Corrected Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Wt. Loss Wt. Loss Adjusted Adjusted Wt. Loss Filt. Corr. Salt Corr. Salt Corr. Salt Corr. Salt Corr. Adjusted Salt Corr. Chlodde Dean Stark Dean Stark Dean Stark Salt Corr. Connate Conc. Net Permeability, Salt Corr. Water Oil Total Filtrate Water in Connate Depth, Confining millidarcys Porosity, Saturation, Saturation, Saturation, Saturation .Saturation, Water, Corn Number feet Pressure Klinkenberg I to Air percent % pv % @v % pv % pv % pv ppm I 1 7529,15 800 0,015 0,029 11,8 100,0 0,0 I 2 7260,05 800 0,086 O, 116 11,2 100,0 0,0 1 3 7261,05 800 0,016 0,034 11,2 100,0 0,0 1 4 7262,05 800 0,031 0,045 9,2 100,0 0,0 I 5 7263,05 800 1,56 1,60 9,4 100,0 0,0 1 6 7263,95 800 0,691 0,734 9,1 100,0 0,0 2 1 7276,25 800 0,136 0,253 14,7 56,0 36,0 2 2 7277,05 800 0,108 0,204 2 3 7277,95 800 0,031 0,066 11.6 69,8 24,1 2 4 7279,30 800 0,790 1,13 17,9 36,8 39,4 2 5 7280,05 800 4,37 5.36 20.9 22,6 50,6 2 6 7281,05 800 1,77 2.31 17,4 29.1 19.0 2 7 7282,10 800 1,54 2,07 19,3 26,5 51.3 2 8 7283,05 800 1,43 1.93 18.8 26,8 53,6 2 9 7284,05 800 4,48 5,49 20,3 21,2 54,0 2 10 7285,05 800 6,20 7,45 20,0 24,0 55,6 2 11 7286,05 800 2,04 2,60 17,3 42,7 36,7 2 12 7287,05 800 2,87 3,60 18,4 29,3 47,6 2 13 7288,15 800 9,76 11,4 20,5 19,8 67,7 2 14 7289,05 800 5.04 6.15 20,7 24,0 47,0 2 15 7290,05 800 7,62. 9,09 18,1 28,8 51,4 2 16 7291,05 800 10,6 12,4 21,0 18,2 64,1 2 17 7292,05 800 1.45 1.65 21.0 18,5 56.8 2 18 7293,05 800 3,99 4,95 18,8 25.5 54,6 100,0 3,7 100,0 10782, 100,0 2,1 100,0 5019, 100,0 3,3 100,0 7483, 100,0 2,9 100,0 3903. 100,0 3,0 100,0 3832, 100,0 2,4 100,0 3712, 92,0 3,0 52,9 21352, sample broke 94.0 0.7 69.2 13986. 76.2 1.7 35.1 20271. 73.3 1.3 21.3 18275. 48.2 0.1 29.0 18338. 77.7 0.3 26.2 16986. 80.3 0.1 26.7 17750. 75.2 0.2 21.0 18215. 79.6 0.7 23.3 16054. 79.4 5.8 36.9 17764. 76.9 1.1 28.2 14718. 87.5 0.3 19.5 19710. 71.0 0.9 23.2 12252. 80.2 1.4 27.4 22109. 82.3 0.6 17.6 16177. 75.3 0.5 18.0 16407. 80.0 1.2 24.3 15975. Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS Salt and Filtrate Corrected Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Wt. Loss Wt. Loss Adjusted Adjusted Wt. Loss Filt. Corr. Salt Corr. Salt Corr. Salt Corr. Salt Corr. Adjusted Salt Corr. Chlodde Dean Stark Dean Stark Dean Stark Salt Corr. Connate Conc. Net Permeability, Salt Corr. Water Oil Total Filtrate Water in Connate Depth, Confining millidarcys Porosity, Saturation,:Saturation,:Saturation, Saturation :Saturation. Water, Core Number feet Pressure Klinkenberg I to Air percent % pv % pv % pv % pv % pv 2 19 7294.05 800 7.89 9.32 20.3 24.8 50.6 75.4 0.5 24.3 15018. 2 20 7295.05 800 1.81 2.37 18.6 30.0 76.3 106.3 0.2 29.8 17771. 2 21 7296.05 800 5.77 6.94 19.9 27.3 52.1 79.4 3.7 23.5 17372. 2 22 7297.15 800 1.83 2.49 19.5 23.6 42.2 65.8 0.4 23.2 17433. 2 23 7298.05 800 3.76 4.66 18.9 26.9 51.1 77.9 0.6 26.3 14534. 2 24 7299.05 800 3.69 4.60 20.2 24.1 52.6 76.7 0.3 23.8 14970. 2 25 7300.05 800 0.057 0.110 13.0 54.8 32.1 86.9 0.0 54.8 17309. 2 26 7301.05 800 0.570 0.766 16.4 34.6 41.1 75.7 0.0 34.6 17145. 2 27 7302.05 800 2.13 2.77 20.3 23.2 18.9 42.1 0.1 23.1 17391. 2 28 7302.95 800 0.53 0.73 16.5 32.1 47.9 80.0 0.1 32.0 19216.. 2 29 7304.05 800 1.66 2.19 19.3 27.8 48.8 76.7 0.5 27.4 12694. 2 30 7305.05 800 0.708 1.02 18.6 30.4 48.0 78.5 0.1 30.4 11881. 2 31 7306.05 800 2.73 3.49 21.1 28.4 45.9 74.4 0.4 28.0 15216. 2 32 7307.05 800 11.7 13.4 21.2 24.1 68.4 92.5 0.2 23.8 13171. 2 33 7308.05 800 1.50 2.06 18.9 30.1 43.7 73.8 0.2 29.8 17234. 2 34 7309.05 800 0.022 0.042 11.3 41.1 34.2 75.3 1.5 39.6 14427. 2 35 7310.05 800 0.0035 0.0087 7.4 59.5 18.7 78.2 0.9 58.6 11571. 2 36 7311.05 800 2.96 3.81 20.0 28.1 50.2 78.4 1.0 27.1 24148. 2 37 7312.05 800 2.58 3.28 19.6 28.5 43.8 72.2 0.2 28.2 14992. 2 38 7313.05 800 1.87 2.46 18.1 30.1 50.3 80.4 0.8 29.3 16733. 2 39 7314.10 800 0.622 0.895 16.9 34.7 38.4 73.1 0.0 34.7 10795. 2 40 7315.05 800 0.696 0.994 16.6 35.9 41.0 76.9 0.5 35.4 15437. 2 41 7316.05 800 3.51 4.36 19.4 25.5 47.4 72.9 0.4 25.2 15857. 2 42 7317.05 800 4.42 5.42 19.9 24.7 55.7 80.5 0.4 24.3 16179. Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS Salt and Filtrate Corrected Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Wt. Loss Wt. Loss Adjusted Adjusted Wt. Loss Filt. Corr. Salt Corr. Salt Corr. Salt Corr. Salt Corr. Adjusted Salt Corr. Chloride Dean Stark Dean Stark Dean Stark Salt Corr. Connate Conc. Net Permeability, Salt Corr. Water Oil Total Filtrate Water in Connate Depth, Confining millidarcys Porosity, Saturation, Saturation, Saturation, Saturation Saturation, Water, Core Number feet Pressure Klinkenberg I to Air percent % 13v % pv % pv % @v % pv ppm 2 43 7318.05 800 8.97 10.5 20.7 21.7 58.2 79.9 0.2 21.5 10740. 2 44 7319.05 800 1.83 2.39 18.9 26.0 53.5 79.4 0.3 25.6 . 16718. 2 45 7320.20 800 1.11 1.50 17.7 33.1 42.1 75.1 0.6 32.5 13807. 2 46 7321.05 800 6.82 8.13 21.0 20.4 59.2 79.6 0.3 20.1 16722. 2 47 7322.05 800 1.42 1.89 18.9 27.5 51.8 79.3 0.7 26.8 16983. 2 48 7323.10 800 1.88 2.47 19.2 27.8 46.9 74.7 0.4 27.3 15362. 2 49 7324.05 800 2.30 2.94 19.5 27.2 45.1 72.3 0.5 26.7 14433. 2 50 7325.05 800 1.63 2.17 19.2 25.5 51.7 77.2 0.5 25.0 15846. 2 51 7326.10 800 1.51 2.02 18.5 27.9 46.4 74.4 0.4 27.6 13704. 2 52 7327.05 800 5.84 7.03 21.0 21.9 57.4 79.3 0.6 21.3 14004. 2 53 7328.05 800 1.18 1.59 18.1 28.0 46.8 74.8 0.6 27.4 15988. 2 54 7329.05 800 1.48 1.97 17.8 28.2 49.4 77.7 0.9 27.3 14239. 2 55 7330.05 800 1.60 2.12 19.2 27.4 48.6 76.0 0.8 26.6 12872. 2 56 7331.05 800 2.24 2.86 19.2 27.4 48.4 75.9 0.4 27.0 14515. 2 57 7332.05 800 2.43 3.09 19.3 29.2 46.6 75.8 0.5 28.8 12119. 2 58 7333.05 800 2.08 2.68 19.8 29.4 46.1 75.5 0.2 29.1 13490. 2 59 7334.05 800 1.07 1.42 17.2 35.8 40.1 75.9 0.4 35.4 14027. Average Values at 800 psi net confining stress: 2.69 3.32 17.7 36.5 42.9 79.4 0.9 35.8 14924. Core Laboratories i@O0.O 0 0 0 N Permeability vs. Porosity @.OOi 0.0 / / Porosity (Boyies Law He)' ~ 800 psi Salt Corrected N®v~ N0. i ~o~'~ No.l 7a76.0-7~3~.0 f~ Colviile Delta Permeability Histogram lO0 7O 60 40 3O / / / / / / / / / / / / ~0 tO 0 .$4 . tt~ .78 Horizontal K1 Permeability: md 800 psi ia. md-ft t40.0 t~O. 0 800.0 ~ 60 · 0 '~ 4@.@ ~0.0 7@ ~G ii} Porosity Histogram Porosity (Boylss Law He)' % 800 Salt CoP ~-ft SUMMARY OF TRACER ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well Depth, Core Number feet Porosity, percent I Dean Stark I Dean Stark WaterI Oil Saturation, Saturation percent % pv 2-4 1T4 7279.0 13.5 48.2 22.3 2-4 3T4 7279.0 14.2 44.9 24.7 2-4 5T4 7279.0 13.9 48.7 18.9 2-13 IT13 7288.0 20.9 21.9 36.6 2-13 3T13 7288.0 20.4 25.0 33.6 2-13 5T13 7288.0 20.8 37.2 23.5 2-22 1T22 7297.0 20.1 25.8 37.1 2-22 3T22 7297.0 20.6 28.1 25.7 2-22 5T22 7297.0 19.7 40.7 25.2 2-30 1T30 7305.5 19.9 35.1 25.6 2-30 3T30 7305.5 20.0 37.1 27.4 2-30 5T30 7305.5 20.0 40.7 22.6 2-39 1T39 7314.0 20.3 24.8 40.4 2-39 3T39 7314.0 19.9 25.0 38.4 2-39 5T39 7314.0 19.8 35.0 25.5 2-48 1T48 7323.0 18.7 25.5 34.3 2-48 3T48 7323.0 19.3 27.2 34.6 2-48 5T48 7323.0 18.9 41.9 36.5 2-54 1T54 7329.0 18.9 25.2 37.8 2-54 3T54 7329.0 19.5 25.5 36.5 2-54 5T54 7329.0 18.9 40.0 21.3 Colville Delta Exploration File: DAL-96063 Dean StarkI Dean StarkI Dean StarkI Total I Chloride I Br°mide I Saturation,I Conc., I Conc., I %pv I ppm I DPm I Grain Density, g/cc 70.5 15175. 89.12 2.66 69.6 16118. 101.02 2.67 67.6 26635. 961.78 2.67 58.5 17417. 112.55 2.68 58.7 18218. 269.92 2.66 60.7 28161. 1428.43 2.68 62.9 15356. 126.16 2.67 53.8 16521. 141.03 2.67 65.9 27699. 1355.41 2.65 60.8 21197. 611.42 2.66 64.6 23785. 727.13 2.66 63.3 28570. 1515.15 2.68 65.2 16258. 124.38 2.66 63.4 15639. 179.35 2.65 60.5 25979. 1222.35 2.65 59.9 16415. 97.62 2.65 61.8 15411. 177.20 2.68 78.4 37285. 819.22 2.66 63.0 14006. 105.63 2.65 62.1 21380. 111.08 2.66 61.2 25081. 1103.21 2.65 Average Values: 19.0 33.5 29.9 63.4 21062. 541.86 2.66 Core Laboratories SUMMARY OF TRACER ANALYSIS TEST RESULTS salt and Filtrate Corrected Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Depth, Core Number feet 2-4 1T4 7279.O 2-4 3T4 7279.0 2-4 5T4 7279.0 2-13 1T13 7288.0 2-13 3T13 7288.0 2-13 5T13 7288.0 2-22 1T22 7297.0 2-22 3T22 7297.0 2-22 5T22 7297.0 2-30 1T30 7305.5 2-30 3T30 7305.5 2-30 5T30 7305.5 2-39 1T39 7314.0 2-39 3T39 7314.0 2-39 5T39 7314.0 2-48 1T48 7323.0 2-48 3T48 7323.0 2-48 5T48 7323.0 2-54 1T54 7329.0 2-54 3T54 7329.0 2-54 5T54 7329.0 Salt Corr. Porosity, percent 13.6 14.3 14.0 21.0 20.5 21.0 20.2 20.6 19.9 20.0 20.1 20.2 20.4 20.0 20.3 19.1 19.3 19.2 19.0 19.6 19.1 Wt. Loss Adjusted Salt Corr. Dean Stark Water Saturation, % pv 48.2 44.9 48.6 21.8 25.0 37.0 25.6 28.0 40.8 35.1 37.1 40.4 24.8 25.1 34.8 25.5 27.2 42.1 25.2 25.5 39.6 Wt: Loss Adjusted Salt Corr. Dean Stark Oil Saturation % pv 22.1 24.6 18.7 36.3 33.3 23.1 36.6 25.4 25.0 25.4 27.1 22.2 40.2 38.2 25.1 34.1 34.3 36.1 37.6 36.2 20.8 Salt Corr. Dean Stark Total Saturation % pv 70.4 69.5 67.3 58.1 58.3 60.1 62.2 53.4 65.8 60.5 64.2 62.7 65.1 63.3 59.9 59.6 61.5 78.2 62.8 61.7 60.4 Wt. Loss Adjusted Salt Corr. Filtrate Saturation % pv 1.0 1.2 20.1 0.7 2.6 23.0 1.0 1.3 24.1 9.0 11.4 26.7 0.9 1.6 18.5 0.6 1.7 14.6 0.7 0.8 18.9 Filt. Corr. Salt Corr. Connate Water Saturation, % pv 47.2 43.7 28.5 21.1 22.4 14.0 24.6 26.7 16.7 26.1 25.6 13.7 23.9 23.5 16.3 24.8 25.5 27.5 24.5 24.7 20.7 Salt Corr. Chloride Conc. in Connate Water, ppm 14499. 15343. 23316. 16542. 16415. 24O76. 14426. 15488. 23405. 17636. 20314. 24658. 15331. 14343. 20674. 15651. 14126. 38608. 13235. 20402. 19899. Average Values: 19.1 33.4 29.7 63.1 8.6 24.8 18971. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 4 VERTICAL PLUG DATA 800 psi NOB Core Laboratories CORE ANAI~'IS RESULTS(CMS-300 Hydrosta Confinement) ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File:DAL-96063 1-Jul-96 Net Overburden Pressure: 800 psi Plug Permeability Grain Core Plug Depth, Klinkenberg, I to Air, Porosity, Density, Number Number feet millidarcysI millidarcys percent gm/cc Core Analysis Data for the Vertical Plugs 2 2v 7277.25 0.05 0.10 17.2 2.66 2 4v 7279.25 0.65 0.96 18.6 2.65 2 6v 7281.25 1.01 1.44 18.7 2.65 2 8v 7283.25 0.88 1.26 19.4 2.65 2 10v 7285.25 1.40 1.89 19.0 2.66 2 12v 7287.25 0.77 1.09 17.7 2.66 2 14v 7289.25 4.33 5.53 20.8 2.65 2 16v 7291.25 9.12 10.8 21.9 2.64 2 18v 7293.25 1.27 1.72 18.3 2.68 2 20v 7295.25 0.97 1.36 17.7 2.66 2 22v 7297.30 3.64 4.59 20.3 2.6'~ 2 24v 7299.25 0.99 1.39 19.0 2.66 2 26v 7301.25 0.20 0.33 17.2 2.65 2 28v 7303.15 0.16 0.30 17.3 2.67 2 30v 7305.25 0.32 0.51 19.0 2.66 2 32v 7307.25 0.31 0.50 17.5 2.67 2 34v 7309.25 0.12 0.17 11.3 2.74 2 36v 7311.25 1.30 1.78 19.5 2.65 2 38v 7313.25 0.84 1.19 18.6 2.68 2 40v 7315.25 0.55 0.84 18.5 2.65 2 42v 7317.25 1.85 2.44 19.4 2.65 2 44v 7319.25 1.18 1.65 19.7 2.65 2 46v 7321.25 0.95 1.35 18.6 2.65 2 48v 7323.33 0.75 1.07 18.5 2.66 2 50v 7325.25 0.36 0.56 17.6 2.65 2 52v 7327.25 1.17 1.60 19.4 2.66 2 54v 7329.25 1.25 1.72 19.2 2.66 2 56v 7331.25 0.92 1.29 18.8 2.65 2 58v 7333.25 0.61 0.90 18.9 2.65 Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION SPECTRAL GAMMA LOG AND CORRELATION COREGRAPH Core Laboratories Correlation Coregraph UF Gamma AP]: 0~_ ~.50 7~GO 7~0 7~0 ........... ~ ' ......................... ARCO ALASKA, INC. File: DAL-96063 APPENDIX Core Laboratories TRACER ANALYSIS and CHLORIDE CONCENTRATION PROCEDURES Core Laboratories Appendix 1 TRACER ANALYSIS 1. Use the routine horizontal core plug for bromide ion analysis, redry if necessary. 2. Allow the sample to cool and record dry weight. . Crush sample in mortar and pestle. Transfer crushed material to tared flask and weight. Rinse mortar and pestle with distilled water into flask and weigh again. Use 3 cm3 distilled water per gram of rock. 4. Extract with continuous shaking overnight in a wrist shaker. 5. Analyze blank samples of distilled water for bromide and chloride using ion chromatograph. 6. Filter supernatant liquid (at least 10cc) through .45 micron cellulose nitrate cartridge filter. 7. Analyze extract samples for bromide and chloride using ion chromatograph. 8. Provide the following data: a. Initial weight b. Dean-Starkwater volume c. Archimedes weight in toluene and weight in air d. Toluene temperature e. Bulk volume f. Dry weight g. Grain volume h. Crushed rockweight I. Flasktare weight j. Rock transfer weight k. Liquid transfer weight I. Water saturation, oil saturation, porosity, and grain density m. Bromide and chloride concentration measured by ion chromatograph 9. Calculations were made from the observed and data using formulas specified by Dr. Jake Rathmell of Arco (see following page). EQUATIONS USED FOR CALCULATION OF POROSITY, GRAIN DENSITY, SATURATIONS AND CHLORIDE CONCENTRATION Dean Stark Salinity 1 DS Chlodde(ppm) =Meas. Extr CI*(DS grain wt/Crushed grain wt)*Extr, water wt/(DS water vol.*Water dens) 2 DS NaCl(ppm) = DS Chloride*58.5/35.5 Iter O Salt Corrected Salinity 3 Salt Corr Cl(ppm) = Meas. Extr CI*(DS grain wt/Crushed grain wt)*(Extr, Water wt./(1- Extr. NaCI/10^6))/(VVater dens.*DS water vol/(1-DS NaCI/10^6)) 4 Salt Corr NaCl(ppm) = Salt Corr C1'58.5/35.5 Inter 1 Salt Corr Salinity 5 Salt Corr Cl(ppm)(Iter 1)= Meas. Extr CI*(DS grain wt/Crushed grain wt)*(Extr. Water wt./(1-Extr. NaCI/10^6))/(Water dens.*DS water vol/(1- Sit Corr NaCl(Iter 0)/10^6)) 6 Salt Corr NaCl(ppm)(Iter 1) = Salt Corr C1'58.5/35.5 Inter 2 Salt Corr Salinity 7 Salt Corr Cl(ppm)(Iter 2)= Meas. Extr CI*(DS grain wt/Crushed grain wt)*(Extr. Water wt./(1 -Extr. NaCI/10^6))/(Water dens.*DS water vol/(1 - Salt Corr NaCl(Iter 1 )/10^6)) 8 Salt Corr NaCl(ppm)(Iter 2) = Salt Corr C1'58.5/35.5 Salt Corrected Iodide in Dean Stark Water 9 DS Iodide(ppm) =Meas. Extr. Iodtde*(DS grain wt/Crushed grain wt)*Extr, water wt/(DS water vol.*Water dens) 10 Salt Corr DS I(ppm)= Meas. Extr Iodide*(DS grain wt/Crushed grain wt)*(Extr, water wt./(1-Extr. NaCI/10^6))/(VVater dens,*DS water vol/(1- Salt Corr NaCl(Iter 2)/10^6)) Salt Corrected Weight Fraction Filtrate in Dean Stark Water 11 Formation Brine Iodide(ppm) = Forml = 0 12 Wt. Fract. Filtrate=(Salt Corr. DS I-Forml)/(Mud Filtr. Iodide for Cored Int.-Forml) · , Formation Bdne Salinity 13 Formation Brine Chlodde(ppm) -- (Salt Corr Cl(Iter 2)-Wt. Fract. Filtr.*Mud Filtr. CI for Core No.)/(1 -Wt. Fract. Filtr) 14 Formation Bdne Salinity(ppm) = Formation Brine Chloride*58.5/35.5 · . EQUATIONS USED FOR CALCULATION OF POROSITY, GRAIN DENSITY, SATURATIONS AND CHLORIDE CONCENTRATION Salt Corrected Dean Stark Water Saturation 15 Brine Dens(g/cc) = -5'10^-13'(NaCl)^2 + 8'10^-07'(NACI) + 0.9970 @ 75°F 16 Salt Corr. DS Water Vol. = DS water vol.*Water Dens./((1-DS NaCI/10^6)DS Brine Density) 17 Salt Corr Pore Volume = Measured pore vol.*(DS grain wt/Dry grain wt.) + DS water vol*Water dens.*(DS NaCI/10A6)/(NaCI Dens.*(1 -DS NaCI/10^6)) 18 Salt Corr DS Sw = 100' Salt Corr. DS water/Salt Corr Pore Volume Salt Corr. Connate Water Saturation (Dean Stark Sw Corrected for Filtrate Invasion) 19 Scw = (1-Wt Fract. Filtr.)*Salt Corr. DS Sw*DS Brine Dens./Form. Brine Dens. Filtrate Saturation 20 Filtrate Saturation = Salt Corr. DS Sw - Scw Salt Corrected Porosity 21 Salt Corr. Porosity = 100*Salt Corr. Pore Volume/(Measured Grain Vol. + Meas. Pore Vol) Salt Corrected Grain Density 22 Salt Corrected Grain Volume = Measured Grain Vol. - DS water vol*Water dens.*(DS NaCl/t 0^6)/(NaCI Dens.*(1 -DS NaCI/10^6)) 23 Salt Corrected Grain Weight = Measured Dry Wt. - DS water vol*Water dens.*(DS NaCI/10^6)/(1-DS NaCI/10^6) 24 Salt Corrected Grain Density = Salt Corrected Grain Weight/Salt Corrected Grain Volume LISTING OF ADDITIONAL SAMPLES REQUESTED Core Laboratories ARCO ALASKA, INC. NEVE NO. 1 WELL Box1 Box 2 Box 3 Box 4 i Sample Number Depth, CoreSealed . feet Plug Weight ~ ....................................................................................................... 4' .............................................. ~ 2S-2 ~ 76.4 [ 190.53 i 2S-3 i 76.6 i 184.39 i~ ................ ""'""'i~ 2S ................... ' i ...................................................... 76.8 ~* ............................................... 187.43 j [ 2S-6 i 80.46 i 183.48 i 2S-8 ~ 80.76 ~ 184.17 i .............................. 2S-1 ~' .................................... i 82.]J ................................................................................. 8 '! 175.26 ~ ...................... . ......................... . ...... .. ......... ,..., .......... · ................................................................... i 26-12 i 82.68 i 174.11 i 2S-13 i 82.80 i 177.62 I, .................................................................................................. · ...... 4, ........ * ................... · .................. i 2S-14 i 82.95 ! 179.38 .., ................................................. ; ...................................................... .~ ............................................... ; ,. 2S-17 i 86.58 -note dog leg 4' 175.88 i 26-22 i 89.65 i 183.72 · ................................................. ~ ...................................................... .e. ............................................... : 26-23 ~ 89.80 ~ 181.04 i 2S-24 i 7292.30 i 182.15 i 26-25 i 92.45 i 175.52 · ' 2S-29 ~ 7294.30 ~ 178.59 i 2S-30 i 94.45 i 172.21 i 2S-31 i 94.60 (94.56) i 172.91 .., ................................................. ? ...................................................... . ............................................... 2S-32 : 94.75 .. 173.13 [ ................................................. ~ .............. , ....... . .............. . ....... ,..~.~**.~...... ................. . .................. j 2S-33 j 94.88 i 172.87 · ................................................ · ...................... . ................ o .............. . ........................... , .................. i 26-36 !7298.60 j 175.56 ] 2S-37 i 98.75 i 176.91 I' ................................................. ,~ ...................... · .......... ~ ....... ,~..4' ............. ,** .......... · .................. i 2S-38 i 98.92 i 186.37 i 2S-39 i 7300.30 i 85.10 ~ 2S-40 ! 00.45 i 185.33 2S-42 ~ 00.75 ~ 184.10 I, ................................................. 4 .............................................................................................. · ...... 26-46 [ 03.80 i 180.95 ................. .................. ! ........... .............................. i ........... .................... Arco Alask~ · Neve No. 1 Well Sample Number Depth, CoreSealed feet Plug Weight .................................... ; ................................................. ; ...................................................... ~. ............................................... Box 5 ~ 2S-49 ~ 7306.45 ~ 180.96 :.. ................. '~'§:~'~ .................. ' ................................................ 06.60 *~ ............................................... 186.07 [ ................. .................. i ........... .............................. i ........... .................... 2S-52 ~ 06.90 ~ 180.14 ~. ........ . ............... . ........................ , ............. . ....................................... ~ ............................................... ~ 2S-53 ~ 7308.30 ~ 182.56 ! 2S-54 .' 08.45 ~ 181.77 ,. ................................................ ,e ...... · ...... · ...................................... ,,1, ............................................... i 2S-55 [ 08.60 i 176.23 ~ 2S-57 ~ 08.90 Frac. ; 184.70 i .................'ff§:~'~' ................. ~ ..... 'ffff~'"i'[§'~ .............................. ~ ........... ;i':~ifi~;i ..................... [ 2S-59 ! 11.45 ~ 176.26 = 2S-60 11.60 , 178.50 Box 6 ~ 28-61 ~ 11.75 ~ 183.96 ~ S2-62 ~ 11.90 ! 177.90 ~ S2-63 = 7312.30 ~ 171.64 i 82-64 i 12.45 [ 189.18 ~ S2-65 ~ ........... ..1..2..:..5...5. ............................... ~ ............ .1..,..8~,.....4...0.. .................... , ~ S2-66 ~ 12.75 : 182.44 82-67 12.90 ; 185.60 : S2-68 : 7315.35 : 179.79 ~ 82-69 ~ 15.48 ~ 175.86 ~ 82-70 ~ 15.65 ~ 180.35 ; 82-71 ~ 15.75 ~ 191.05 i. ................................................. · ...................................................... ~, ...... . ....... . ................................ . . . ; 82-72 .. 15.90 ; 183.09 ; ; ; Box 7 ~ S2-73 ~ 7318.30 ~ 181.36 ~ S2-74 ~ 18.45 ~ 186.07 ~ ................................................. .; ...................................................... 4. ............................................... ~ 82-75 ! 18.60 ~ 180.38 ~ S2-76 ~ 18.75 ~ 183.32 ,~ ................................................. ~, ...................................................... ~ ..................... : ......................... ~ S2-77 ~ 18.88 ~ 179.82 ~ S2-78 ~ 7320.45 ~ 181.41 , S2-79 i ........... ~;~Ji~'~J .............................................................................. ~ 186.01 ? ................................................. ~ ..................................................... ? ............................................... = S2-80 ~ 20.75 ~ 192.05 .' · ..... ~ ........................................... .~ ......... . ...... ...~.. ......... .. ...... .... ..... ... ...... o ...... ..... ....... . ....... . ....... . ....... i 82-81 ! 20.90 i 183.48 ~ S2-82 ~ 7324.30 ~ 218.90 ~ ................................................ ~. .................................................... ? ............................................... ~ S2-83 ~ 24.45 ~ 220.53 S2-84 ~ 24.58 ~ 222.25 Arco Alaska, ~nc. Neve No. I Well Box 8 Box 9 ................... S~-86 ......................... '~ ................................................ 24.90 '~i ........................................... 218.18 ................................................. 'I. ................................................... ~. .............................................. S2-88 ~ 26.45 ! 193.05 ................................................. ~, ..................................................... ~ ............................................... S2-89 i 26.58 i 188.76 S2-90 i 26.75 ! 193.44 S2-91 { 26.90 ~ 183.82 ........................................ ,.~ .......................................... ~ ............................................... S2-92 i 7330.30 i 207.49 ............................................... ~. ............................................. & ............................................... 62-93 ! 30.45 [ 217.41 ................................................. S2-95 :i ................................................... 30.75 ?i ............................................. 218.41 ~ S2-96 j 30.90 i 212.27 $2-97 i 7332.30 i 204.24 ..................... S~.'-98 ......................... ~i ............................................ 32.45 *[ ............................................... 202.53 ' ..................... S~;-99 ....................... "*i .................................... 32.58 ' .... "'""'-"~ .............. 213.56' ....... ' ........................ ~ S2-100 i 32.75 [ 210.93 62-101 i 32.90 ! 204.12 CORE LABORATORIES CORE ANALYSIS REPORT ARCO ALASKA, INC. " . NEVE NO. 1 WELL COLVILLE DELTA EXPLORATION FINAL REPORT Performed for: ARCO ALASKA, INC. 700 G Street Rm: ATO1450 Anchorage, Alaska 99501 July 1, 1996 Performed by: CORE LABORATORIES ADVANCED TECHNOLOGY CENTER 1875 Monetary Lane Carrollton, Texas 75006 : File: DAL-96063 PETROLEUM SERVICES July 1, 1996 ARCO ALASKA, INC. 700 G Street Rm: ATO1450 Anchorage,Alaska 99501 Attention: Ms. Rene Hannon Reference: Neve No.1 Well Colville Delta Exploration Core Analysis Study File: DAL-96063 Ms. Hannon: Core Laboratories' Advanced Technology Center in Carrollton (Dallas), Texas is pleased to present the final report for a core analysis study performed on 66.0 feet of core matedal recovered from the referenced well. Preliminary information was provided to the client as it became available. A project summary, description of laboratory procedures, and presentation of results are provided within. Ten copies of this final report have been issued. Large format, table shot white light and ultraviolet photographs of all slabbed whole core material were taken. Copies of all photographs and CD-ROM formats have been provided under separate cover previous to this final reporting. The slabs are currently in storage at Arco's core storage facility in Anchorage, Alaska. The remaining core matedal (3/4 butt ends) are in storage at our Carrollton, Texas facility. We appreciate this opportunity to have been of service to Arco Alaska, Inc. Please contact us at (214) 466-2673 if you should have any questions regarding this report, or if we may be of further assistance. Sincerely yours, Daniel J Scott Petrophysics Group Core Laboratories. Inc. i875.. Monetary Lane. Carroilton. Texas ~- 7 ; b006- 012. (214'~ 466-2673. Telex 163166. CORDAL UT. Fax (214/323-393C ARCO ALASKA, INC. File: DAL-96065 PROJECT PARTICIPANTS Field Core Retrieval and Shipping Basic Properties Core Photography David Sutton Basic Properties Chloride Sample Preparation Dean-Stark Fluid Saturations Dean-Stark and Chloride Calculations and Data Evaluation Ste~ Basic Properties, Data Evaluation and Report Preparation Daniel J. Scot{.I Final Review Melanie F. Dunn Core Laboratories ARCO ALASKA, INC. File: DAL-96063 TABLE OF CONTENTS SECTION 1: PROJECT SUMMARY SECTION 2: LABORATORY PROCEDURES SECTION 3: HORIZONTAL PLUG AND TRACER SAMPLE DATA 800 psi Net Overburden SECTION 4: VERTICAL PLUG DATA 800 psi Net Overburden SECTION 5: SPECTRAL CORE GAMMA AND CORRELATION COREGRAPH APPENDIX: TRACER ANALYSIS and CHLORIDE CONCENTRATION PROCEDURES Core Laboratories ARCO ALASKA, INC. File: DAL-96065 SECTION 1 PROJECT SUMMARY Core Laboratories ARCO ALASKA, INC. File: DAL-96063 PROJECT SUMMARY Core Retrieval and Shipping - Prudhoe Bay, Alaska (Colville Delta Exploration) A Core Laboratories' representative from Anchorage was at the wellsite for initial core handling and transportation. The first conventional core was recovered in the field on February 27, 1996. The core barrel liner containing the core was cautiously laid down on the catwalk and was stdped with red and black markers along its length to maintain uphole orientation. The liner was depth marked (top to bottom), then cut into three foot lengths with a chop saw. End caps were placed on each end of the tubes containing the core and placed into specially constructed wooden shipping crates. The well was ddlled to the second core point on February 29, 1996 and the above procedure was repeated. The client selected seven locations in Core 2 for tracer wafers to be cut out and preserved in Saran Wrap and ProtecCoreTM as outlined in the wellsite core handling procedures. The tubes containing core and the tracer samples were placed in the shipping crates and air-freighted to our Carrollton facility for core processing. Core Reception and Processing-Carrollton, Texas The core processing was performed according to a procedural protocol outlined by Arco Alaska, Inc. Two cores totaling 66.0 feet in length were uncrated and laid out, oriented, labeled, marked, and sectioned for routine and special core analysis plug sampling. The cores were then run through Core Laboratories' spectral gamma logger to measure, total gamma counts, and uranium, thodum, and potassium isotopes. Routine horizontal and vertical core plugs were ddlled with Isopar-M. The horizontal plugs were immediately loaded into Dean-Stark glassware for saturation measurements. SCAL plugs were ddlled using humidified nitrogen as the plugging coolant and then were Saran Wrapped, aluminum foiled, CoreSealed, and preserved in aluminum laminate ProtecCoreTM. Routine plug end pieces (tdm ends), special core analysis plug end pieces (tdm ends), and wafers were preserved in ProtecCoreTM. Concurrently, a 1/4 slab was taken during the core processing. Core chips from each foot were taken for shipment to the State of Alaska. All remaining core material was preserved in Saran Wrap, aluminum foil and CoreSeal. In addition, four mud samples were taken at the wellsite dudng codng and sent to the Carrrollton laboratory for filtration and analyzed for tracer concentration. All core matedai (butt ends and slabs), plug samples, and end pieces/wafers were boxed and prepared for distribution. Special additional plugging required three core pieces from Core No.1 to be depreserved (one foot at a time) and 1-1/2 inch horizontal and vertical plugs were taken from the selected pieces. These plugs were Saran Wrapped, aluminum foiled, and placed into an individual ProtecCoreTM pouch. These plugs were delivered to Arco Oil and Gas in Piano, Texas. Laboratory Program Routine plug samples were analyzed in strict accordance with Arco Alaska's protocol described in the laboratory procedures. The horizontal plugs and tracer samples were subjected to Dean-Stark saturation determination, cleaning and drying, permeability, porosity and grain density measurements, and crushing and leaching for bromide and chloride concentrations. Vertical plug samples were batch cleaned and tested for permeability and porosity. The tracer samples followed Core Laboratories ARCO ALASKA, INC. File: DAL-96065 the same test protocol as the routine horizontal plugs. Laboratory procedures are described in Section 2 and test results are presented in Sections 3 through 5. A summary of sample selection is ~isted below: Horizontal Plugs inch dia. Routine Vertical Plugs 1 inch Special Core Analysis Plugs 1 1/2 inch dia. Tracer Sample Cut Out Cubes Additional 1-1/2 inch dia. Plugs Horizontal Additional 1-1/2 inch dia. Plugs Vertical 1 6 0 0 0 3 2 2 59 29 101 7 0 0 As noted, 101 SCAL plugs, end pieces, and wafers were taken at the Carrollton laboratory. Preliminary data results were provided to the client on a regular basis. A preliminary core analysis report provided on May 13, 1996 included all horizontal plug permeability and porosity, grain density, water and filtrate saturation data. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 2 LABORATORY PROCEDURES Core Laboratories ARCO ALASKA, INC. File: DAL-96065 LABORATORY PROCEDURES Laboratory analytical and quality control procedures used dudng the analysis of the core from the Neve No. 1 well followed the procedural guidelines set forth by Arco Alaska, Inc. and under the supervision of AEPT representatives. Any modifications or additions to the wdtten protocol were by request or by approval of Arco Alaska, Inc. Surface Core Gamma Logging Before the commencement of spectral gamma logging of each core run, the equipment was checked with a calibration cylinder. The check cylinder contains known concentrations of the following elements: K = 4.0%, Th = 24 ppm, U = 12 ppm, with a total gamma ray count of 200 APl units. If the equipment was observed to measure values outside the tolerance limits, then a recalibration routine was initiated using individual standard calibration tubes. The core spectral gamma logger utilizes a Na-I detector of similar configuration to downhole log detectors, and an anti-coincidence shield around the detector to greatly reduce background radiation and reduce Compton scattering to improve the signal to noise ratio. The core travels over the detector under the protection of lead shielding at a slow rate of two minutes per foot. A multi-channel analyzer is interfaced with a PC for digitized data acquisition. Core gamma data was processed and plotted in depth versus total and uranium-free gamma (APl units), potassiUm (%), and thorium and uranium (ppm), at a vertical scale of 5" = 100 feet and is presented in Section 5 of this report. Preliminary plots were sent to the client as soon as they became available. · Slabbing Following the core gamma logging process, a 1/4 slab was tdmmed in our Carrollton Laboratory using a slab saw cooled with liquid nitrogen mist. Slabbing was performed relative to the yellow and white orientation lines drawn on the up dip side of the core. The 1/4 section was then carefully cleaned, labeled and placed in core slab presentation boxes (about nine feet of core per box) with styrofoam liners. The 1/4 slab section was prepared for core photography. · Plugging Routine horizontal and vertical core plugs were drilled with Isopar-M. The horizontal plugs were immediately loaded into Dean-Stark glassware for saturation measurements. SCAL plugs were ddlled using humidified nitrogen as the plugging coolant and then were Saran Wrapped, aluminum foiled, CoreSealed, and preserved in aluminum laminate ProtecCoreTM. Routine plug end pieces (trim ends), special core analysis plug end pieces (trim ends), and wafers were preserved in ProtecCoreTM. Core chips from each foot were taken for shipment to the State of Alaska. All remaining core material was preserved in Saran Wrap, aluminum foil and CoreSeal. All core material (butt ends and slabs), plug samples, and end pieces/wafers were boxed and prepared for distribution. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 · Core Photography The 1/4 longitudinal cuts of core were used for white light and ultraviolet core photography after careful cleaning and preparation of the rock. Large format (approximately 18 feet per frame) shots were taken and photographs were provided in both white light and UV 8x10 inch pdnts. CD-ROM formats were also provided of the core photos. Following photography the 1/4 slabbed core was shipped to Arco Alaska's core storage facility in Anchorage on March 4, 1996. · Plug Samples The preserved special core analysis plug samples, end pieces and wafers were submitted to AEPT representatives along with core processing data sheets, and routine plug samples were retained for analysis by Core Laboratories. The horizontal plug and tracer samples were then forwarded to the extraction room for Dean-Stark analysis. The vertical plugs were batch cleaned using toluene followed by chloroform. · Dean-Stark Analysis Each Dean-Stark flask and associated glassware were cleaned and dded before use. The condenser, core chamber and flask were rinsed 5 times with 20cc of fresh reagent grade toluene before adding toluene to the apparatus for pre-boiling. The sidearm was checked for water and pure toluene was transferred from sidearm to flask, the sidearm was then dded. Each core plug sample was removed from its Saran Wrap seal, then weighed to 0.001 g, placed in a predded and prelabelled thimble and weighed again. Each plug and thimble was then loaded into the Dean-Stark apparatus. The system was sealed with Teflon tape to prevent leakage and capped with desiccant to prevent the introduction of condensed atmospheric water. Water volume in each Dean-Stark receiving tube was monitored dudng the toluene refluxing until stabilization. A wire was used to swab off any water droplets from the neck of the condenser. A record of time and water volumes was kept for each sample. Extraction time for each sample was approximately 48 hours. After extraction, the flask and contents were removed. The toluene in the side arm was removed and added to the flask. The water recovered in the side arm was poured into a storage bottle, sealed, and labeled for possible tracer analysis. · Sample Drying Each core plug and thimble was dded in a convection oven at 180°F for four hours, followed by 24 hours drying in a vacuum oven at 180°F. Sample weights were monitored approximately every 4 to 24 hours until weight stabilization (+/- .01 g) was achieved. After drying, each plug and thimble was allowed to cool in a desiccator and then weighed to 0.001 g. Each plug was removed from its thimble and carefully brushed to remove fines, labeled and reweighed. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 · Grain Volume Determination Grain volumes were measured using the Boyle's law AutoporosimeterTM which was calibrated and checked with a known volume steel disk and Berea Sandstone (2.65 g/cc) check plug before each run. Plug samples and tracer samples were kept in a desiccator until ready for grain volume measurement. After every five samples, the steel check disk was measured to ensure correct equipment operation. Equipment recalibration was performed a minimum of twice a day or as needed. Grain densities (gm/cc) were calculated using the dry sample weight (gm) and grain volume (cc). · Mercury Bulk Volume Determination Bulk volumes of the tracer samples were determined by mercury immersion. Pore volume and porosity of the tracer samples were calculated as follows: PV = BV- GV 2~ = PV/BV x 100 Where: PV = Pore volume, cc ~ = Porosity, percent BV = Mercury bulk volume, cc GV = Grain volume, cc · Plug Porosity and Permeability Measurements by CMS-300TM Horizontal plug samples were measured for permeability and porosity by the CMS-300TM at 800 psi net overburden. Before each group of samples was run, a standard system leak test was performed to ensure correct equipment operation. Calibrated, known volume check cylinders were run before and with each carousel suite of samples. The Klinkenberg (slip corrected) permeability for each plug sample was determined as a function of pressure decay (helium blow-down). A reference cell of known volume charged the sample with helium. A downstream valve vented the sample to atmosphere, and the change in pressure with time was monitored. The multiple flow regime data allowed the determination of Klinkenberg permeability of the sample, a calculated air permeability, along with parameters helium slip factor (b) and the inertial resistance factor (g) beta. Any plug with permeability to air of 3000 md or more was remeasured using the Autopermeameter (a steady-state device), which has greater accuracy in measuring higher permeability samples, and the Autopermeameter data was reported. Porosity for each plug sample was calculated using Boyle's law by the CMS-300TM with grain volume and pore volume by: Where: ~ = PV , 100 PV + GV ~D = Porosity, percent PV = Pore volume at net confining pressure, cc GV = Grain volume, cc Core Laboratories ARCO ALASKA, INC. File: DAL-96063 Data was downloaded to diskette, imported to the core analysis report software, and preliminary data printouts were provided to the client regularly. Samples unsuitable for CMS-300TM testing were subjected to ambient condition porosity and profile (probe) permeability testing and are noted in the tabular data. The horizontal plug data is presented with the fluid saturation data in tabular format in Section 3. · Vertical Plugs A vertical plug was taken every other foot on an odd depth mark just below the horizontal plug. The slabbed four inch routine core section adjacent to the horizontal plug sampling points were used to obtain vertical plug samples. Testing of vertical plug samples included permeability and porosity by CMS-300TM at 800 psi confining pressure and grain density measurements. The results are found in Section 4. Tracer Analysis Following permeability and porosity measurements, all horizontal samples, as well as the designated tracer sections, were crushed and leached as outlined in the Appendix. Bromide and chlodde analyses on the extracts were performed by subcontractor Peak Analytical, Inc. using ion chromatography. Bromide and Chlodde concentrations were provided by Peak Analytical, Inc. to Core Laboratories for filtrate saturation calculations. Ddlling mud filtrate concentrations were also measured by Peak Analytical, Inc. for core filtrate calculations. Filtrate saturation calculation equations used were provided by the client and are found in the Appendix of this report. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 3 HORIZONTAL PLUG AND TRACER SAMPLE DATA 800 psi NOB Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well Number 1 1 1 2 1 3 1 4 I 5 1 6 2 1 2 2 2 3 2 4 2 5 2 6 2 7 2 8 2 9 2 10 2 11 2 12 2 13 2 14 2 15 2 16 2 17 2 18 2 19 2 20 Depth, feet IDean Stark Water Saturation, percent Net Confining Pressure Dean Stark Oil Saturation % pv Permeability, mill ida rcys Porosity, Klinkenberg J to Air .. percent 7259.15 800 0.015 0.029 11.7 100.0 0.0 100.0 7260.05 800 0.086 0.116 11.1 '100.0 0.0 100.0 7261.05 800 0.016 0.034 11.1 100.0 0.0 100.0 7262.05 800 0.031 0.045 9.2 100.0 0.0 100.0 7263.05 800 1.56 1.60 9.4 100.0 0.0 100,.0 7263.95 800 0.691 0.734 9.0 100.0 0.0 100.0 7276.25 800 0.136 0.253 14.5 56.4 36.6 93.0 7277.05 800 0.108 0.204 16.7 43.1 38.4 81.5 7277.95 800 0.031 0.066 11.5 70.3 24.4 94.7 7279.30 800 0.790 1.13 17.8 36.9 39.9 76.8 7280.05 800 4.37 5.36 20.8 22.6 51.1 73.7 7281.05 800 1.77 2.31 17.4 29.2 19.2 48.4 7282.10 800 1.54 2.07 19.3 26.5 51.6 78.1 7283.05 800 1.43 1.93 18.7 27.6 54.0 81.6 7284.05 800 4.48 5.49 20.2 21.2 54.4 75.6 7285.05 800 6.20 7.45 19.9 24.0 56.1 80.1 7286.05 800 2.04 2.60 17.2 43.0 37.2 80.2 7287.05 800 2.87 3.60 18.3 29.4 48.1 77.5 7288.15 800 9.76 11.4 20.5 19.8 68.1 87.9 7289.05 800 5.04 6.15 20.6 24.2 47.4 71.6 7290.05 800 7.62 9.09 18.0 28.9 52.0 80.9 7291.05 800 10.6 12.4 21.0 18.2 64.7 82.9 7292.05 800 1.45 1.65 20.9 18.6 57.3 75.8 7293.05 800 3.99 4.95 18.7 25.5 55.1 80.6 7294.05 800 7.89 9.32 20.3 24.9 51.0 75.9 7295.05 800 1.81 2.37 18.6 30.1 77.0 107.1 Colville Delta Exploration File: DAL~96063 Dean Stark Total Saturation, % pv .... Dean Stark Chloride Conc., __ ppm__ 11689. 5547. 8312. 4572. 4508. 4251. 22539. Dean StarkI Bromide] Grain Conc., I Density~ .... ~ ~ g/cc 124.76 2.70 84.50 2.69 114.58 2.69 96.17 2.68 96.64 2.66 84.71 2.69 161.64 2.66 2.67 2.67 2.66 2.66 2.66 2.66 2.65 2.66 2.65 2.68 2.66 2.65 2.66 2.66 2.65 2.65 2.66 2.66 2.66 sample broke 14460. 62.33 21365. 141.62 19498. 173.13 18951. 52.37 17587. 63.20 18307. 47.06 18866. 60.91 16883. 106.62 19874. 341.71 15632. 123.55 20517. 76.94 13149. 123.24 23275. 149.48 17049. 113.00 17233. 104.54 17035. 144.76 15715. 89.94 18392. 59.04 Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Dean Stark Dean Stark Dean Stark Dean Stark Dean Stark Net Permeability, Water Oil Total Chloride Bromide Grain Depth, Confining millidarcys Porosity, Saturation, Saturation, Saturation, Conc., Conc., Density, Core Number feet Pressure Klinkenberg.I to Air percent percent % pv % pv ppm _ ,opm g/cc 2 21 7296.05 800 5.77 6.94 19.8 27.4 52.8 80.2 19542. 346.26 2.66 2 22 7297.15 800 1.83 2.49 19.4 23.7 42.6 66.3 18160. 81.43 2.65 2 23 7298.05 800 3.76 4.66 18.9 27.1 51.6 78.7 15209. 88.53 2.66 2 24 7299.05 800 3.69 4.60 20.2 24.2 53.2 77.4 15512. 66.60 2.66 2 25 7300.05 800 0.057 0.110 12.9 55.1 32.5 87.6 17806. 0.00 2.67 2 26 7301.05 800 0.570 0.766 16.3 34.8 41.6 76.4 17634. 36.43 2.66 2 27 7302.05 800 2.13 2.77 20.2 23.9 19.6 43.4 17974. 55.40 2.66 2 28 7302.95 800 0.53 0.73 16.4 32.2 48.4 80.6 19855. 45.79 2.66 2 29 7304.05 800 1.66 2.19 19.2 27.9 49.3 77.2 13256. 79.21 2.66 2 30 7305.05 800 0.708 1.02 18.6 30.5 48.4 78.9 12152. 45.51 2.66 2 31 7306.05 800 2.73 3.49 21.0 28.5 46.4 75.0 15794. 70.85 2.65 2 32 7307.05 800 11.7 13.4 21.1 24.3 69.3 93.6 13626. 63.49 2.65 2 33 7308.05 800 1.50 2.06 18.9 30.2 44.2 74.4 17827. 58.84 2.66 2 34 7309.05 800 0.022 0.042 11.3 41.2 34.5 75.7 15315. 120.05 2.73 2 35 7310.05 800 0.0035 0. 0087 7.3 59.7 18.9 78.6 12073. 74.89 2.75 2 36 7311.05 800 2.96 3.81 19.9 28.3 51.1 79.4 25312. 123.99 2.65 2 37 7312.05 800 2.58 3.28 19.5 28.7 44.4 73.1 15493. 60.13 2.65 2 38 7313.05 800 1.87 2.46 18.1 30.3 51.0 81.3 17532. 98.93 2.65 2 39 7314.10 800 0.622 0.895 16.9 35.0 38.8 73.8 10987. 37.72 2.65 2 40 7315.05 800 0.696 0.994 16.6 36.2 41.6 77.8 16042. 73.95 2.65 2 41 7316.05 800 3.51 4.36 19.3 25.7 48.0 73.7 16466. 71.88 2.65 2 42 7317.05 800 4.42 5.42 19.9 25.0 56.7 81.7 16842. 78.77 2.65 2 43 7318.05 800 8.97 10.5 20.7 21.8 58.9 80.8 11066. 56.47 2.65 2 44 7319.05 800 1.83 2.39 18.9 26.3 54.4 80.7 17352. 69.86 2.66 2 45 7320.20 800 1.11 1.50 17.6 33.2 42.6 75.8 14394. 78.87 2.66 2 46 7321.05 800 6.82 8.13 20.9 20.6 60.1 80.7 17370. 72.43 2.65 Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well ICore. Number Depth, feet Net Confining Pressure Permeability, millidarcys Porosity, Klinkenberg i to Air percent 47 7322.05 800 48 7323.10 800 49 7324.05 800 50 7325.05 800 51 7326.10 800 52 7327.05 800 53 7328.05 800 54 7329.05 800 55 7330.05 800 56 7331.05 800 57 7332.05 800 58 7333.05 800 59 7334.05 800 Dean Stark Water Saturation, percent Average Values at 800 psi net confining stress: 1.42 1.89 18.9 27.8 1.88 2.47 19.1 28.0 2.30 2.94 19.5 27.2 1.63 2.17 19.1 25.6 1.51 2.02 18.4 28.1 5.84 7.03 20.9 22.0 1.18 1.59 18.0 28.4 1.48 1.97 17.7 28.4 1.60 2.12 19.1 27.7 2.24 2.86 19.1 27.8 2.43 3.09 19.2 29.6 2.08 2.68 19.7 29.9 1.07 1.42 17.1 36.2 2.69 3.32 17.7 36.8 Colville Delta Exploration File: DAL-96063 I Dean StarkI Dean Stark Oil I Total Saturation, I Saturation, .__ °/°Pr , I ..... %PY,, Dean Stark Chlodde Conc., ppm Dean Stark Bromide Conc., .... P~ Grain Density, 52.6 80.4 17791. 98.94 47.6 75.7 15974. 75.32 2.65 45.4 72.6 15085. 85.60 2.65 52.2 77.9 16528. 83.60 2.65 46.9 75.0 14226. 70.25 2.66 58.0 80.0 14729. 97.48 2.65 47.7 76.1 16726. 92.02 2.65 50.1 78.5 15092. 115.29 2.65 49.3 77.0 13652. 107.45 2.66 49.4 77.2 15092. 74.46 2.66 47.3 76.9 12644. 76.32 2.65 47.2 77.1 13911. 57.29 2.65 40.8 77.0 14506. 62.76 2.67 43.4 80.1 15652. 92.96 266 Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS Salt and Filtrate Corrected Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 .............. Wt. Loss Wt. Loss " Adjusted Adjusted Wt. Loss Filt. Corr. Salt Cor~ Salt Corr. Salt Corr. Salt Corr. Adjusted Salt Corr. Chlodd~ Dean Stark Dean Stark Dean Stark Salt Corr. Connate Conc. Net Permeability, Salt Corr. Water Oil Total Filtrate Water in Conna Depth, Confining ........ mi!lidarcys Porosity, Saturation, Saturation, Saturation,ISaturation Saturation,i Water, Core Number feet Pressure Klinkenberg I to Air percent % pv % pv % pv. % PV % pv i:).pm_ I 1 7529.15 800 0.015 0.029 11.8 100.0 0.0 100.0 3.7 100.0 10782. 1 2 7260.05 800 0.086 0.116 11.2 100.0 0.0 100.0 2.1 100.0 5019. 1 3 7261.05 800 0.016 0.034 11.2 100.0 0.0 100.0 3.3 100.0 7483. 1 4 7262.05 800 0.031 0.045 9.2 100.0 0.0 100.0 2.9 100.0 3903. 1 5 7263.05 800 1.56 1.60 9.4 100.0 0.0 100.0 3.0 100.0 3832. 1 6 7263.95 800 0.691 0.734 9.1 100.0 0.0 100.0 2.4 100.0 3712. 2 1 7276.25 800 o. 136 0.253 14.7 56.0 36.0 92.0 3.0 52.9 21352. 2 2 7277.05 800 o. 108 0.204 sample broke 2 3 7277.95 800 0.031 0.066 11.6 69.8 24.1 94.0 0.7 69.2 13986. 2 4 7279.30 800 0.790 1.13 17.9 36.8 39.4 76.2 1.7 35.1 20271. 2 5 7280.05 800 4.37 5.36 20.9 22.6 50.6 73.3 1.3 21.3 18275. 2 6 7281.05 800 1.77 2.31 17.4 29.1 19.0 48.2 0.1 29.0 18338. 2 7 7282.10 800 1.54 2.07 19.3 26.5 51.3 77.7 0.3 26.2 16986. 2 8 7283.05 800 1.43 1.93 18.8 26.8 53.6 80.3 0.1 26.7 17750. 2 9 7284.05 800 4.48 5.49 20.3 21.2 54.0 75.2 0.2 21.0 18215. 2 10 7285.05 800 6.20 7.45 20.0 24.0 55.6 79.6 0.7 23.3 16054. 2 11 7286.05 800 2.04 2.60 17.3 42.7 36.7 79.4 5.8 36.9 17764. 2 12 7287.05 800 2.87 3.60 18.4 29.3 47.6 76.9 1.1 28.2 14718. 2 13 7288.15 800 9.76 11.4 20.5 19.8 67.7 87.5 0.3 19.5 19710. 2 14 7289.05 800 5.04 6.15 20.7 24.0 47.0 71.0 0.9 23.2 12252. 2 15 7290.05 800 7.62 9.09 18.1 28.8 51.4 80.2 1.4 27.4 22109. 2 16 7291.05 800 10.6 12.4 21.0 18.2 64.1 82.3 0.6 17.6 16177. 2 17 7292.05 800 1.45 1.65 21.0 18.5 56.8 75.3 0.5 18.0 16407. 2 18 7293.05 800 3.99 4.95 18.8 25.5 54.6 80.0 1.2 24.3 15975. Core Laboratories SUMMARY OF CORE ANALYSIS '['EST RESULTS Salt and Filtrate Corrected Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAl_-96063 Net Permeability, Salt Corr. Depth, Confining millidarcys Porosity, Core Number feet Pressure ' 'Kl'i'nkenbe.r.g. i to Air.. percent 2 19 7294.05 800 7.89 9.32 20.3 2 20 7295.05 800 1.81 2.37 18.6 2 21 7296.05 800 5.77 6.94 19.9 2 22 7297.15 800 1.83 2.49 19.5 2 23 7298.05 800 3.76 4.66 18.9 2 24 7299.05 800 3.69 4.60 20.2 2 25 7300.05 800 0.057 0.110 13.0 2 26 7301.05 800 0.570 0.766 16.4 2 27 7302.05 800 2.13 2.77 20.3 2 28 7302.95 800 0.53 0.73 16.5 2 29 7304.05 800 1.66 2.19 19.3 2 30 7305.05 800 0.708 1.02 18.6 2 31 7306.05 800 2.73 3.49 21.1 2 32 7307.05 800 11.7 13.4 21.2 2 33 7308.05 800 1.50 2.06 18.9 2 34 7309.05 800 0.022 0.042 11.3 2 35 7310.05 800 0.0035 0.0087 7.4 2 36 7311.05 800 2.96 3.81 20.0 2 37 7312.05 800 2.58 3.28 19.6 2 38 7313.05 800 1.87 2.46 18.1 2 39 7314.10 800 0.622 0.895 16.9 2 40 7315.05 800 0.696 0.994 16.6 2 41 7316.05 800 3.51 4.36 19.4 2 42 7317.05 800 4.42 5.42 19.9 Wt. Loss Adjusted Salt Corr. Dean Stark Water Saturation, % pv Wt. Loss Adjusted Salt Corr. Dean Stark Oil Saturation % pv 24.8 30.0 27.3 23.6 26.9 24.1 54.8 34.6 23.2 32.1 27,8 30.4 28.4 24.1 30.1 41.1 59.5 28.1 28.5 30.1 34.7 35.9 25.5 24.7 50.6 76.3 52.1 42.2 51.1 52.6 32.1 41.1 18.9 47.9 48.8 48.0 45.9 68.4 43.7 34.2 18.7 50.2 43.8 50.3 38.4 41.0 47.4 55.7 Salt Corr. Dean Stark Total Saturation % pv 75.4 106.3 79.4 65.8 77.9 76.7 86.9 75.7 42.1 80.0 76.7 78.5 74.4 92.5 73.8 75.3 78.2 78.4 72.2 80.4 73.1 76.9 72.9 80.5 Wl. Loss Adjusted Salt Corr. Filtrate Saturation % pv Filt. Corr. Salt Corr. Connate Water Saturation O/o pv,,,, Salt Corr. Chloride Conc. in Connate Water, , .~E.m_ ....... 0.5 24.3 15018. 0.2 29.8 17771. 3.7 23.5 17372. 0.4 23.2 17433. 0.6 26.3 14534. 0.3 23.8 14970. 0.0 54.8 17309. 0.0 34.6 17145. 0.1 23.1 17391. 0.1 32.0 19216. 0.5 27.4 12694 0.1 30.4 11881 0.4 28.0 15216 0.2 23.8 13171 0.2 29.8 17234 1.5 39.6 14427 0.9 58.6 11571 1.0 27.1 24148. 0.2 28.2 14992. 0.8 29.3 16733. 0.0 34.7 10795. 0.5 35.4 15437. 0.4 25.2 15857. 0.4 24.3 16179. Core Laboratories SUMMARY OF CORE ANALYSIS TEST RESULTS Salt and Filtrale Correcled Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Wt. Loss Wt. Loss ...... Adjusted Adjusted Wt. Loss Filt. Corr. Salt Corr. Salt Corr. Salt Corr. Salt Corr. Adjusted Salt Corr. Chloride Dean Stark' Dean Stark Dean Starki Salt Corr. Connate Conc. Net Permeability, Salt Corr. Water Oil Total Filtrate Water in Connate Depth, Confining millidarcys Porosity, saturation, saturation, saturation, saturation saturation, water, core Number ..feet Pressure Klinkenberg I to Air percent % pv % pv ..% @v % pv % pv ppm ._ 2 43 7318.05 800 8.97 10.5 20.7 21.7 58.2 79.9 0.2 21.5 10740. 2 44 7319.05 800 1.83 2.39 18.9 26.0 53.5 79.4 0.3 25.6 16718. 2 45 7320.20 800 1.11 1.50 17.7 33.1 42.1 75.1 0.6 32.5 13807. 2 46 7321.05 800 6.82 8.13 21.0 20.4 59.2 79.6 0.3 20.1 16722. 2 47 7322.05 800 1.42 1.89 18.9 27.5 51.8 79.3 0.7 26.8 16983. 2 48 7323.10 800 1.88 2.47 19.2 27.8 46.9 74.7 0.4 27.3 15362. 2 49 7324.05 800 2.30 2.94 19.5 27.2 45.1 72.3 0.5 26.7 14433. 2 50 7325.05 800 1.63 2.17 19.2 25.5 51.7 77.2 0.5 25.0 15846. 2 51 7326.10 800 1.51 2.02 18.5 27.9 46.4 74.4 0.4 27.6 13704. 2 52 7327.05 800 5.84 7.03 21.0 21.9 57.4 79.3 0.6 21.3 14004. 2 53 7328.05 800 1.18 1.59 18.1 28.0 46.8 74.8 0.6 27.4 15988. 2 54 7329.05 800 1.48 1.97 17.8 28.2 49.4 77.7 0.9 27.3 14239. 2 55 7330.05 800 1.60 2.12 19.2 27.4 48.6 76.0 0.8 26.6 12872. 2 56 7331.05 800 2.24 2.86 19.2 27.4 48.4 75.9 0.4 27.0 14515. 2 57 7332.05 800 2.43 3.09 19.3 29.2 46.6 75.8 0.5 28.8 121 '19. 2 58 7333.05 800 2.08 2.68 19.8 29.4 46.1 75.5 0.2 29.1 13490. 2 59 7334.05 800 1.07 1.42 17.2 35.8 40.1 75.9 0.4 35.4 14027 Average Values at 800 psi net confining stress: 2.69 3.32 17.7 36.5 42.9 79.4 0.9 35.8 14924. Core Laboratories Permeability '/s. Porosity (.3 ~U Poros&ty H~stogram SUMMARY OF TRACER ANALYSIS TEST RESULTS ARCO Alaska, Inc. Neve No.1 Well Depth, Core Number feet Porosity, . percent 2-4 1T4 7279.0 13.5 2-4 3T4 7279.0 14.2 2-4 5T4 7279.0 13.9 2-13 1T13 7288.0 20.9 2-13 3T13 7288.0 20.4 2-13 5T13 7288.0 20.8 2-22 1T22 7297.0 20.1 2-22 3T22 7297.0 20.6 2-22 5T22 7297.0 19.7 2-30 1T30 7305.5 19.9 2-30 3T30 7305.5 20.0 2-30 5T30 7305.5 20.0 2-39 1T39 7314.0 20.3 2-39 3T39 7314.0 19.9 2-39 5T39 7314.0 19.8 2-48 1T48 7323.0 18.7 2-48 3T48 7323.0 19.3 2-48 5T48 7323.0 18.9 2-54 1T54 7329.0 18.9 2-54 3T54 7329.0 19.5 2-54 5T54 7329.0 18.9 Colville Delta Exploration File: DAL-96063 IDean Stark Water Saturation, .. percent 48.2 44.9 48.7 21.9 25.0 37.2 25.8 28.1 40.7 35.1 37.1 4O.7 24.8 25.0 35.0 25.5 27.2 41.9 25.2 25.5 40.0 Dean StarkI Dean Stark! Dean Stark Oil I Total I Chloride Saturation,I Saturation,I Conc., , % pv I , % pv ! ppm Dean Stark Bromide Conc., , ppm Grain Density, g/cc 22.3 70.5 15175. 89.12 2.66 24.7 69.6 16118. 101.02 2.67 18.9 67.6 26635. 961.78 2.67 36.6 58.5 17417. 112.55 2.68 33.6 58.7 18218. 269.92 2.66 23.5 60.7 28161. 1428.43 2.68 37.1 62.9 15356. 126.16 2.67 25.7 53.8 16521. 141.03 2.67 25.2 65.9 27699. 1355.41 2.65 25.6 60.8 21197. 611.42 2.66 27.4 64.6 23785. 727.13 2.66 22.6 63.3 28570. 1515.15 2.68 40.4 65.2 16258. 124.38 2.66 38.4 63.4 15639. 179.35 2.65 25.5 60.5 25979. 1222.35 2.65 34.3 59.9 16415. 97.62 2.65 34.6 61.8 15411. 177.20 2.68 36.5 78.4 37285. 819.22 2.66 37.8 63.0 14006. 105.63 2.65 36.5 62.1 21380. 111.08 2.66 21.3 61.2 25081. 1103.21 2.65 Average Values: 19.0 33.5 29.9 63.4 21062. 541.86 2.66 Core Laboratories SUMMARY OF TRACER ANALYSIS TEST RESULTS Salt and Filtrate Corrected Values ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File: DAL-96063 Core Number Depth, feet Salt Corr. Porosity, percent Wt. Loss Adjusted Salt Corr. Dean Stark Water Saturation, % pv Wt: Loss Adjusted Salt Corr. Dean Stark Oil Saturation % pv Salt Corr. Dean Stark Total Saturation % pv Wt. Loss Adjusted Salt Corr. Filtrate Saturation % pv Filt. Corr. Salt Corr. Connate Water Saturation, % pv Salt corr. Chloride Conc. in Connate Water, ....... ppm 2-4 1T4 7279.0 2-4 3T4 7279.0 2-4 5T4 7279.0 2-13 1T13 7288.0 2-13 3T13 7288.0 2-13 5T13 7288.0 2-22 1T22 7297.0 2-22 3T22 7297.0 2-22 5T22 7297.0 2-30 1T30 7305.5 2-30 3T30 7305.5 2-30 5T30 7305.5 2-39 1T39 7314.0 2-39 3T39 7314.0 2-39 5T39 7314.0 2-48 1T48 7323.0 2-48 3T48 7323.0 2-48 5T48 7323.0 2-54 1 '1'54 7329.0 2-54 3T54 7329.0 2-54 5T54 7329.0 13.6 14.3 14.0 21.0 20.5 21.0 2O.2 2O.6 19.9 20.0 20.1 20.2 20.4 20.0 20.3 19.1 19.3 19.2 19.0 19.6 19.1 48.2 44.9 48.6 21.8 25.0 37.0 25.6 28.0 40.8 35.1 37.1 40.4 24.8 25.1 34.8 25.5 27.2 42.1 25.2 25.5 39.6 22.1 24.6 18.7 36.3 33.3 23.1 36.6 25.4 25.0 25.4 27.1 22.2 40.2 38.2 25.1 34.1 34.3 36.1 37.6 36.2 20.8 70.4 69.5 67.3 58.1 58.3 60.1 62.2 53.4 65.8 60.5 64.2 62.7 65.1 63.3 59.9 59.6 61.5 78.2 62.8 61.7 60.4 1.0 1.2 20.1 0.7 2.6 23.0 1.0 1.3 24.1 9.0 11.4 26.7 0.9 1.6 18.5 0.6 1.7 14.6 0.7 0.8 18.9 47.2 43.7 28.5 21.1 22.4 14.0 24.6 26.7 16.7 26.1 25.6 13.7 23.9 23.5 16.3 24.8 25.5 27.5 24.5 24.7 20.7 14499. 15343. 23316. 16542. 16415. 24076. 14426. 15488. 23405. 17636. 20314. 24658. 15331. 14343. 20674. 15651. 14126. 38608. 13235. 20402. 19899. Average Values: 19.1 33.4 29.7 63.1 8.6 24.8 18971. Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 4 VERTICAL PLUG DATA 800 psi NOB Core Laboratories CORE ANALY(. RESULTS(CMS-300 Hydrostatic nfinement) ARCO Alaska, Inc. Neve No.1 Well Colville Delta Exploration File:DAL-96063 1-Jul-96 Net Overburden Pressure: 800 psi ~ Plug Permeability Grain Core Plug Depth, Klinkenberg, I to Air, Porosity, Density, Number Number feet millidarcys! millidarcys percent gm/cc Core Analysis Data for the Vertical Plugs 2 2v 7277.25 0.05 0.10 17.2 2.66 2 4v 7279.25 0.65 0.96 18.6 2.65 2 6v 7281.25 1.01 1.44 18.7 2.65 2 8v 7283.25 0.88 1.26 19.4 2.65 2 10v 7285.25 1.40 1.89 19.0 2.66 2 12v 7287.25 0.77 1.09 17.7 2.66 2 14v 7289.25 4.33 5.53 20.8 2.65 2 16v 7291.25 9.12 10.8 21.9 2.64 2 18v 7293.25 1.27 1.72 18.3 2.68 2 20v 7295.25 0.97 1.36 17.7 2.66 2 22v 7297.30 3.64 4.59 20.3 2.67 2 24v 7299.25 0.99 1.39 19.0 2.66 2 26v 7301.25 0.20 0.33 17.2 2.65 2 28v 7303.15 0.16 0.30 17.3 2.67 2 30v 7305.25 0.32 0.51 19.0 2.66 2 32v 7307.25 0.31 0.50 17.5 2.67 2 34v 7309.25 0.12 0.17 11.3 2.74 2 36v 7311.25 1.30 1.78 19.5 2.65 2 38v 7313.25 0.84 1.19 18.6 2.68 2 40v 7315.25 0.55 0.84 18.5 2.65 2 42v 7317.25 1.85 2.44 19.4 2.65 2 44v 7319.25 1.18 1.65 19.7 2.65 2 46v 7321.25 0.95 1.35 18.6 2.65 2 48v 7323.33 0.75 1.07 18.5 2.66 2 50v 7325.25 0.36 0.56 17.6 2.65 2 52v 7327.25 1.17 1.60 19.4 2.66 2 54v 7329.25 1.25 1.72 19.2 2.66 2 56v 7331.25 0.92 1.29 18.8 2.65 2 58v 7333.25 0.61 0.90 18.9 2.65 Core Laboratories ARCO ALASKA, INC. File: DAL-96063 SECTION 5 SPECTRAL GAMMA LOG AND CORRELATION COREGRAPH Core Laboratories Correlation Coregr ~.0o in ~ !oO.t ft ARCO ALASKA, INC. File: DAL-96063 APPENDIX Core Laboratories TRACER ANALYSIS and CHLORIDE CONCENTRATION PROCEDURES Core Laboratories Appendix 1 TRACER ANALYSIS 1. Use the routine horizontal core plug for bromide ion analysis, redry if necessary. 2. Allow the sample to cool and record dry weight. 3. Crusl~ sample in mortar and pestle. Transfer crushed material to tared flask and weight. Rinse mortar and pestle with distilled water into flask and weigh again. Use 3 cm3 distilled water per gram of rock. . 5. 6. 7. 8. . Extract with continuous shaking overnight in a wrist shaker. Analyze blank samples of distilled water for bromide and chloride using ion chromatograph. Filter supematant liquid (at least 10cc) through .45 micron cellulose nitrate cartridge filter. Analyze extract samples for bromide and chloride using ion chromatograph. Provide the following data: a. Initial weight b. Dean-Starkwater volume c. Archimedes weight in toluene and weight in air d. Toluene temperature e. Bulk volume f. Dry weight g. Grain volume h. Crushed rockweight I. Flasktare weight j. Rock transfer weight k. Liquid transfer weight !. Water saturation, oil saturation, porosity, and grain density m. Bromide and chloride concentration measured by ion chromatograph Calculations were made from the observed and data using formulas specified by Dr. Jake Rathmell of Arco (see following page). EQUATIONS USED FOR CALCULATION OF POROSITY, GRAIN DENSITY, SATURATIONS AND CHLORIDE CONCENTRATION Dean Stark Salinity 1 DS Chlodde(ppm) =Meas. Extr CI*(DS grain wt/Crushed grain wt)*Extr, water wt/(DS water vol.*Water dens) 2 DS NaCl(ppm) = DS Chloride*58,5/35.5 Iter 0 Salt Corrected Salinity 3 Salt Corr Cl(ppm) = Meas. Extr CI*(DS grain wt/Crushed grain wt)*(Extr, Water wt./(1- Extr. NaCI/10^6))/(Water dens.*DS water vol/(1-DS NaCI/10^6)) 4 Salt Corr NaCl(ppm) = Salt Corr C1'58.5/35.5 Inter 1 Salt Corr Salinity 5 Salt Corr Cl(ppm)(Iter 1)= Meas. Extr CI'(DS grain wt/Crushed grain wt)*(Extr. Water wt./(1-Extr. NaCI/10^6))/(Water dens.*DS water vol/(1- Sit Corr NaCl(Iter 0)/10^6)) 6 Salt Corr NaCl(ppm)(Iter 1) = Salt Corr C1'58.5/35,5 Inter 2 Salt Corr Salinity 7 Salt Corr Cl(ppm)(Iter 2)= Meas. Extr CI*(DS grain wt/Crushed grain wt)*(Extr, Water wt./(1-Extr. NaCI/10^6))/(Water dens.*DS water vol/(1- Salt Corr NaCl(Iter 1 )/10^6)) 8 Salt Corr NaCl(ppm)(Iter 2) = Salt Corr C1'58.5/35.5 Salt Corrected Iodide in Dean Stark Water 9 DS Iodide(ppm) =Meas. Extr, Iodide*(DS grain wt/Crushed grain wt)*Extr, water wt/(DS water vol.*Water dens) 10 Salt Corr DS I(ppm)= Meas. Extr Iodide*(DS grain wt/Crushed grain wt)'(Extr, water wt./(1 -Extr. NaCI/10^6))/(VVater dens.*DS water vol/(1- Salt Corr NaCl(Iter 2)/10^6)) Salt Corrected Weight Fraction Filtrate in Dean Stark Water 11 Formation Brine Iodide(ppm) = Forml = 0 12 Wt. Fract. Filtrate=(Salt Corr. DS I-Forml)/(Mud Filtr, Iodide for Cored Int,-Forml) Formation Brine Salinity 13 Formation Brine Chloride(ppm) = (Salt Corr Cl(Iter 2)-Wt. Fract, Filtr.*Mud Filtr. CI for Core No.)/(1-Wt. Fract. Filtr) 14 Formation Bdne Salinity(ppm) = Formation Brine Chloride*58.5/35.5 . . EQUATIONS USED FOR CALCULATION OF POROSITY, GRAIN DENSITY, SATURATIONS AND CHLORIDE CONCENTRATION Salt Corrected Dean Stark Water Saturation 15 Brine Dens(g/cc) = -5'10^-13'(NACI)^2 + 8'10^-07'(NACI) + 0.9970 @ 75°F 16 Salt Corr. DS Water Vol. = DS water vol.*Water Dens,/((1-DS NaCI/10^6)DS Brine Density) 17 Salt Corr Pore Volume = Measured pore vol,*(DS grain wt/Dry grain wt.) + DS water vol*Water dens.*(DS NaCI/10^6)/(NaCI Dens.*(1-DS NaCI/10^6)) 18 Salt Corr DS Sw = 100' Salt Corr. DS water/Salt Corr Pore Volume Salt Corr. Connate Water Saturation (Dean Stark Sw Corrected for Filtrate Invasion) 19 Scw = (1-Wt Fract. Filtr.)*Salt Corr. DS Sw*DS Brine Dens,/Form Brine Dens. Filtrate Saturation 20 Filtrate Saturation = Salt Corr. DS Sw - Scw Salt Corrected Porosity 21 Salt Corr, Porosity = 100*Salt Corr. Pore Volume/(Measured Grain Vol. + Meas. Pore Vol) Salt Corrected Grain Density 22 Salt Corrected Grain Volume = Measured Grain Vol. - DS water vol*Water dens.*(DS NaCI/10A6)/(NaCI Dens.*(1-DS NaCI/10^6)) 23 Salt Corrected Grain Weight = Measured Dry Wt. - DS water vol*Water dens.*(DS NaCI/10^6)/(1-DS NaCI/10^6) 24 Salt Corrected Grain Density = Salt Corrected Graif~ Weight/Salt Corrected Grain Volume LISTING OF ADDITIONAL SAMPLES REQUESTED Core Laboratories Box1 Box 2 Box 3 Box 4 ,~.RCO ALASKA, INC. NEVE NO. 1 WELL I Sample Number I Depth,feet Plug CoreSealed ] Weight ................................................. 28-2 '~ ........... 'f6.4 ........................................ '~ ............................................. 190.53 ' 28-6 i 80.46 ~ 183.48 ............................................... 4 ................................................................................................ 28-10 i 82.35 i 179.39 ................. '~'§::i'i~ .................. ! ..... '~:f.§iE~i'~i .............................. t .......... q'§-E"i'i~' .................... ................................................. : ...................................................... .,, ............................................... 2S-17 i 86.58 -note dog leg i 175.88 28-18 i 86.78 ! 182.16 25-22 i 89.65 ~ 183.72 28-25 i 92.45 i 175.52 ................................................. 4 ...................................................................................................... 28-26 i 92.60 ~ 180.18 ................................................. 4 ...................................................... .4' ............................................... 25-30 ~ 94.45 ~ 172.21 28-31 i94.60 (94.56) ! 172.91 ................. '~.'§:~'~- .................. i ........... '{i;i:'f'~ .............................. '..'.' ........... "i':~'~,':i'~,' .................... ................. '~'§-'~,'~ .................. ! ........... ~:ii'~i ....................... -7.'. ........ "i'T';F§~' .................... 25-34 i7298.30 ~ 180.22 25-37 ~ 98.75 ~ 176.91 28-38 ~ 98.92 186.37 t ................. '~'§::;i',~ .................. '.: ........... ~§:'~'~ ............................. T ........ "i'i~':i~§' .................... 28-46 ; 03.80 180.95 25-47 ~ 03.95 i 182.90 ; ................................................. .. ...................................................... ,ff. ............................................. 28-48 i 7306.30 ~ 184.31 Arco Alaska, inc. Neve No. 1 Well Box 8 Box 9 Sample Number I Depth, feet ! CoreSealed Plug Weight .............................................. .I .......................................... 4, .......................................... S2-86 i 24.90 [ 218.18 ................................................ 4 .......................................... 4, ....... .-. ..................................... S2-90 ! 26.75 ! 193.44 ........................................... S2-94 -~ ~ .................................... 30.58 4, ~ .............. 214.6~"~' ................... S2-97 : : 7332.30 : 204.24 .................. §~::§'i~ ................ t 32.45 ?--'~'~':i~,' ................... I;~r A~GCC ~eg. 20 AAC 25.531 ARCO ALASKA INC. - NEVE NO. 1 Section 14, T11N-R4E UM Wildcat Colviile DelCo North Slope, Alaska MiCROFILMeD Date ~._.~.=~{~-=j~ JUN 0 ~J~,ska Oil & G~::¢ 00118. A-qch0rage EPoch Well Logging, Inc. I'A~I E OF CONTENTS 1. Well Resume 2. Daily Chronology 3. Daily Activity Summary 4. Mud Record 5. Bit Record 6. Morning Reports 7. Core Report / Show Report 8. Drilling Curve 9. Rig Acivity 10. Formation Log 1 1. Drilling Dynamics Log 12. MWD Combo Log WELL RESUME OPERATOR: WELL NAME: LO~ATION: FIELD: COORDINATES: ELEVATIONS: COUNTY: STATE: APl INDEX: SPUD DATE: TOTAL DEPTH: COMPLETION DATE (T.D.J: CONTRACTOR: RIG #: RIG TYPE: MUD PUMPS: COMPANY GEOLO~S: COMPANY ENGINEERS: TOOLPUSHERS: MUD COMPANY: MUD ENGINEERS: MUD TY'PES: HOLE SIZES: CASING DATA: MUDL~ING SERVICES: TYPE UNIT: UNIT #: L~ING GEOLOGISTS: SAMPLE TECHNICIANS: ELECTRIC LOGS BY: LO(; INTERVALS: LOG TYPES: DST INTERVALS: CORED INTERVALS: CORING COMPANY: WELL STATUS: ARCO ALASKA INC. NEVE NO. 1 SEC. 14, T11N R4E, UM COLVILLE DELTA 465' FNL, 2440' FWL R.K.B. = 29..7' G.L.: 12.0' MSL NORTH SLOPE BOROUGH ALASKA FEBRUARY 14, 1996 7700' MARCH 4, 1996 POOL ARCTIC ALASKA, INC. NO. 6 SCR DIESEL-ELECTRIC (2) NATIONAL A1700 (6"X 12") RENEE HANNAN DOUG STOLTZ / DAVE BAUMGARNER CHUCK SCHEVE / TOM COVINGTON BAROID DRILLING FLUIDS, INC. GARY MARTIN / SAM WILLIS SPUD TO 18,60', BLAND TO 7259', KCL TO 7700' TD 12 1/4'" TO 18~O', 8 lj2" TO 7700' 16"" AT 108', 9 5/8" AT 185'2' EPOCH WELL L~ING, INC. (FID) GAS DEI'ECTION. DML / RIGWATCH/RIGTRAK 12 CRAIG SILVA. GEOFF DAVISON ROBERT ANDERSON. JIM MCCUTCHEON SCHLUMBERGER CEI'-CBT-CN L-GR NONE 7259"-7267'; 7276'-7336" EASTMAN CHRISTENSEN NO DOPE. TIGHT HOLE DAILY CHRONOLOGY N tE NO. f 2-14-96: 2-15-96: 2-16-96 2-17-96: 2-18-96: 2-19-96: 2-20-96: 2-21-96: 2-22-96: 2-23-96: 2-24-96: Introduce spud mud. Test BOPE. Pick up NB No. 1, stabilizers, mudmotor and MWD. RIH 89' and circulate mud. Check valves and lines in the mud system with observation of some leaks in the mud system lines. POOH and repair leaks. RIH and break circulation. Test MWD tool. Circulate and ream through conductor fill. Drill ahead to 135'. Drill ahead from 135' to 995'. Drill from 995' to 1860'. Circulate bottoms up and POOH. RIH and encounter several tight spots while running in. Work pipe, ream and wash through tight spots. Run to bottom and circulate bottoms up. Pump high viscosity sweep and continue to circulate and clean hole. Circulate and clean hole. Pump high viscosity sweep and POOH. RIH and work pipe, ream and wash through tight spots on way in. Circulate and clean hole. POOH and lay down drill collars. Rig up and run 9 5/8" (53.5 Ib/ft) casing. Casing landed on bottom at 1660'. Rig up circulating head and pick up 12' and work casing back to bottom while circulating. Circulate bottoms up and prepare for cement job. Circulate bottoms up and continue to circulate to prepare for cement job. Pump cement and displace with mud. Bump plug and rig down circulating head. Cut casing to top of spool. Wait on cement and do rig maintenance work. Do a top job and nipple up BOPE. Condition surface mud. Nipple up and test BOPE. Pick up NB No. 2 and BHA. RIH and tag top of cement at 1695'. Drill cement and float collar. Pressure test casing. Complete pressure testing casing. Drill cement and drill out casing shoe. Drill 10' of new hole to 1870' and and run leak-off test. Drill from 1870' to 2857' and make a 10 stand wiper trip. Drill from 2857' to 3607'. Lay down 9 joints of drill pipe. Make a wiper trip 'to the shoe. Drill ahead from 3607' to 3800'. Drill from 3800' to 4642'. Circulate bottoms up and make a 10 stand wiper trip. Drill ahead from 4642' to 4754'. Drill from 4754' to 5394'. Circulate bottoms up and make a wiper trip to the shoe. Drill ahead from 5394' to 5584'. Drill from 5584' to 6141'. Circulate bottoms up and POOH. Change BHA and RIH with Bit ~2 and a new mudmotor. Drill from 6141' to 6164'. DAILY CHRONOLOG' NEVE NO. I 2-25-96: 2-26-96: 2-27-96: 2-28-96: 2-29-96: 3-01-96: Drill from 6164' to 7088'. Circulate bottoms up and POOH for new BHA. Lay dow mudmotor. RIH with Bit #2 and ream to 7088'. Ream to 7088'. Drill from 7088' to 7259'. Circulate bottoms up. Continue to circulate while pumping the current bland mud to tanker trucks and cleaning the pits prior to receiving a new KCL mud system for coring. Circulate while pumping the current bland mud to tanker trucks and cleaning the pits prior to receiving a new KCL mud system for coring. Fill the pits with new mud and displace the old mud still in the hole. Circulate and condition the new mud. Make a 10 stand wiper trip and circulate bottoms up. POOH and test BOPE. Change BHA and pick up new core bit, core barrel and mudmotor. RIH with coring assembly. RIH with coring assembly. Encounter tight spot 18 stands out. Work pipe and wash through tight spot. CVomplete RIH and drop ball, Pick up kelly and wash and circulate two joints to bottom. Core from 7259' to 7267'. Barrel jammed. POOH and lay down inner core barrel. Core No. 1 cut 8' and recovered 6.5'. Note that the rest of the core barrel was packed with fill. Stans back coring assembly and mudmotor. RIH with RRB #2 and drilling assembly. Ream last 100' to bottom. RIH with RRB #2 and drilling assembly. Ream last 100' to bottom. Drill from 7267' to 7271'. Circulate bottoms up and continue to circulate while waiting on a decision on whether to drill any farther before coring. Drill from 7271' to 7276' and circulate bottoms up. Continue to circulate and clean hole. Note abundant large shale cuttings returning over shakers. Pump high viscosity sweep to clean hole. Make a 25 stand wiper trip and circulate and condition hole. POOH and change BHA. Pick up rerun core bit and core barrel. RIH circulating every 20 stands. RIH to 60' above core point and circulate to bottom. RIH with Core Bit #3. RIH to 60' above core point and circulate to bottom. Drop ball and core from 7276' to 7336'. POOH and lay down core. RIH with coring assembly for another core. RIH to 60' above core point and circulate and ream to 7' above core point. Lose circulation at this point - lose about 50 barrels in 6 minutes. No returns to surface. POOH 3 stands and monitor while making up LCM pill. POOH another 7 stands and monitor mud loss while building mud in dewatering unit. Pump this mud to active system. Build and pump two LCM pills (160 barrels). After last pill, stop pumping and monitor well. Y CHRONOL OG NEVE NO. I 3-02-96: 3-03-96: 3-04-96: 3-05-96: 3-06-96: lOSS. 3-07o96: Monitor well 10 stands off bottom after losing circulation. POOH 8 more stands and slow circulate to observe mud volume losses. POOH 8 more stands and repeat the above procedure. POOH to shoe and break circulation. Continue to POOH and build new mud volume. Reduce mud weightto 10.5 ppg. Lat down coring tools and make up new BHA> RIH with NB ~4 (insert bit) and drilling assembly. Stop at 2978' and circulate out. Receive 356 units of gas from zone at 2350' to 2850'. Continue to RIH, stopping to break circulation every 10-15 stands. Continue to RIH stopping to break circulation every 10-15 stands. Circulate and wash to 7236 and ream to 7255' with mud loss, Circulate and stabilize mud loss. POOH to 6750'. Wash to 6790'. POOH to 6283 and lay down 5 stands. Start washing and reaming back to bottom. Note frequent packing off after 7120'. Pump repeated higgh viscosity sweeps to clean hole while reaming in. Ream to 7286' at report time. NOTE that the ratios of the heavy gases indicates that most of the gas is coming from uphole (probably from the C-30 at 2350'-2850'). Ream from 7286' to 7336'. Tag bottom and circulate bottoms up. Pump and circulate a high viscosity pill. Work on mud pump #2 and then drill from 7336' to 7560'. Drill from 7560' to 7631' and circulate bottoms up. Make a 5 stand wiper trip. Drill from 7631 to 7700' T.D.). Circulate bottoms up. Pump a high viscosity and circulate, make a 7 stans wiper trip and circulate bottoms up. Circulate a high viscosity pill and circulate up. POOH. POOH. Rig up Schlumberger and run in with wireline tools. Unable to get past 2380'. Pull tools out of hole and rig down Schlumberger. RIH with drilling assembly to clean hole. Break circulation at the shoe and work through tight spot at 2830'-2900'. Continue to RIH and work through tight spot at 4300'. Continue to RIH to 7670'. Break circulation and circulate out. Start losing mud above 80 spm pump rate. Increase pump rate to 120 spm and lose 60 barrels in 6 minutes. Lower pump rate to reduce mud Pump LCM pill and circulate around. Bring pump rate ap slowly while hole is stabilized. Net mus loss was 100 barrels. Circulate and condition. POOH and encounter tight spot at 2780'. POOH and rig up Schlumberger, Run in with wireline tools but unable to get past 2854'. Pull tools out of hole and rig down Schlumberger. Pick up RRB ~4 and drilling assembly and Anadrill LWD triple combo tool. RIH and break circulation at shoe. Work through tight spot at 2750'-2950'. Continue to RIH to 6950' and circulate bottoms up. Pump pill and circulate out. Ream to 6980' and very tight going to 7000'. Lay down one joint and ream and clean hole back to 7000'. Control ream on MAD run from 7000' to 7186'. DAILY CHRONOLOGY NEVE NO. I 3-08-96: 3-09-96: 3-10-96: 3-11-96: 3-12-96: Control ream on MAD run from 7186' to 7218'. Hole is very tight while reaming. Pull as much as 100 klbs over normal hookload several times while picking up. Pick up and circulate bottoms up. Pump dry job and POOH. Pull tight at 5910'. Remove radioactive source and lay down Anadrill LWD tool. Test BOPE. RIH with RRB #4 and rotary drilling assembly to clean up the hole. Break circulation at shoe and at 4000'. Continue to RIH to 7120' and pick up kelly and break circulation. Ream from 7120' to 7599'. Note raising mud weight to 11.0 ppg. Ream to 7700' and circulate bottoms up. Make a 10 stand wiper trip and pull tight during trip. Circulate bottoms up, pump pill and circulate around. Pump second pill and circulate around. POOH to shoe and run back in. Break circulation at the shoe and at 4400'. RIH with only minor resistance until 7350'. Pick up kelly and wash and ream to 7700'. Circulate bottoms up. Pump 100 barrel pill of special mud for casing run. Pump dry job and POOH. Rig up to run 7" casing. Run 7" casing and land shoe at 7678'. Rig up circulating head and break circulation. Start with 30 spm pump rate. Increase to 60 spm rate and start losing mud (apparently packing off uphole). Lower pump rate until no longer losing mud to the hole. Mud is no longer lost at rate of 12 spm (1 bbl/min.). Circulate at slow rate while waiting for the brine truck to arrive. Dispalce mud in suction lines with brine and blow clean rig lines with air. Pressure test lines. Pump brine spacer, ARCO preflush and cement. Displace with brine. Do cement job for 7" casing. Pump 20 barrel water spacer and 50 barrel ARCO preflush. Drop bottom plug and pump 85 barrel Class G cement slurry. Drop top plug and displace with 10.6 ppg brine. Bump plug and pressure up to 1500 psi. Hold for 5 minutes and then pressure off. Note that there are no returns to the surface during the entire procedure. Rig down Dowell. Break off lines to stack. Pick up stack and set slips. Lay down stub and bell nipple. Cut 7" casing. Install packoff and make up tubing spool. Install wellhead and test to 3000 psi. Nipple up stack and reconnect all lines and test to 3000 psi. Pump diesel down 9 5/8"x20" annulus for freeze protection. Lay down BHA and 5" drill pipe. Lay down 5" drill pipe. Rig up Schlumberger. RIH with gauge ring and junk basket. Tag up at 7565' and POOH. Pick up wireline tools CET-CBT-CNL- GR and RIH. Tag at 7585' and Icg. POOH and lay down logging tools. Rig down Schlumberger. Test casing to 4500 psi. Rig up Schlumberger lubricator and test to 500 psi. Pick up Schlumberger perforation guns and RIH on wireline. Fire guns at depth of 7222'-7220. POOH. Wait and watch to ensure that the well is stable. Pick up cement retainer and RIH on wireline. Set retainer and POOH. Rig down Schlumberger and prepare for squeeze job. DAILY CHRONOL OG Y N 'I E NO. 1 ! 3-13-96: 3-14-96: Set retainer at 7150'. POOH and rig down Schlumberger. Pressure test casing and retainer. Pick up stinger and 3 1/2" drill pipe. RIH with stinger and stab into packer at 7156'. Do cement squeeze job. POOH 5 stands to 6772', reverse circulate and displace 46 barrels. POOH and lay down stinger. Pick up 6 1/8" bit and junk basket. RIH. lay down 19 joints of drill pipe. RIH to 6635'. Pick up kelly and wash in and tag top of ,packer. Pull up off of packer and circulate. Wash to 7153' and tag top of retainer. Circulate out and drill out the retainer. Drill cement to its base at 7231'. Wsh down to 7270' and circulate bottoms up. RIH to 7572' and tag up. Circulate around a high viscosity pill. Pull up 4 stands to 7165' and test 7" casing through the choke to 5000 psi for 10 minutes. POOH and lay down junk basket. Pick up 7" casing scraper. RIH to 7576' and circulate bottoms up. Circulate around a high viscosity pill. POOH laying down 3 1/2" drill pipe. 7259' REPORT- T'-'u 7267' ClaystonelMudstone = med gry brn -med brn gry grdng to dk with occ dusky yellow hues; mod rrm - frm, becoming si hd & britt; massive w/no vis bedding structure; dull earthy luster overall w/corn micro sparkles from cryptomica; smooth - si gritty texture from occ silt inclusions; grades in part to a very fine siltstone. Siltstone = dom med gry grdng to It gry w/occ si brnsh & rare dusky yelsh brmsh hues; mod frm to frm w/a v si deg of hydration on outer edges of core surface; crushed and finely ground sample consists of approx 60% clays, 30% fine lower grain to coarse silt size qtz, & 5 - 10% med- dk bright green glauc nods; gen dull earthy luster w/corn microsparkles from cryptomica; smooth to v si gritty texture; massive no overall vis bedding structure although sample breakage planes suggest possible ripple marks; no apparent development of fissility; non calc w/ no vis pinpoint reactions; one chip showed branched worm tube (?) w/fine lower qtz, glauconite and lithic grain infill and v mnr clay matrix; grades to a claystone/mudstone in pts. Sandstone = med brnsh gry overall grdng to dk brnsh gry w/a med - si dksh bri grn speckled effect from glauc grns; indiv gms of clr - transl - It gry qtz, med - si dk bri grn glauc & v mnr dk gry/blk lithic frags; comp of 75% qtz, 20% glauconite and 5% lithics; mod frm - si hd& mod brittle; v fine lower grain to coarse silt size w/ occ coarse upper qtz inclusions; gen mod sphericity; sub rndd grdng to sub angular; gen grain supported w/silic cmnt; tr med brnsh gry silt matrix; pale thin yelsh wh nat fluor corn concentrated in v fine layers assoc w/faint fine bedding structure; pale slow streaming to occ blooming straw yel cut fluor; pale straw yel resid cut fluor & pale dull resid cut color; poor ~ occ si fair vis por & poor perm; si - occ fair show. grades to a med- coarse siltstone w/dec in glauconite content. SHOW REPORT- 7267' TO 7276' Sandstone = It gry overall with occ It brn hues & si speckled effect from bright med gry glauconite gms & v mnr dk grylblk lithic frags; mod frm - frm w/rare si hd, britt frags; gen sub rndd -occ mod well rndd aggs; indiv gms of clr - transl - It gry qtz, reed - occ dk bright grn glauc, dk gry/blk lithic frags & v mnr wht - It gry fspars; comp of approx 90% qtz, 5% glauconite & 5% lithics and fspars; gen coarse upper silt to v fine lower grn w/ occ med- upper v fine, rare coarser; mod to occ poor sphericity; dom sub ang grdng to sub rndd w/rare coarser being gen rounded; mod to occ poor sphericity;gen grain supported occ wl tr matrix support; tr silic cmnt & rare tr clay matrix; abdnt gas bubbles noted to be popping from freshly collected & washed ditch samples; mod - si strong pet odor noted on unwased sample; common & fast 2-3mm pops and blebs on water immersed sample; 90-100% oil sheen on blender sample; tr free oil noted on unwashed sample giving 30 - 50% med yelish wh nat fluor; 25 - 30% bri med yel nat fluor on washed sample; very si slow streaming straw yel cut on wet sample bec a si stronger slow strmng to occ blooming whitish yellow cut fluorescence on air dried sample; pale gold yel resid cut fluorescence; no vis resid cut color; poor to si fair vis por & poor permiability; fair show. SHOW REPORT - ?276' TO ?336' Sandstone = Light brown from the pervasive oil staining; ranges from very fine lower to fine lower; almost all is very fine upper to fine upper; abundantly well sorted in very fine upper range; quartz arenite; estimated 93% quartz, 2 to 5% glauconite; 2 to 5% lithics, chert, and other forms of cryptosilica; subrounded to rounded grains; spherical to subspherical shape; very weakly cemented, appears very minor silica cementation, locally appears to have some spotty intergranular clay; at it's best, the sandstone appears to be "held together" by oil tension; overall porosity appears good; sptty pieces appear to have fair porosity, and occasionally there is some very good porosity; strong petroleum odor from all souces: at shakers, in unwashed and washed mud, and very strongly from blendor samples; oil is pervasive in the unwashed mud, and commonly displays a light unbroken sheen; there are both gas and oil pops emanating from the unwashed mud, and the pops become extremely abundant when water is added to the samples; the unwashed mud shows a pervasive bright yellow to whitish yellow sample fluorescence and in plain light shows scattered to concentrated blebs of free oil; note that from roughly 7285' to 7310' there was an easily observable covering of light brown to iridescent yellowish brown free oil on mud moving over the shakers; the washed cuttings do not have significant free oil on the surfaces of each cutting chip; the wash water may be carrying away a fairly high gravity oil; the sandstone pieces do not cut very rapidly when wet, and the intensity of the cuts is moderately bright to pale yellowish white to bluish yellowish white with very slow blooming; when air dried the samples have an instantaneous translucent to transparent very bright bluish white to bluish yellowish white cut fluorescence with strong blooming and streaming; the visible cut in plain light is colorless to very faint straw color; the residual ring is a very light straw color that fluoresces a bright whitish yellow to slightly bluish yellow; permiability is "guestimated" to be highly variable, but is suspected to be better in the zones with the highest gas readings. SHOW REPORT - 7276' TO 7336' Sandstone = Light brown from the pervasive oil staining; ranges from very fine lower to fine lower; almost all is very fine upper to fine upper; abundantly well sorted in very fine upper range; quartz arenite; estimated 93% quartz, 2 to 5% glauconite; 2 to 5% lithics, chert, and other forms of cryptosilica; subrounded to rounded grains; spherical to subspherical shape; very weakly cemented, appears very minor silica cementation, locally appears to have some spotty intergranular clay; at ifs best, the sandstone appears to be "held together' by oil tension; overall porosity appears good; sptty pieces appear to have fair porosity, and occasionally there is some very good porosity; strong petroleum odor from all souces: at shakers, in unwashed and washed mud, and very strongly from blendor samples; oil is pervasive in the unwashed mud, and commonly displays a light unbroken sheen; there are both gas and oil pops emanating from the unwashed mud, and the pops become extremely abundant when water is added to the samples; the unwashed mud shows a pervasive bright yellow to whitish yellow sample fluorescence and in plain light shows scattered to concentrated blebs of free oil; note that from roughly 7285' to 7310' there was an easily observable covering of light brown to iridescent yellowish brown free oil on mud moving over the shakers; the washed cuttings do not have significant free oil on the surfaces of each cutting chip; the wash water may be carrying away a fairly high gravity oil; the sandstone pieces do not cut very rapidly when wet, and the intensity of the cuts is moderately bright to pale yellowish white to bluish yellowish white with very slow blooming; when air dried the samples have an instantaneous translucent to transparent very bright bluish white to bluish yellowish white cut fluorescence with strong blooming and streaming; the visible cut in plain light is colorless to very faint straw color; the residual ring is a very light straw color that fluoresces a bright whitish yellow to slightly bluish yellow; permiability is "guestimated" to be highly variable, but is suspected to be better in the zones with the highest gas readings. DAILY ACTIVITY SUMMARY ARCO ALASKA INC, WELL: NEVE ~1 TOTAL FEBRUARY, 1996' MARCH, 19~6 " ACTIVITY HOURS 14 15 16 17 18 19 20 21 22 23 24 25 Z6 27 28 29 I 2 3 4 Drill ! Core 204.0 14.5 20.0 "ii!i!!!i!i!!i!!i i!i!i!iiiii!iii!i i!!iii!!i!!ii!i! 20.0 20.0 22.5 17.0 15.5 14.5 5.0 ii!!ii!iiii!iiiii 8.5 1.0 3.0 !iiii?i!iii!i!ii 6.0 16.5 20.0 TripIBHA 120.0 7.0 2.5 10.5 ::::::::::::::::: 4.5 1.5 3.0 0.5 5.0 7.5 8.0 3.5 7.5 13.0 13.0 17.0 13.0 !iiiii[i!!!!!!ii!'!!!i!i!i!i!i!i!ii 3.0 ......... · ~-~C.~.~.~.~C '.'.'.:.'.'.'.'.' ' ............ Circulate 69.5 i:i:!:!:i:i:i:!:i:! 0.56.0 3.0 :.:.:.:,:.:.:.:. 1.5 1.0 1.0 1.0 1.0 1.0 13,5 12.5 :::::::~::::::::: 8.0 2.0 $.5 7.5 2.5 1.0 iReam 29.0 i:[:!:!:!:i:i:i:!:i:i:i:!:!:!:i:i:! 4.0 ::::::::::::::::::::::::::::::::: 1,0 i:i:i:i:i:i:i:i:ii:i:i:i:i:i:i:i: i:i:i:i:i:i:i:i::i:!:i:i?!:i:i:i 0.5 2.0 ~¥:¥:::¥:¥ 2.5 2.0 2.0 r:'::::?:':::':'] 10.0 5.0 ,....,..-.-...,. Work on Rig 0.5 :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ',:::::::::::::::: ::::::::::::::::, :::::::::::::::: ::::::::::::::::: :::::::::::::::::l 0.5 i:::::::::::::::: ::::::::::::::::: ::::::::::::::::: :::::::::::::::::::::::::::::::::: ::::::::::::::::: :::::::::::::::: :::: ::::::::::: i::::::::::::::::: '.:::::::: ::: ::: :::: :::::: ~..:.~...¥..;.;.;,~.~.~.~.¥.:.¥ ................................................. r.','.'.'.'.-.-.' '.-.'.'.'.'.'.'.' '.-.'.'.'.','.'.' '.'.'.'.'.'.','..'.','.'.'.'.'.'..'.'.'.'.'.-.'.'..-.-,-.'.'.'.-.' .-.','.'.'.-.'.' '.'.-.-.-.'.'.'.' -.'.'.'...-.'.'.' 'Casing/Cementing 10.5 ::::::::::::::::::::::::::::::::::::: 3.5 7.0 i!i!iii:~i:~ii!:~i~!~!i!::!::!::!::!i!~!::::!::!::!i!::!~!::!::!!~!i!i!i!::!::i::!i!~!::!::i::!::!i!i!::!:: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: i:~i~iii!iiiiiiiiii!i!ii::i::i::i::i::i::::i:~i:~iii~iii:~!:~i::!!::iii!iii~i::i::! :Ti::!iiiiii!i!i::i iii!!i!iiii!!i!i!iiii::i::!:.i:.iiii! ~ :::: ::'::: :':: :':: :':::::::::: ::::::::::::::::: ::::::::::::::::: :::::::::::::::::i :::::::::::::::: :::::::::::::::: ::::::::::::::::: ::::::::' BOP Testing/Rig-Up ~4.0 ::::::::::::::::::::::::::::::::::::::::::::::::::::: 10.5 19.5 :i:i:i:i:i:i:i:i: i:i:i:i:i:i:i:i: :i:i:i:i:!:i:i:i: :i:!:i:i:i:i:!:i :i:!:i:i:i:i:i:i i:i:i:i:i:i:!:!:! i:i:i:i:i:i:i:i: 4.0 :.:.:.:.:.:.:.:..:.:.:.:.:.:.:.:..:.:.:.:...:.:.? :.:.:.:.:.:.:.:.:.:.:,:.:.:.:.:.:..:.:.:.:,:.:.:.:..:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.: .:.:.:.:.:.:.::: :.:.:.:.:-:.:.:.: Cut and Slip Drill Line 0.5 -:.:.:.:.:.:-:.:,:.:.:.:.:-:.:-:.::.:.:.:.:.:.:.:.: :::::::::::::::::::::::::::::::::::::::::::::::::: :-:-:.:.:.:.:-:..:.:.:.:.:.:.:.:. 0.5 iii!i!iiiii!iiii iiii!ii!i!! i i i ii iii i iiiiiiiFiiiii!!iiii!i!i!iiiiiiiii ....................- ..... .., :: : :: :.: ::: :::-.::::..:-::.: :: ........ ::.:.:-:::: :::::::: :-:::::-:: :.:.:::::: ::::::::::::::::::::::::::: ................ ::::::::.:.::,:+:.:,, OtherActMties 12.0 2.5 1.0 i:!:i:i:!:i:i:i:il 3,5 :!:i!i!i:i:i:iiiii:!!i:!:iii:i:iii: :iii:iii:ii!!i!!!!i!!i!:i!!i!i!ii:iiiiii:i:i:i:iii ii:!ii!!:i:!ii:ii:!:iii:!ii:i:!:i,i!!!i:!:ii!!!:!i:!i:!ii:!ii:!:!!!: :::::::::::::::::::::::::::::::::::::::::::::::::: 4,5 0.5 '"'""'"'"'"...................-.........-,,,~'"'"'"'""'" TOTAL HOURS 480 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 24 REPORT DEPTH 7700 679 1860 1860 1860 1860 2722 3622 4632 5398 6131 7088 7259 7259 7267 7276 7336 7336 7336 7519 7700 FOOTAGE 7592 571 1181 0 0 0 862 900 1010 766 733 957 171 0 8 9 60 0 0 183 181 DAILY AVG 379.6 DAILY ACTIVITY SUMMARY ARCO ALASKA WELL: NEVE #1 , , TOTAL MARCH. 1996 ACTIVITY' HOURS 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 ZZ ;'3 24 Drill/Core 204.0 :i:i:i:i:i:i:!:i:i::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::: i:i:i:!:i:!:i:i:i,i:i:i:i:i:i:i:i: ,:i:.i!:::.:::.:::.:::.::i!:' ::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: i!:.!:.::!i:.:::.!!!:.:: ,Trip/BHA 192.5 11.0 10.0 9.5 12.5 5.5 i!:i:!:!:i:!:!:!::!:i:i:i:!:!:!:!: 14.0 10.0 ::::::::::::::: ::::::i::::: :::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Circulate 100.0 8.5 1.5 2.0 4.0 4.5 3.5 i:.:.:.:.:.:.:.:.: 1.0 5.5 :"'"':'"""' "'"'"'"""" """'"'"'"' '"'""'"'"" '"'"'"'"'"' :'"'"'"'"':" '"'""'"'"'" '"""'"'"'"' "'"""'""" "'"'"'"'"'" "'"' :.:.:.:.:::.:.:..:.:.:.:.:::.:.:..:.:.:.:.:.:.:.:.: .:.:.:.:.:.:.:.: .:.:.:.:.:.:.:.: :.:.:.:::.:.:.:.: :.:.:.:.:.:.:.:.: :.:::.:.:.:.:.:.: :.:.:.:::.:.:::. ,:.:.:.:.:.:.:,:..:.:.: Work on Rig 3.0 :i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:ii: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:ii:i:i:i:i:i:i:i: 2.5 ::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::'::::::::i:::::::i::::::::::::i:::i:i::: ::::::::::::::::':::i:::::::::i::: Casing/Cementing 25.0 :::::::::::::::::::::::::::::::::::: ::::::::::::::::: :::::::::::::::::: 9.5 2.5 ::::::::::::::::: 2.5 ::::::::::::::::J :::::::::::::::: :::::::::::::::: ::::: :::::::::: ::::::::: ::: :: :::::: :::::::::: :::::::: ::":::::::::::::: :::::::::: :':': :'::: '.'-'-'.'.'.'-'- .'-'-'.':'-'-'.'- .'-':'.:.'.:.'.'..'-'.'.'-'.'.'.' '-'-"-'.'-'.'.':' ::'.'-','.'.'.:.' '.'.'.'~'L:.':';' ','.'.','.".'.':l.'.':'.'.','.'~:: .'.'.'::.'.',:.'..','.':':'.'.'.': .'.:.'.':".'.".' .::'i .... '. .......... i ..... . ..... . ........................ BOPTesting/Rig-Up 51.5 !:i:!:!:!:!:i:!: :i:i:!:i:i:i:i:!: 2.5 ::::::::::::::::: ............... ::::::::::::::::' 15.0 ::::::: ::::::i:: :::::::::::::::::::::::::::::::i:!:!:::i:!:!:i: i:!:!:!:!:!:!:!::i:i:i:i:i:i:::i: :i:i:!:!:i:i:i::: :i:::i:i:::::!:! ::::::!:i:::::i:! :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::: :::::::::::: Other Activities 75.5 3.5 11.0 5.0 :!:i:i:!i:.:i:i:: 4.5 3.0 21.5 6.5 8.5 ::,::,:i:i:i:i:i:i: ~:.:.:~:.:`:~:~:':~:~:.:~:.:~:~:.:+:.:~:~:.:~:.:~:~:.:~:~:~:~:~:~:~:~:~:~~~:~~.:~:~:~'~~~.~:.~`~.~~:.::::~.~~:~:~:.:~:~`:.:~~~:.:~:`:~~.~:~:~:~.`:~:~:.:~~:~:~:~:~:~:~:~: TOTAL HOURS 696 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 24.0 REPORT DEPTH 7700 7700 7700 7700 7700 7700 7700 7700 7700 7700 FOOTAGE 7592 0 0 0 0 0 0 0 0 0 DAILY AVG 261.8 RCoAILY MUD REPORTS ALASKA INC. Well: NEVE #1 Mud Dais Provided By: BAROID MUD SYSTEMS DATE DEPTH MW VIS PV YP GELS pH FILTRATE CAKE MD ALKAL FL ALKAL CI- Ca+ Sd Sol MBT 2/14196 135' 10.0 96 50 34 314 8.0 10.0 2 0.00 0.00t0.60 600 80 0.0 9.0 30.0 2/15/96 679' 10.0 92 26 35 12/37 8.2 9.6 2 0.00 0,00/0.10 600 20 0.75 8.0 17.5 2/16/96 1860' 10.0 65 19 23 14/38 8.2 9.6 2 0.00 0.00/0.20 900 20 0.75 8.9 17.5 2117196 1860' 10.1 78 24 27 12/38 8.1 9.2 2 0.00 0.00/1.50 1300 20 0.75 8.9 17.5 2/I8/96 1860' 10.1 70 26 21 9~32 8.1 9.2 2 0.00 0.00/1.80 1300 80 0.75 9.9 20.0 2/19/96 1860' 10.0 55 20 18 6/30 8.1 9.6 2 0.00 0.00/1.80 1200 80 0.50 9..0 20.0 2/20/96 2760' 10.2 41 16 8 2/12 8.5 9.6 2 0.00 0.08/1.00 1600 240 0.25 9,9 12.5 2/21/96 3700' 10.3 44 16 12 2/15 9.2 6.8 2 0.00 0.15/1,50 1300 100 0.25 10.4 15.0 2122/96 4642' 10.2 39 13 9 2/10 9.0 6.6 2 0.00 0.08/1.10 1100 60 0.25 10.4 17.5 2/23/96 5460' 10.3 40 15 9 3/14 9.1 6.5 2 0.00 0.12/1.60 1100 60 0.25 11.4 20.0 2124196 6141' 10.2 40 14 8 2/6 8.8 6.4 2 0.00 0.0611.20 900 60 Ir 10.5 20.0 2t25t96 7088' 10.3 42 14 8 2/5 9.0 6.2 2 0.00 0.10/1.60 900 40 Tr 12.0 20.0 2/26/96 7259' 10.2 39 13 7 2/5 9.3 6.2 2 0.00 0.20/1.80 600 60 Tr 10.5 20.0 2/27/96 7259' 10.2 66 22 16 2/4 8.2 3.4 1 0.00 0.0010.00 34200 120 Tr 9.1 7.0 2/28/96 7267' 10.3 64 26 18 2./7 8.0 3.2 1 0.00 0.01/0.05 33700 112 Tr 9.7 7,0 2/29196 7276' 10.6 79 34 24 3/10 8.0 3.0' 1 0.00 0.02/0.05 35500 140 Tr 11.1 7.0 3/01/96 7336' 10.5 73 28 17 2/8 9.5 4.0 1 0.00 0.00/0.00 27000 100 Tr 10.6 7.0 3/02/96 7336' 10.5 72 24 15 2/7 8.2 3.4 1 0.00 0.1010.90 28000 112 Tr 10.5 9.0 3/03/96 7336' 10.5 68 24 19 3/7 8.0 3.2 1 0.00 0.04/0.60 26000 140 Tr 10.6 10.0 3/04/96 7530' 10.5 60 21 21 4/12 8.0 3.8 1 0.00 0.05t0,50 27000 140 0.25 10.6 10.0 3/05/96 7700' 10.5 60 24 24 4/14 8.0 4.0 I 0.00 0.00/0.80 24000 200 0.25 10.7 12.5 3/06/96 7700' 10.6 65 24 25 4/12 8.0 4.2 1 0.00 0.00/0.70 25000 240 0.25 11.2 12.5 3/07/96 7700' 10.7 70 25 22 3/12 8.0 4.2 1 0.00 0.00/0.80 27000 200 0.25 11,6 12.5 3/08196 7700' 10.9 65 25 21 3/10 7.8 4.0 I 0.00 0.00/1.20 26000 360 0.25 12.6 12.5 3/09/96 7700' 11.0 65 25 21 3/10 7.8 4.0 1 0.00 0.00/0.80 26000 360 0.25 12.6 12.5 3/09196 7700' 11.0 82 28 25 4/14 8.0 4.2 I 0.00 0.00~2.00 27000 320 0.25 13.1 15.0 3/10196 7700' 11.0 76 24 20 3/10 8.0 4.6 1 0.00 0.00/1.60 27000 480 0.25 12.5 15.0 BIT #2 ~s run with ~ mudmotor. ~hen POOH ~t 6132, it ~s di~overed that the mudm~tor h~d ~iled. The EP~ values sho~n ~re surface ~lues only. The mudmotor produced 0.500 revolutions per gallon. The pump output through the entire run was 490 to 540 GPM. Downhole RPM's possibly as high as 360, but very likely were closer to the surface values. ~~~~~;~~~~~~~~~:~~:~::::::::::::::::::::::~~~~~~~~~;~~~~;~~;~~~~~;:~~~~;~~:~¥~~~~;~~;~~~~~;~~~:~~~~~:~~~;:~:~:~~~~~:~:;~~:~~~:~~~~~~::~~:~~:~:~~~:~~¥:::::~:~:::~:¥~~~~~~:~~;~~~~~;:~:~::~~~~:~:~;;~~::~:~~~:~~~;:~:~~~~::;~;~~~~~:~~:~~~;:~~~~~~~~:~;~:~;~::~~:;~¥~~~:~~~~;~~~;~;~;;:;;~~~~;;¥~~:;~~:¥:¥ :::;:¥:;:::¥:¥:::;::::;¥:;:¥:::::::¥:::::::¥::;::¥;¥:::¥:::¥:::¥:::;:¥;¥:: Epoch Well Logging. Inc. MU. WT: 40.0 tiiiii::i::iiiiiiiiiilFo" T ON: Gravel, s,,., I!iii!i::iiiiiii::i!iii::it" <G"NO GAS: :!3!: !:!3!:!: !3! :!:!:i:!:!:i:!:!:! :! :!:!:!3!:!:!: i: i:i: !: i:!:!:!:! :!3 !:i :!:! :!:!3!:! 3! :!:! :! :!:! 3!:!:!:! :! 3! :! 3! :!:!:!:!:i :! :! :i:i:!:!: !:!:i:i :!:!:!:!:!:i:!:! 3! :!3! :!:!3 !3! :! :!:!:!:!:i:!:!:! 3! :! :! :! :!:!:!:i :!:! :!:! :! :!:!:!:i:!:!:i:!: !:i:i :! 3!: !3!: !3! :i: i:!:!:!:i:!:i:i :!:!:!:!: i: !: !:!:i:i: i:i: CON. GAS: None I :!ii:!i!i!ii!i!iiifRi" GA$':'N°ne ' ii!ii!iii!iiiiiiiiiilMAXIMUM GAS: 8.0u jii!i!i:iii!iiiiiiiiiiiiDC EXPONENT: 0:30 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::ii!i!iiiiiii!iiii::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::!!i!!!!iiiiii!iiiii:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::i!iiiiiii!!!iii!i!iii!:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: giT INFORMATION: No. Size Type Sedal No. ,lets Interval Footage Hours Condition 1 12 1/4" STC MA1SL LE3939 15,15, c 10 t08'o In Hole MUD INFO: MW VIS PV YP GELS FL FO SOL OIL SD MBT pH CI Ca+ 10.0 95 50 34 013 5 1 1 $.0 0 0 15 8.0 600 20 DRILLING PARAMETERS: High Low Average Rate of Penetration 95 at 110' 26 at 130' 66 fi/hr Surface Torque 45 at 122' 14 at 119' 23 Ft-lbs Weight on Bit 3 at 109' 17 at 131' 10 Klbs Bit RPM 82 at 110' 81 at 135' 82 RPM Pump Pressure 477' at 134' 454 at 111' 463 psi GAS SUMMARY: High Low Average Total Ditch Gas Out: 8L~LJ.o at 135' 2 at 109' 3.0 units Methane (0-1) 1600 at 135' 300 at 135' 600 ppm Ethane (0-2) at at ppm Propane (0-3) at at ppm Butane (0-4) at at ppm Pentane (0-5) at at ppm Total Cuttings Gas: 1 at 130' 1 at 130' 1 units Connection Gas: units average units max, Trip Gas: units @ :HYDROCARBON SHOWS: NONE LITHOLOGY: Disaggregated Conglomerate/Gravels 90% Sand 10% iDAILY ACTIVITY SUMMARY: Introduce spud mud; test BOPE: pick up NB #1, stabilizers, mudmotor, and MWD; RIH 89'; circulate mud; check valves and lines in the mud system; observe some leaks in the mud system lines; POOH: repair leaks: RIH; break circulation; test MWD tool; circulate and ream through conductor fill; drill to report depth. MuG WT: ao.o liiiiiiiii!ii[iiii}lFORMaT~ON: Gravel, Sand, Claystone I!iii[iiiiii!iiiiiiii!i}laKORND OAS: 2u ~:'0',,' '&A~ ':"'"gag. ........ I:.:.:.:.~:~:~:.:.:.:. :.t~'~l~" '&A~ '-'. '"'0"; ........ t:.~:.:.:.:. :.:.:. :. :1 '~i~O~" ~'AS' :'. '~'AA. ............ I:.'~~ib~"~AP'O'aAN'+":" ~:.:.:. :.:.:. :. :. :.:. . . ~ .... '"'"" ' BIT INFORMATION: No, Size Type 1 12 1/4" STC MA1SL Serial No. Jets Interval Footage Hours Condition LE3939 15,15, c 10 108'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ 10.0 92 26 35 12/37 9.6 2 8.0 0 0.75 17.5 8.2 600 20 DRILLING PARAMETERS: High Low Average Rate of Penetration 1432.8 at g35' 9,0 at 639' 151 ff./hr Surface Torque 80 at 433' 12 at 224' 34 Ft-lbs Weight on Bit 19 at 938' 0.5 at 529' 6 Klbs Bit RPM 86 at 180' 75 at 337' 80 RPM .O, um Pressure 1652 at 881' 275 at 200' 1159 psi :::: :::::: :::: ::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 807' 0,5 at 250' 3,3 units Methane (C.1) 1440 at 807' 100 at 250' 653 ppm Ethane (C--2) ' at at ppm Propane (C-.3) at at ppm Butane (C-4) at at ppm Pentane (C--5) at at ppm Total Cuttings Gas: 3 at 270' 1 at 780' 1.6 units :i:i:i:! :i:i:i: i:!:!:i:i: i:i:i:i:i:i:i :i:i:i:i:!: i:i: i: i:i:i: i: i: i:i:i:!:i:i:!i!:i:i:! :i:i:i:!: i: i:i:i:i:i:i:i:i:i: i: i:i:i:!:i:i:i:i: i: i:i:!: !:!: i:i:i:i:i: i:i:i: i:i:i:i: i: i: i:i:i:i:i:i:i: i:i:i:!:i: i:i:!:i:!:!:i :i:!:i:i:i: i: i:!: i:i:i: i:i:i: i:i:i: !: i:i:i:i:i:i:i:i: i i!ii!i:i: !ii:i: !:iii:i:iiii!i!i!!iiii!i!!!iiiii ii!! !ii! ~;~.~;~.~.~~~;~.~~.~.~.~..~~.~.~.~;~~ ;,',i~;'""~'" ........................ Connection Gas: units average units max. Trip Gas: units @ HYDROCARBON SHOWS: NONE LITHOLOGY: Disaggregated Conglomerate/Gravels 56% Sand 43% Mudstone 1% DAILY ACTIVITY SUMMARY: Drill from 135' to report depth. ............................................................................................. !~~::~:~::::::::::::~:~::~::~::~:~~:::::::::~~::::~::~:~:~:::~:~~:::~:::~::~~~:~:::~:::::::::::~:::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::~:~::::::::::::::::~:::::~~:::::::::::::::::::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::¥:¥:::::::::::::::::::::::::::::::::::::¥:::::::::::::::i:i:::i:i:¥ DEPTH: 186o; 'i(4~0~AM} ............ ~e;t~da~: ....... ~95; ..............~4'H~¢'P~'g~&s~: ......... I'~ 0~; ' ~[~;~[;~;~;~;~:i~i~i~;~;~;;~;:~i~;~: ~~~ .......................................................................................... ~.; ...:.. :~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~~~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.~~ E:~:~:~:~:~:~:~:~:~:~:~:~:E:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:E:~:~:~:~:~:~:~:~:~:~:~:~:~:i:~:i:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:E:~:E:;:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:;:~:~:~:E:~:~:~:~:E:~:~:~:~:E:E:~:~:E:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~: ~UD ~: 10.0...........Ii~::~::~?:~::~::~::IFoR~ATIO~: Siltstone, Sandstone, Claystone [~::~::~::~?:~::~??~JBKGRHD GAS: 2u CONN GAS: None i~?:?:~::~::::~TRIP GAs: ~3u l~?;~?~?:.l~u~ GAS: 6.9u I::~::~[~?IDc EXPONENT':' 0.77 ' ....... :: ..... :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: BIT INFOR~TION: No. Size Type Serial No. Jets Inte~l Footage Hours Cond~ion 1 12 1/4" STC MA1SL LE3939 15,15, c 10 108'-1860' 1752' 19.74 In Hole :;:::~:::~::~:::~:::;:..::::~;~:~:::~:;:::;~~::::::~~~::::::::::::~:::::::::::::::~::::::::~:::~::::::~:::::::::::::::::;:~::::::::~:::::::::::::~:::::~:~:::~~::~:::;~:~:::::::~:::~:::::::::::::::::::::::::::~:::::~:::;:~:::::::~:::::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~::::::~::::~:~::::::.:::: ~~~.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~..~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~.~~~~~~~~~~~~~~~~~~~~~~..~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~ MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ 10.0 65 19 23 14138 9.~ 2 9.0 0 0.75 17.5 8.20 600 20 :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......-................ ...... ..,.......... ............ .._ ..... .... .... ..... .... ...... ............................................................................................................ DRILLING P~METERS: High Low Average Rate of Penetration 1499.0 at 1058' 10.0 at 1596' 151.1 ~hr Su~ce Torque 162 at 1810' 7 at 1412' 92 Ft-lbs Weig~ on B~ 19 at 1172' 0.1 at 1535' 7 Klbs Bit RPM 80 at 1782' 10 at 1412' 78 RPM Pump Pressure 1652 at 1058' 677 at 996' 1~0 psi GAS SUMIViARY: High Low Average Total Ditch Gas Out: ~ at 974' 1.0 at 1167' 2.7 units Methane (O-1) 1380 at 974' 181 at 1167' 529 ppm Ethane (0-2) at at ppm Propane (0-3) at at ppm Butane (C,-4) at at ppm Pentane (0-5) at at ppm Total Cuttings Gas: 6 at 1860' 1 at 1150' 3.1 units Connection Gas: units average units max. Tdp Gas: 13 units @ 1860' HYDROCARBON SHOWS: NONE LITHOLOGY: Siltstone 44% Sand/Sandstone 31% Claystone/Mudstone 23% Gravel 2% DAILY ACTIVITY SUMMARY: Ddll from 995' to 1860'; circulate bottoms up; POOH; RIH; encounter several tight spots while running in; work pipe, ream, and wash through tight spots; run to bottom; circulate bottoms up; pump high viscosity sweep; continue to circulate and clean hole. DATE: FEBRUARY 17, t996 i:!:!:i:!:i:i:i:i:i:i:i:i:!:i:!:!:i:!:!:!:i:i:i:i:i:!:!:i:i:i:!:i:i:i:J:i:i:i:!:i:i:i:i:!:i:}:i:i:i:i Casing to Date: 16" at 108' ....................... .:-:.:-:.:.:.:.:.:-:-:-:.:.:.:.:.:.:.:.:.:.:.: :i:i:!:!:i:i:!:i:!:i:i:i:!:i:i:i:!:i:i:!:!:i:i:!:i:i:i:!:i:i:i:i:i:i:i:i:!:i:i:i:!:i:i:i:!:i:!:i:!:!:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:!:i:!:i:i:!:!:!:i:!:i:i:!:!:!:i:i:i:i:!:i:!:i:!:!:!:i:!:!:!:!:i:i:i:i:i:i:i:i:i:!:!:i:i:i:!:!:!:!:!:i:i:!:!:!:!:!:!:!:!:!:i:i:!:!:!:!:i:!:::::::::::::::::::::::!:!:!:i:!:i:!:!:!:!:!:i:i:!:!:i:!:!:!:! ~'~"': ..... ~`~i~.~i~.~:i~i~.~;.;i~;~;a;~;~..`~i.~b~.~.~.~.~.~.;~;;~.~.~;~;.;;~.~.~~~!~i!:: MUD ~: 10.0 ~::~::~::~::~::~IFORMATION: SiEstone, Claystone, Sandstone I~::~::~IBKGRND GAS: 2u CONN GAS: None i~:~:~TRIP..,.............. GAS: 8.5u i~~IM~IMUM................... GAS: 8,5u i~~IDC...................... EXPONENT: 0.77 :.:~:.:~:.:.:~:.:.~~:.:.:.:~:.:.:.:~:.:.:~:~:.:~:~:.:.:.:.:~:.:~:.:.:`:~:.:.:.:.:~:.:.:.:.:.:.:.:~:~:.:.:.:~:.:~:.:.:.:~:~:.:.:~:.:~:~:.:~:.:~:~:~ ......... ~BIT INFOR~TION: No. S~e T~e SePal No. Jets Inte~al Footage Hours Cond~ion 1 12 1/'4" STC MA1SL LE3939 15,15, c 10 108'-1860' 1752' 19.74 3-E-In ~UD INFO: MW VIS PV YP GELS FL FC SOL OIL SD M BT pH CI Ca+ 10.1 78 24 27 1~38 9.2 2 8.9 0 0.75 17.5 8.10 1300 20 DEILLING P~ETERS: High Low Average Eate of Penetration at at Su~ce Torque at at Ft-lbs Weig~ on Bit at at B~ EPM a~ at RPM ~ump Pressure at at psi . ~AS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 1860' 1.0 at 1860' 2.5 units Methane (C-1) at at pprn Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units i~;i;~';';~'~' '~'~;?'""'"'"'"'"'"'"~' ;;'~i~ ;" "'" '"" '"'"' '"'"'"'"'"'""' "'"'""'""'"'"'"' '"'""'"' """'" "'"'"" '"'"'""" '~,'~;~;' ~;;;i"'""'""'"""'""'"'"'"'"'u'~';' '"~'"'"' ...................... Connection Gas: units average units max. Trip Gas: 8.5 units @ 1860' HYDROCARBON SHOWS: NONE LITHOLOGY: N/A DAILY ACTMTY SUMMARY: Circulate and clean hole; pump high viscosity sweep; POOH; RIH: work pipe, ream, and wash through tight spots on way in; circulate and clean hole; POOH; lay down drill collars; dg up and run 9 5/8"(53.5 lb/fi) casing; casing landed on bottom at 1860'; dg up circulating head; pickup 12' and work casing back to bottom while circulating; circulate bottoms up; prepare for cement job, .:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:~.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:. :.~~:~:.:.:.:.:.:.:.~.~.:~:~~..:~~..:~~.~.:.:.:.:.:.:.:.:.:.:.:.:.~.:.:~:~:.:.~.:.:.:.~.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:~~.:.:~:.:.:.:~:.:~:.:.:~:.:.~.:.:.:.:.:.:.~.:.:.:.:~:~:.:.:.:.:.:.:.:.:.:.:.:.:.~.:.:.:.:.:.:.:.:.:.:.:.:.:.~.:.:~:.:.:.:~:.:.: ~UD ~:..!0r! CONN GAS' None I~?:?:?:~?:?:~T~IP GAs: S. Su t~?:~?~;~;~l~,~u~ GAS: 8.5u l??~{~:/IDC EXPONENT: 0.77 ~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~: BIT INFOR~TION: No. S~e T~e Serial No. Jets Inte~l Footage Hours Condition 2 8 1/2" ' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: MUD INFO · MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ 10.1 70 26 21 9/32 9.2 2 9.9 0 0.75 20 8.1 1300 80 DRILLING P~ETERS: High Low Average Rate of Penetration at at ~r Su~ce Torque at at Ft-lbs ~eight on Bit at at Bit RPM at at RPM Pump Pressure at at psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 1860 0 at 1860 0.5 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Connection Gas: units average units max. Trip Gas: 8.5 units @ 1860' HYDROCARBON SHOWS: NONE LITHOLOGY: N/A DALLY ACTIVITY SUMiVlARY: Circulate bottoms up; continue to circulate preparing for cement job; pump cement; displace with mud; bump plug; rig down circulating head; cut casing to top of spool; wait on cement; do rig maintenance work; do a top job; nipple up BOP's; condition surface mud. ............................................................................................ DATE: FEBRUARY 'I, 9, 'I, 996 !iiiiiiiii!i!!iii!i!i!i!i!i!!!i![!!!iii!i!i!iiiiiii!ii!!iii!i!iiiii!i!iii[iiiiiiii!!iiiiiiii!ii!iiiiiCasing to Date: 16" at 108', 9 5/8" at 1860!iiiiiiiiiiii!i!i!i!i!i!!iiiiiiiiiiiiiii!i!i CONN GAS: None i?~?~?~iTR'P,...........,.... GAS: None I~IM~IMUM ~aS: ~.Ou EXPONENT: n/a BIT INFORMATION: No. Size Type 2 8.50" HYCALOG SX7082*6V Serial No. Jets Interval Footage Hours Condition 17660 6-10's 1860'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth: 1860' 10.0 55 20 18 6/30 9.6 2 9.0 0 0.5 20.0 8.1 1200 80 DRILLING PARAMETERS: High Low Average Rate of Penetration at at ft/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM Pump Pressure at at psi ;AS SUMMARY: High Low Average Total Ditch Gas Out: ~ at In Casing 0 at In Casing 0.5 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C--5) at at ppm Total Cuttings Gas: at at units Connection Gas: units average units max. Tdp Gas: units ~.~.~.:.:.:`:.:.:~:.:.:~:.:~:~:.:.:~:.:~:~:.:.:~:.:.:.:~:.:.:.:.:~:~:.:~:.:.:.:.:.:.:.:.:~:~:~:.:.z.:~:~:.:.:~:~:~:.:~:.:..~.:.:.:.:~:~:~:~:`:~:.:.:~:.:~:.;~;.:~:.:.:~:.:.:.:.:~:~:~:~:~:.:~.~.:.:.:~:~:~:.:.:~:.:.:~:.;.:.:.:~:.:~:.:.:.:.:.:.:~:.:.:.:.:.:.:.:.:~.~.;~:.:.:.:.:.: HYDROCARBON SHOWS: NONE LITHOLOOY: N/A DAILY ACTMTY SUMMARY: Nipple up BOP's; test BOPE; pickup NB #2 and BHA; RIH; tag top of cement at 1695'; drill cement; drill out float collar; pressure test casing. · ~f:DDI In-DY "J'l't 4G R ..~...~.~.............*~.~~.~`~.~~~~~~.~~..~..~..~...~..~.~~~~~..~..~.~.*.~...~....~~.........~~~~... ' · " ~ " t.'.'.'.*,'.'.'*'.'**.'.'.*.'.'.'.'.'*','.'* O.A..T.E: ...... ,..-..-,:m~.-.,..--..-,.,..,x9.,,. .... :::::::::::::::::::::::::::::::::::::::::::::::~:::::~:::::~:::::~:::::::::::::::::::::::::~:::::::::~c~s. !qg. t.o.. D.a!e: .... !.6..~.t. !.o.e., .... e..5/.e., mt. ::::::::::::::::::::::::::::::::::::::::::::::::: ~~~~~~:~~~:~~~~~~~~~~~~~~~~.:~~.:.?~~~~:~:~:.~~~~:`:~~~:~~~~~:~:~:~:~:~~~~~:~:.:.:~~~:.~~:~:~:~:':~:~:~~~:~:~~~~.~~b :~:.:~~.:~~~:~:.:~~~:~~~~.~.~~~~~~:.~~~~:~:~:.:~~.:.:~:.:~:~:~:~~~:~:~~~~~~~:~~~~~~~:~:~:~~~~~~~:~:~:~~~:~:~:~:~~~~~:.:~:.~~:.:~:~:~:~:~F F F F F F F;.F F:';'hF Fb F F b F F F h F b F F F F F:.F DEPTHi 2857' 1(4io0'Aui ............ 9e'~'t'~?aa~: ....... i8~0; ............. ~24'H;1~. 'l~.0'g~es's: ......... i "' bg 7; ' ,~!::!::i::i::i::i::!::!::!::i!!::i::!::i::iii::!::ii!::i::/::!::!::!::i!!::!::!!!ii::!::i::i::!::!!i ::i!i::i!i::i::i::i::i:: !::!::i: !~~.~.:.:.:~~~~.~~~~~~~~~~~.~~~.:~~.`~~~~~.~.~~*..:~~.:.*`.~~~~..~~~~:.~~~~~.:~`*.~*`:~~~~~~~.~~~~:.:.:.:~~*~~.~~.~.~~.~~~~~.~~:~~~~.~~.~~~.:~~.:.:~:.:~:~~~~..`.~~~~~~:~~~~.:.~.:.~.:.~.:~:.~..".`*~~..*~:.~.~.~~:.~`...~.*.~~~.~.~.~.~.~.~.~~~~~~:.:.~~~.:~~.~.~:.:.~.:~~~~.~.:.~.~.~.~.~.:.~.:.:.~.~.~.:.:.:`~.~.~.~.~.:.~.:.~.~.~.`*.:.:.~ BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 2 8.50" HYCALOG SX70B2+6V 17660 6-10's 1860'- In Hole :!:i:!:!:!:!:!:i:!:i:!:!:i:!:!:!:!:!..!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:i:!:!:!:!:!:!:!3!:!:!:!:!:!:!:!:!:!:!3!:!:!:!:!:!:!:!:!:!:i:!:!:!:!:!:!3;:!:!:!:!:!:i:!:!:!:!:!:i:!:!:!:!:!:!:!:!:!:!:i:!:!:!:i:!~!~i:i~!:!:!~!%!~!:!:!:!:!:!:!:!~!~!~!:!:! MUD INFO: MW VIS PV YP GELS FL FO SOL OIL SD MBT pH Cl Ca+ Depth' 2760' 10.2 41 16 8 1/30 9.6 2 9.9 0 0.25 12.5 8.5 1600 240 !:!:}:!!!:!:!8! 3 !!!:!:i!!:!:!:i:i:!:i:i:i:i:!:i:i:i:i:i:i:!:i:!:i:i:!:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i 8 i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:}:i 8 i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:!:i:!:i:!:!:!:!:i:i:i:i:!:i:!:!:!:i:i:i:!:! DRILLING PARAMETERS: High Low Average Rate of Penetration 387.8 at 1882 11.1 at 1861 98.1 fi/hr Surface Torque 264 at 1872 33 at 1867 114 Ft-lbs Weight on Bit 12 at 2853 0 at 1994 5 Klbs Bit RPM 80 at 2854 16 at 1867 77 RPM Pump Pressure 3121 at 2576 254 at 1861 2414 psi ".~AS SUMMARY: High Low Average rotal Ditch Gas Out: ~ at 2387 0.5 at 1863 93.4 units Methane (C-1) 105252 at 2400 - 101 at 1863 15580 ppm Ethane (C-2) 7686 at 2387 0 at 720 ppm Propane (C-3) 5225 at 2387 0 at 445 ppm Butane (C-4) 2661 at 2387 0 at 208 ppm Pentane (C..5) 403 at 2387 0 at 28 ppm Total Cuttings Gas: 36 at 2400 3 at 2010 13.8 units Connection Gas: 60 units average 165 units max. Trip Gas: units ~:~:~;~:~?~:~??~:~:~.~.~.:.:~;~.~.;~:~;~:~.~?:~;*;~:~.~??~:~:~??b~.:.:~:~:~;~;~;~;~:.;.;.:.~.?:.~.;.?:.:~:~.b:.:~?;.b?;.:.~`~.;.:.;.~.~:.~b;.;~:~:~?~;~;~?F b b F F ? FF? F ..~~:.~~:.:~~~:~:~:,~~:~:~:.:.~~:~~.~~:~:.~~~.:.~.:.:::.:~:~:.:~:~~~~.:~:.:~~.:~~.~~:~:~:~:~:.:.:.:.:.:~:.:~:.:~:~:.:.:~:.:~:~~~:.:.:`:.:~:~:~:~:~:~:~:~~~:.~~~~:~:~:~:.:~:~~~:.:~:~:.:.:.:.:~:~:~:~:~:~:~~~:~:~:.:~:~:~:~:.:.~~:.:.:.;.:.:.;.;.:.:.:.:.:.:.:.:.:d`:E.:.:d.;.:d E HYDROCARBON SHOWS: NONE LITHOLOGY: Shale 30% Tuff/Bentonite 25% Claystone 20% Sandstone/Sand 17% Silststone 3% Calcareous tuff 2% Tuffaceous claystone 2% DAILY ACTMTY SUiViiVIARY: Pressured test the casing; drill cement; drill out the casing shoe; drill 10' of new hole to 1870' and run leak off test; drill from 1870' to 2857'; do 10stand wiper trip; ddll to report depth. ............................................................................................ ~:~i:i:i:i:i:i:i~i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:?i:i:i:i:!:i:!:i:i:!:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:!:i:i:i:!:i:i:i:i:i:i:i:i:i:!:!:!:!:i:i:!:i:i:i:i:i:!:i:!:i:i:!:i:i:i:!:!:i:i:i:!:i:!~!:::i:i:i:i:i:!:!?i:!:!:!:i:!:!:!:!:i:i:i:i:!:i:::i:!:i:i:!:i:i:!:!:i:i:!:i::!: ~.~~.~~.~.~.~:~:~:~:~:~:.:~:~:~:~:~:~:~:.:.:.:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~::~~.~~.~.~~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: · r=~l I,~g)v ,,),! 4~o~ ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~.~~~~.~~~~~~~~.~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~ ' ' " ' " 60 '.'* '.'-'.'-'.' '-'' '.'' '.'.'.'.' '.' DATE ............. ,,~, ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Casing [o Date. 16 at 108, 9 5/8 at 18 . ....................................... ~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:.:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:.:~:~:~:~:.:~:~:~:~:~:~:~:~:.:~:~:.:~:~:~:~:~:~:~:~:.:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~.~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:. .:.:.:.:.:.:.:. DEPTH: '3800; '{~4~06AU~ ............ 9e;t;;dh~: ....... 2~i: ............. ~'H;6;'P;;'g;es¢: ......... ================================================================================================== :::::::::::::::::::::::: mud ~: aa,3 I~}~::~}~}~}~}IFORmT~ON: Cl~stone,. ............. Shale, Tuffaceous claystone . I.:.:.:.:?~:~:~:}.:.:.:.:.: :~:~:~ :[:~:~:~.:.:.IBKGRND GAS': 30u ~:~:~:~:~:~:.:.:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:.:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:.:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~::..~~:~~.~:~:~:~:~:~:~:~:~:~~~~:~:~:~~~~:~:~:~:~:~:~:.:~:~:.:~~~:~:~:~:.:~~~:~:~~~~~~~:.:~:~:~:~: ''''' :: ;: :: :: :::: ;: :2 :: :: :: :::: :::; :: 2: :: :;:: :: :2 :; :: :;:::: :: ;: ;: ;: :: :: :: :: :: :: :: :: :; :: :::::: :: :::: :: :: :: :'. :::: :: :: :: :: :::: :::: :: :; :::: :: :: :;:: :: :::: :: :: :: :: 7::: :: :: :: :: :: :::: :: :: :: :: :: :: :::: :: :; :: :: :: :: :: :: :: :: 2::: :: :: :; :: 7::::::::: :: 2: :: :: :::: :::: :::::: :: :: r22:~2~2 ¥5 ¥222 ~r :: 2522 ¥2 :~ 2~ ¥::222:~¥: ;~2272 2 ~52r 725[22:2: 2::2 ¥222 BIT INFOR~TION: No. S~e T~e SePal No. Jets Inte~l Footage Hours Condition 2 8.50" ~CALOG SX70B2+6J 17660 6-10's 1860'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth' 3700' 10.3 44 16 12 ?_J15 6.8 2 10.4 0 0.25 12.5 9.2 1300 t00 DRILLING PARAMETERS: High Low Average Rate of Penetration 161.0 at 3045 5.7 at 3695 71.0 fi/hr Surface Torque 178 at 3741' 37 at 3356 134 Ft-lbs Weight on Bit 12 at 3547 1 at 3356 7 Klbs Bit RPM 80 at 3607 48 at 3284 79 RPM Pump Pressure 3108 at 2906 1916 at 3613' 2475 psi ~S SUMMARY: High Low Average i'otal Ditch Gas Out: ~ at 3027 19.1 at 2861 60,2 units Methane (C-1) 27384 at 3027 3004 at 3474 8958 ppm Ethane (C,-2) 2084 at 3027 200 at 2896 571 ppm Propane (C-3) 1961 at 3027 48 at 2936 254 ppm Butane (C-4) 422 at 3049 2 at 2975 96 ppm Pentane (C-5) 87 at 3769 0 at 7 ppm Total Cuttings Gas: 64 at 3720 9 at 3630 19.1 units Background Gas: ~ units Wiper Gas: 618 units @ 3607' Connection Gas: 97 units average 190 units max. Tdp Gas: units @ ;:!:!:!:i:i:!:i:!:i:i:i:i:i:i:i:i:!:!:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:!:i:i:i:!:i:!:i:!:i:i:i:i:i:i:i:i:i:i:!:!:!:i:i:i:!:i:i:i:i:i:i:!:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i: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: HYDROCARBON SHOWS: Trace show in sand at 3020' to 3060'; no visible pops in the mud; 5% dull yellow gold sample fluorescence; slowly streaming dull yellow cut fluorescence; no visible cuts in plain light. LITHOLOGY: ClaystoneJMudstone 41% Shale 37% Tuffaceous claystone 11% Silts'tone 5% Sandstone 3% Tuffaceous siltstone 2% Calcareous tuff 1% DAILY ACTIVITY SUMMARY: Drill from 2857' to 3607', lay down 9 joints of drill pipe; do wiper trip to shoe; drill ahead to report depth, ........................................................................................ DATE: FEBRUarY 22~ 4995 i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:icasing to Date: 16" at 108', 9 5/8" at 1860!:i:i:i:i:i:i:i:i.i:i:i:i:i:i:i:i:i:i:i:i:i: BIT INFORMATION: No. Size Type 2 8.50" HYCALOG SX70B2+6J Serial No. Jets Interval Footage Hours Condition 17660 6~10's 1860L In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth · 4642" 10.2 39 13 9 2/10 6.6 2 10.4 0 0.25 17.5 9 1100 60 DRILLING PARAMETERS: High Low Average Rate of Penetration 168.7 at 4295' 18.3 at 4298' 66.2 fi/hr Surface Torque 247 at 4298' 38 at 4230' 170 Ft-lbs Weight on Bit 18 at 4230' 2 at 4080' 8 Klbs Bit RPM 82 at 4549' 19 at 4230' 78 RPrvl Pump Pressure 2818 at 4712' 1821 at 4080' 2389 psi .SAS SUMMARY: High Low Average Total Ditch Gas Out: ~ 676.5 ~ at 4107' 27.7 at 4482' 83.4 units Methane (C..1) 81714 at 4107' 4927 at 4482' 11632 ppm Ethane (0,-2) 4507 at 4107' 140 at 4575' 491 ppm Propane (C-3) 5221 at 4107' 34 at 4575' 326 ppm Butane (C-4) 2993 at 4107' 13 at 4764' 213 ppm Pentane (0-5) 1562 at 4107' 0 at 79 ppm Total Cuttings Gas: 95 at 4110' 10 at 4610' 26.7 units Connection Gas: 50 units average 115 units max. Tdp Gas: units HYDROCARBON SHOWS: LITHOLOGY: ClaystoneJMudstone Shale Sand Siltstone Tuff/Bentonite Tuffaceous siitstone Pyrite fragments Trace to poor show in in zones from 3840' to 3860', 3930' to 3950', 3980' to 4010', 4060' to 4080', and 4280' to 4360'; poor to marginally fair show in sand zone at 4090' to 4150'; the latter show had 40% dull gold sample fluorescence, an initial moderately bright yellow flash cut, followed by a slow blooming medium bright yellow cut fluorescence, medium gold residual ring fluorescence and light gold brown residual color, and moderate visible porosity. 53% 24% 12% 6% 2% 2% 1% DALLY ACTIVITY SUMi~RY: Drill from 3800' to 4642'; circulate bottoms up; do 10 stand wiper trip; drill ahead from 4642' to report depth, BIT INFORIVIATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 2 8.50" HYCALOG SXTOB2+6J 17660 6-10% 1860'- In Hole MUD INFO: MW ViS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth: 5460' 10.3 40 15 9 2/14 6.5 2 11.4 0 0.25 20.0 9.1 1100 60 :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: D'RiLLING PARAMETERS: High Low Average Rate of Penetration 94.9 at 4769' 21.6 at 5337' 59.1 fi/hr Surface Torque 280 at 5145 115 at 5080' 225 R-lbs Weight on Bit 19 at 5338' 1 at 4801' 9 Klbs Bit RPM 82 at 5268' 41 at 5338' 79 RPM Pump Pressure 2823 at 4840' 1449 at 4801' 2543 psi !:!:::!:! :!:: :: :: :!:: :::: :: :: :::::: :: :: :: :::: :: ;: :: :: :::: :;:::::: :: :: :: :::: :: :: :: :::: :: :: ::;: :: :: ::::;::::: :: ::::::¥::: :: :: :; :: :: :;:: :: ;: :: :: :::: :: :::: :: :: :::: :: :: :: :: :: :: :: :::: :: :::::::: ::::;::::: :: :::: :::;:::: :;:: :: :::::::: :: :;:::::::::::::::: ::::¥i .: G: { E GN G:-:.:-h?:O:Gi.:6: G:ddd.: q .: GhX '.",,AS SUMMARY: High Low Average 'Total Ditch Gas Out: ~ at 4853' 20.1 at 5338' 42.8 units Methane (C-1) 9829 at 4768' 2712 at 5338' 6290 ppm Ethane (C-2) 326 at 5170' 41 at 4811' 188 ppm Propane (C-3) 74 at 5560' 12 at 5233' 37 ppm Butane (C-4) 20 at 4801' at 3 ppm Pentane (C-5) at at ppm Total Cuttings Gas: 20 at 5360' 3 at 5210' 10.2 units Background Gas: ~ units Wiper Gas: 215 units @ 5394' Connection Gas: 2 units average 8 units max. Tdp Gas: units @ HYDROCARBON SHOWS: None LITHOLOGY: ClaystonelMudstone 62% Shale 18% Siltstone 15% Sandstone 3% Tuff/Bentonite 2% Tuffaceous siltstone Tr Pyrite fragments Tr DAILY ACTIVITY SUI~i'vIARY: Drill from 4754' to 5394'; circulate bottoms up; do wiper trip to shoe; drill ahead from 5394' to report depth. ............................................................................................. · ~,ii~-~V -~.~ R~ ~~*~*~:~?~:~.~*~.~:~.~:~:~ ' . " ~ " DATE ................. :~:.:-:~:~:~:-:-:~:-:~:~:.:-:-:~:.:~:-:~:-:~:~:~:~:~:~:~:.:.:~:~:~:~:-:~:.:-:~:~:~:.:~:-:~:~:-:~:~:casing to Date, 16 at 108, 9 5/8 at 1860 , ........ ~ ..... i.~.:.....Z..-} ~.Z.~. X.X.?..Z.i,i..-Z.~'Z.:.Z.:....,~.~.Z....':.:.~.i.i.Z.~.~.:.Zq.~i ~(4:00AM) Yesterday: 5584' 24 Hour Progress: I 580' :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~~~.~~.~.~.~`~.~.~~.~.~1~.~.~~~ ~~;~:~::~:::::~:~:~:::~:~::~:~:~:~:~.~;.:~:.:~:~:~::~> MUD w'r: 40.2 l!i!ili!i!?:i!i!iiilFoRMATION: Claystone, Sandstone, Siltstone . .li!::!::ii!iiiiiii!i!i!i!l"K "NO GAS: 30u ~0NN'G.~s':'-tU ..... j!:i!i:i!!!!!i!iJi!lTRIP GAS: 325u ii!i!i!i!iJi!!!!!!!!iMAXIMUM GAS: 74.0u ii!i!i!i!i!i!i!i!i!!!!!iDC EXPONENT: 1.20 5:2' '" .... -.-.-...-.-.-.-.-.-.-..-.-.-.-;-..-.-.-;-...-.-..-.-.-.-.-..';'2-:-:'2':-:.:.:.:: .-.- .... :-.-..-.x-..-.-.~-.-.-. ...... - ...... -.- .... -.. 2.:.:.:-:.:-:.:.: .-.-...' ......... -..-. , .-.- ....................... ;.:.:.;,;.:,Z.Z.Z,:-;.:.Z-Z-:.Z.:-:-Y-:-:2:SJ BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 2 8.50" HYCALOG SXTOB2+6J 17660 6-10's 1860'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth' 6141" 10.2 40 14 8 2/5 6.5 2 10.5 0 Tr 20,0 8.8 900 60 DRILLING PARAMETERS: High Low Average Rate of Penetration 139.3 at 5934' 36.5 at 5707' 70.4 fi/hr Surface Torque 364 at 5934' 113 at 5830' 270 Ft-lbs Weight on Bit 20 at 5937' 5 at 5707' 11 KJbs Bit RPM 103 at 6024' 60 at 5937' 85 RPM Pump Pressure 3092 at 5941' 1629 at 6025' 6025 psi ,?~AS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 5971' 15.3 at 5773' 33.3 units Methane (O-1) 11923 at 5971' 2869 at 5773' 5082 ppm Ethane (C-2) 757 at 5971' 99 at 5710' 265 ppm Propane (0-3) 378 at 5971' 44 at 5586' 128 ppm Butane (0-4) 185 at 5900' 0 at 41 ppm Pentane (0-5) 6 at 6011' 0 at 0 ppm Total Cuttings Gas: 32 at 5960' 5 at 5810' 16.8 units Background Gas: ~ .......... ~'r~ii~ ....................................................... ~p~ ~a~i .................. u'nii~'"@ ....................... Connection Gas: 1 units average 5 units max. Trip Gas: 325 units @ 6141' HYDROCARBON SHOWS: Trace to poor show from 5900' to 6050'; 30% medium to dull yellow sample fluor; slow pale bluish white cut fluorescence; dull gold yellow residual dng fluorescence; dull brown residual dng; no free oil seen; generally poor porosity, LITHOLOGY: Claystone/Mudston~ 39% Sandstone 33% Siltstone 29% Tuff/Bentonite 1% Tuffaceous siltstone Tr DAILY ACTMTY SUMMARY: Drill from 5584' to 6141'; circulate bottoms up; POOH; change BHA; RIH with Bit #2 and new mudmotor; drill from 6141'to report depth. .......................................................... MORNING REPORT DATE: FEBRUARY 25. 1906 i:i:!:i:i:i:~:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:[:i:i:i:!:!:i:i:!:!:!:!:i:i:i:i:i:i:i:!:i:i:i:!casing to Date: 16" at 108', 9 5/8" at 1860 ..................... ,J . . , ~ DEPTH: 7088 1(4.00AM) Yesterday. 6164 24 Hour Progress: ~24.~:-:~:~:~:~:-:~:~:.:~:~:.:-:~:~:~:~:~:~:~:.:~:~:.:~:~:-:~:.:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:-:~: MUD WT: 10.3 lil}!iiii!i[ii!iiiilFORMnTION: Sha~e, Sandstone, Cla}/stone liii!iiiiiiii!iiiiiiiiilaKORND...................... OAS: .... ..................................................................................................................................................................... CONE GAS: la I~tTRIP OAS: 28Sa t[~[~[~I~IMUM OAS: ~26.0u I~~iOCEXPON~NT: ~.~3 .............. ., .. .... ..., .... ............. ,..,..,.,.,..,.,.,...,.,...,.,..._....... ....................................................................................................... BIT INFOR~TION: No. Size T~e Serial No. Jets I~e~l Footage Houm Cond~ion 2 8.50" ~CALOG SX70B2+6J 17660 ~10's 1860'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ D, epth · 8141" 10.3 42 14 8 2/5 6.2 2 12.0 0 Tr 20.0 9 900 40 DRILLING PARAMETERS: High Low Average Rate of Penetration 166.7 at 6148' 14.2 at 7062' 111.5 ff./hr Surface Torque 225 at 6393' 60 at 6288' 183 R-lbs Weight on Bit 12 at 7062' 1 at 6202' 6 Klbs Bit RPM 79 at 7090' 39 at 6288' 78 RPM Pump Pressure 3370 at 6161' 1706 at 6202' 2995 psi SAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 8407' 12.0 at 7088' 42.4 units Methane (C-1) 13258 at 6408' 1687 at 7050' 6252 ppm Ethane (C-2) 924 at 6969' 132 at 7050' 392 ppm Propane (0,-3) 887 at 6407' 80 at 6147' 263 ppm Butane (C-4) 721 at 6968' 33 at 6333' 121 ppm Pentane (C-5) 85 at 6464' 0 at 7022' 7 ppm Total Cuttings Gas: 150 at 6410' 2 at 6260' 46.9 units Background Gas: ~ units Wiper Gas: units @ Connection Gas: 1 units average 4 units max. Trip Gas: 285 units @ 7088' HYDROCARBON SHOWS: Trace to poor show from 6370' to 6620' and several other smaller zones; 10% medium to dull yellow sample fluorescence; slow pale yellowish white cut fluorescence; dull gold yellow residual ring fluorescence; dull brown residual ring; no free oil seen; mostly poor porosity, LITHOLOGY: Shale Claystone Sandstone Siltstone Tuff/Bentonite Tuffaceous siltstone 69% 15% 10% 5% 1% Tr DAILY ACTMTY SUMMARY: Drill from 6164' to 7088"; circulate bottoms up; POOH; change BHA; lay down mudmotor; RIH with Bit #2; ream to 7088'. .................................... ' ............... ~:~:~:::~:~:~:~:~~'.~:~~~~`~~ ....................... ' ' · · ............................ :..:.. -:.:.:.:.:.:.:*:.:.:.:.:.:.:.:.:.:. · . . ~ . 'l:.:.:.:.:.:*:*:-:*:-:*:*:.'.:.'*:*:*:.:-:': DATE. FEBRUARY 27, '!996 :.:~:~:~:~:~:.:.:~:.~~:~:.:.:~:`:.:~:~:~:~:..~:..~.~..:~:.:.:~:~~~:.:~..:~:~~~~~.~.~~~.~~~~~.~.~.~.~. Casing to Date. 16 at 108, 9 5/8 at 1::::::::::::::::::::::::::::::::::::::::::::::: = , . i , , DEPTH' 7259 (4 00AM) Yesterday 7259 24 Hour Progress I 0 J .......... . ..... ""'"'"' '""""'""'"'"'"'"'""-'-'-'"'"'"'"'-'I · I ' ' . . ' . . MUD WT: 10. Z i!ii!iiiiii::ilili::::lFORMATION: N~A lili!ili::i::iiiiiiiiiiiit" e"No GAS: "lSu BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hour's Condition 2 8.50" HYCALOG SX70B2+EJ 17660 6..10's 1860'-7259' 5399' 81.81 4-4~CT-A-X-1/16-ER-BHA 3 3.5X4.0" BHI ARC-412C3(cOREa[T) 1900308 1.00 TFA 7259'- In Hole MUD INFO: MW VIS FA/ YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth: 7259' 10.2 105 33 22 2/7 3.2 1 9.0 0 Tr 7.0 8.3 37000 120 DRILLING PARAMETERS: High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM at at ~ump Pressure psi .~AS SUMMARY: High Low Average Total Ditch Gas Out: I 1'!5.0 I at 11.0 at 18.0 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units i'b'""'"' Connection Gas: None units average units max. Trip Gas: units @ :~~~:.:~;~~~:~~~~~~~:~:~~~~~:~~~~~~~~~:~~.~~~~:~~.~~~~~~~~:~~~~.~~:.~~:.:~:~:~:~~.~.~~~.:.~.~~~~~~~~~.:~~~:~~.~~~.~~~~:.x~~.~~~~~~~~:~~~:~~.~~~~:~~.~~~~~~~~:~~~~~~~~~~~~.~~~~~.:~~~:.:~~~~~~~~.~.~.~.~~~.~~~~:~~.~~:~~~~~:.~.~~:.~~~~~~~.~.~~~~~.:.~~~.~~~.~.h;.;.;.~.:.:.;~~.;.;.h;~:~~.~~~.:.~G~~~q.~~:G>;~x.;~x.h ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~:~~~~~~.~~~~~~~~~~~~~~:~:~~~~~:~~~~~~~~~~~~.~~~~~~:.~~~~:.~~:~~~~~:~~~~.~.~~~.~.~.~~~~~~~~~~~~~~~~~~:~~~:~~~~~~~~~~~~~~~~~~~~~~~~~~~..~~.~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~:~~~~~~~~~~~~~~.h~.~~2;~~~~~~~~.~~xG~~~~~.~~~.2~~~~~.~~~~>~~~~~~~~~~~G~~ HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Circulate while pumping away the current bland mud to tanker trucks and cleaning the pits prior to receiving a new KCL mudsystem for coring; fill the pits with new mud; displace the old mud still in the hole; circulate and conditon the new mud; do 10 stand wiper trip; circulate bottoms up; continue to circulate and condition the KCL mud; ( concentration of K+ ion = 3400ppm); POOH; test BOPE; change BHA; pick up new core bit and core barrel and mud motor; ( note 16 drilling tools total in BHA below the HWDP and jars); RIH. -....,,.,.,...-.-.-...,,-,-.,.-.,.-,-.-,,. ~.~.~.~.~..~...~..~.~.~.~.~-~..~.~.~`~.~`.~`~.~.~.~..~.~..~.~.~..~.~..~...~.~.~.~.~.~.~.~..~.~.~..~.~.~.~.~.~.~ .,...,,..........,.,..-,,,..-......,,,-..,..,,,,,.....,....,-,-.,,,.,, .,,.......... DATE: FEBRUARY 28, t996 i:!:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:icasing to Date: 16" at 108', 9 5/8' at ::::::::::::::::::::::::::::::::::::::::::::::: ....................... MUD WT: 10.3 llii!iiiii!i!iiii}ilFORIVlATION: N/A ::::::::::::::::::::::::J:J:J:J:J:J:?:::::?.BKGRND GAS : llu CONN GAS: None [!i!iiii}!ii[iiiiilTmP GAS: 79u t}i!i}iii[ii!iiiiiiil x,MuM ms: 12.6u liiiiiiiiiiii!iiii![iiitDC EXPONENT: 1.22 ~:::~:~::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:::~:::::::;:::::::::::::::::::::::::::::::::::::::::::~::::::::::::~:::::::::::::::::::::~:;:::~:~:::::::::::::~:::::::::::::::::::::::~::::::~:::::::::::::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::~::~:::::::::::;::: ::: :: :: 2::::.::: ::: :: :: ::::: :::::::2 :::: .:.:-;, :. :' :. :-2. :, :. :.:.:. :-:. :-:. :. 7-;.:. 2. :-: .:. :': .:. :, :. :-:.:. :. ;. :. :, 2,:. :. :.: .:-: .:.:-:. :. :. :.:-:. :-:. :-:. :, :,: ,:, :.:-: .:-:.:.:. :. :. :-: .:. :. :.:-:.:-:-:. :. :.2. :. :. :. :' :':, :-:. :. :.:' :.:, :. :. :' :' :' :. 7. :. :. :. :. :' 2,2, F F H. F 2. F 2-2. F 2.2.2.2,2. F 2-2. F 2.2. F J-F 2. J-2, J. 2, F 2.7.2: 7:J-2.J: 7~ BIT INFORMATION: No. Size Type Serial No. 2RE 8.50" HYCALOG SX70B2+6J 17660 3 9.5x4.0' BHI ARC-412C3 (CORE 8~T) 1900308 Jets Interval Footage Hours Condition 6-1 O's 7267'- In Hole 1.00 TFA 7259'-7267' 8' 8.00 N/A MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth · 7267' 10.3 64 26 18 2/7 3.2 1 9.7 0 Tr 7.0 8.0 33700 112 DRILLING PARAMETERS: High Low Average Rate of Penetration CORJNG 8.2 at 7260' 0.75 at 7266' 2.8 fi/hr Surface Torque CORINC~ 94 at 7261' 86 at 7266' 89 Ft-lbs' Weight on Bit CORING 13 at 7267' 6 at 7260' 10 Klbs Bit RPM CORING 71 at 7267' 65 at 7262' 69 RPM Pump Pressure CORING 1463 at 7264' 1330 at 7266' 1373 psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 7260' 11.2 at 7263' 11.9 units Methane (C-1) 2028 at 7267' 1773 at 7263' 1908 ppm Ethane (C-2) 143 at 7260' 120 at 7260' 128 ppm Propane (C-3) 117 at 7260' 40 at 7266' 72 ppm Butane (C-4) 55 at 7260' 18 at 7266' 34 ppm Pentane (C-5) 2 at 7262' 1 at 7267' 1 ppm Total Cuttings Gas: 8 at 7267' 8 at 7267' 8.0 units Connection Gas: None units average units max. Tdp Gas: 79 units @ 7259' ::::!:i:i:!3!:i:i:!:!:!:i:!:i:!:i:!:!:!:!:!:!:!:!3!:!:}:!:}:i:!3!:!:!:!:i:!:!:!:}:!:!:!:!:!:!:!8!:!:i:i:!:!:!:i:!:!:!:!:i:!:!:!:!:i:!:!:!:!8!:!:i~i:i:!:i:!:!:!:!:i:i:!:!:!8i:!:!:!8i:!:!~!:!:!:i:!:!:i:i:!:~:!:i:i3!:i:i:!:!:i:i:i:i:!:!:!:!:i:!8i8?i:i:i:i:i8i8i3!:i:i3i8i:i:i:i3i3?i:i3i HYDROCARBON SHOWS: None DAILY ACTIVITY SUMMARY: RIH with coring assembly; encounter tight spot 18 stands out; work pipe and wash through; RIH; drop ball; fill 2 joints out; pick up kelly and wash and circulate hole rest of the way to bottom; drop ball; wash last 2 joints to bottom; core from 7259' to 7267'; barrel jammed; POOH; lay down inner core barrel; CORE NO. 1: cut 8', recovered 6.5'; note that the rest of the core barrel was packed with fill; stand back coring assembly and mudmotor; RIH with RRB #2 and drilling assembly; ream last 100' to bottom. ' dP;3ch'P'e~;;n'~ei 'on's~t;:' ' ' :4 ........ i!!i!i!i! i::!ii!!!!i! ii!!!i!::i::i?:ii]'AR~6'' ~U~F'R~is6'Ri' ha'ye' Bum~l;rner'' '[!ii!i!!ii!i!i!i!i!i!!!!!i!!!i!!!i!i!!iii!' 'R'eP;rt' 'bY'.' 'C'~ig' ' ~i~a ....... LITHOLOGY: Shale 70% Siltstone 15% Sandstone 15% ...................................................................................................................................................................... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::;:i:i:i:i:i:i:i:;:i:!:i:i:i:!:!:;3i:!:i:;:i:!:i:!:!:!:}:i:!:i:!:!:!:;:i:}:!:!:!:i:i:!:i:i:~:i:~:i:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::w:::::::W:::::::::::::::W:::::::W:::W::::::::::::::: DATE: FEBRUARY 29, 1996 i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:!:!:i:i:i:i:i:i:i:i:i:i:i:i Casing to Date: 16" at 108', 9 5/8" at 1860!!i!i!ii!ii!!!!!i!!!iiiiiii!i!i!i!iii!i!i!i! 6'EPTHi 727'6' i(,i. ioe'AMi ............ ~;'st'e~:aa~: ....... ~.2g~,; ............. ~24'H;u~:'P~-~'gr:e;'~: ............ ================================================================================================.g~ ================================================================================================= ,bo' '" ' ....................................................................... ;' """ .... · :-;.: .: .2-:':. :-:-;. :-:.:. :-:. :. :. :. :. :-2-:-:. :.:. :.:.:.:-:. :. :.:. :. :-: .:-:.:. :.:. :. :. :-:. :.:. :,:.:, :-:. :. :.:. :-:.: .: .:-:-; .:. :.:-:. :.:. :-:. :. ;.: .;.2. :. ;.2. :.:. ;, :. :. 2, :.;. ;. :. :. ;. :.2.:-:-:. :.2. :. 2. :. :. 7.:. :° :. :-;. :. 2. :. :' :. :-:. 2-:. ;. :-;. :-: .:. :-:. 2. :. :-2. J° 2,2,2.2. h J. 2,2. h 2.2. X°> 2,2. h :. 2.5.2,2.2.2.5-5.2,2.2,2.2. :.2 '2' 2. h 2, i CONN GAS: No.e-"'"""li!i!::!i!!!::!i!i!i!tTele ~AS: '.Ou ti!::::::::i::i::!ii!::ii!:.i~AAX~U~ ~^S: '~9~,., iii::i::::iliiii!::!iiii::iitOC EX,ON'=NT: '~.2S i:!:i:i:i:i:!:i:i:i:i:!:!:!:i:i:i:i:i:!:i:!:!:i:i:i:!:i:!:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:!:i:i:i:i:i:i:i:i:i:i:i:!:!:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i: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' '9~ ...... !i::iiiiilili!i!iii::i~O'P'(Si.;~i~> ':'' 9' ~.a.~- ............. [i::iiiii::i::{ili::ii h~P' isAN~i ':' '.i ~:' ~- ................ :~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~::i:i:i:i:i:i:i:i:i::~::~:::::::::~:.::::::::::::!::::::::::::::::::::::::::::::::::::::::::~::::::::::i:i:i:i:i:!:i:i:i.::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::..:::::::::::::::::>i:i:i~i:i:i?i:!:i:i:~:i:i:i:!:!:i:!:!:i: ::~:~:~-~:~:~:~:~:~:~:~:~:~.~.~.~.~..~.~.~.~...~.~...~.~.~...~...~.~.`~.~.~.~.~.~.~..~....~..~...~.~..~.~.~...~?.:.~:~:.:~.~:.~:~..~.~.~..~.~-,...:. '.;.:.X.i-J.:.h:-:.:-:O:-:.:.'OJ,:.'O:-:.:.:.:.:. BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 2RR 8.50' HYCALOG SX70B2+GJ 17660 6-10's 7267'-7276' 9' 0.88 4-4-CT-A-X-In-ER-BHA 3 B.5x4.0' 8HI ARC-412C3 (COF~E e~m) 1900308 1.00 TFA 7267'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth · 7276' 10.6 79 34 24 3/10 3 2 11.1 0 Tr 7.0 8.0 35500 140 ]!~!!!i!!!!!i!i!!!!!i:!!!!!!!!i!!!i!i!i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i~i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i: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:i3i:i:i:i:i:i:f:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i?i:i:i:i?i:i:i?i?i?i:i:i:i:i:i:i:i?i:i?i:i:i?i?i:ii DRILLING PARAMETERS: High Low Average Rate of Penetration 25.6 at 7275' 6.7 at 7269' 16.0 fi/hr Surface Torque 156 at 7275' 124 at 7271' 140 R-lbs Weight on Bit 7 at 7274' 5 at 7271' 6 Klbs Bit RPM 130 at 7276' 95 at 7272' 110 RPM Pump Pressure 1441 at 7273' 1388 at 7272' 1423 psi ,~AS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 7274' 31.0 at 7268' 120.4 units Methane (C--1) 21946 at 7274' 3930 at 7268' 14333 ppm Ethane (C-2) 2437 at 7274' 507 at 7268' 1609 ppm Propane (C-3) 3042 at 7274' 510 at 7268' 1738 ppm Butane (C-4) 1234 at 7274' 236 at 7268' 684 ppm Pentane (C-5) 353 at 7274' 13 at 7268' 144 ppm Total Cuttings Gas: 300 at 7276' 9 at 7268' 8.0 units Connection Gas: None units average units max. Trip Gas: 110 units @ 7267' HYDROCARBON SHOWS: Fair show at 7270' to 7276'; very fine to silt size quartz arenite sandstone with 5% glauconite; spotty to pervasive moderately bright yellowish white sample fluorescence in the unwashed mud; note abundant gas bubbles popping from freshly collected mud; moderate to strong petroleum odor; when small amount of water is added there are abundant pops and blebs; 90-100% oil sheen on blendor sample water; 50% medium bright whitish yellow natural sample fluorescence; bright blooming yelish white cut fluorescence; mostly good porosity; poor permiabi!ity. LITHOLOGY: Sandstone 80% Shale 15% Claystone 5% DAILY ACTIVITY SUMMARY: RIH with RRB #2 and drilling assembly; ream last 100' to bottom; drill from 7267' to 7271'; circulate bottoms up; continue to circulate while making decision on whether to drill farther before coring; ddll from 7271' to 7276'; circulate bottoms up; continue to circulate and clean hole; note abundant large shale cuttings returning over shakers; pump high viscosity sweep around to clean hole; do 25 stand wiper trip; circulate bottoms up and continue to circulate and clean hole; pump high viscosity sweep to clean hole; POOH; change BHA; pick up rerun core bit, core barrel; RIH; circulate hole every 20 stands; RIH to 60' above point; circulate to bottom. 'A'R'C'0"A'i"A'S'KA"'i'Nc." ~::~::::~::::~::~::~::::~::::~::::~::~::~::~::~::~::~::~::~::::~::~::::~::~::~::~::~::::~::::~::~::~::~::~::~::~::~::~::~ N Ii! v Ii! # 1 DATE: MARCH '1, '1996 !iiiiiiii!i!iiiii!i!iiiiiiiiiiii![iii!!ii!iii!!iiiiiiiiii!ii!iiiii!iiiiii!ii![iiiiiiiii!ii!iiiiii!iii Casing to Date: 16" at 108', 9 5/8" at , . , . , ~~~~~~`:~~~:~~~~~:~~~:~~.~.~~:~~~~~:~~~:~~~:~:~:~:~:~~~:~~~~~:.~~~~:~~~:~:~~~~~:~:~~~:~:~:~:~ DEPTH: 7336 i(4:00AM) Yesterday. 7276 24 Hour Progress. 6L~-~.~~.~.~.~:~:~:~:~:~:.:.:.:.:.:.:.:.:.:.:.:.:.:.: :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 3! ::::::::::::::::::::::: !:!:i:!:i:!:!:i:i:i:i :! :!:!3 !:! :i:i:i :i:i :!:!:i:i:i:! :!:i:i:i:i: i:i:i :! :i:i :i :i :i:i :i:i :i :!:i :i :! :i:i:i :i:i:i :i:! :i:i:i:i ::?iiiiiiii ....................................................... iii::i::iiiiiiii!ii i::iiii,' 0" ......... C0,N"e .s': No,. ' I::iii::::iii!i!i!iiiilTR , tili::i::iii!i::i::::i!i lMAxIMUM GAS: 444u I!!::::ii!ii!::iiiiii::ili!pCExpO"E,*: 0,88 :::;:::;:;:::::;:::::::.:.:;:;:.:.:::;:;:;:; '.::::;:::;:.:;:; '.; '.:',:'.; '.: '.;:; :;:;:; '.: '.?:;:::::::::::::;:;:::::::::: '.?::::'.;:;:.:;:;:;:;:.:.:.:::;:;:::,:.'..:.:.:. '.. '..:.:.:.:.:.:.:. ',.:.:. '..:. :.:. '..:,:.:.:.:.:.:.:. '.. '.,:,:.:.:. '..:. '..:. ',.:.:,:.:.:.:.:,:.:.:. '.. BIT INFORMATION: No. Size Type Sedal No. Jets Interval Footage Hours Condition 3 iit.5x4.0' BHI ARC-41203 (coRe B~T) 1900308 1.00 TFA 7276'-7336' 60' 3.013 In Hole MUD INFO: MW VIS PV YP GELS FL. FO SOL OIL SD MBT pH Cl Ca+ Depth · 7336' 10.5 73 28 17 2/8 4.0 2 10.6 0 Tr 7.0 9.5 27,000 100 DRILLING PARAMETERS: High Low Average Rate of Penetration 33.5 at 7296' 6.9 at 7278' 22.0 ft/hr Surface Torque 166 at 7302' 104 at 7336' 149 R-lbs Weight on Bit 6 at 7277' 1 at 7307' 3 Klbs Bit RPM 120 at 7335' 58 at 7278' 95 RPM Pump Pressure 1030 at 7278' 919 at '7286' 965 psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 7291' 53.3 at 7336' 223.5 units Methane (C-1) 37498 at 7296' 7570 at 7336' 24640 ppm Ethane (C-2) 4095 at 7296' 913 at 7277' 2789 ppm Propane (C.-3) 5650 at 7291' 979 at 7336' 3639 ppm Butane (C-4) 2719 at 7291' 417 at 7277' 1664 ppm Pentane (C-5) 1077 at 7291' 65 at 7336' 583 ppm Total Cuttings Gas: 290 at 7280' 189 at 7320' 214.3 units Background Gas: ~ units Wiper Gas: units @ Connection Gas: None units average units max. Tdp Gas: 190 units @ 7276' HYDROCARBON SHOWS: LITHOLOGY: Sandstone Very good to moderately good show through the core interval; pervasive oil staining; ranges from very fine to spotty fine upper sandstone; strong petroleum odor; porosity is dominantly good; permiability ranges from moderately good to poor; oil is pervasive in unwashed mud; abundant gas and oil pops; 80-100% bright yellowish white natural fluorescence; the best cuts are very pale straw color with very light brown residual dng; the best air dry cuttings fluorescence is bright instant bluish yellowish white with good blooming, and bdght yellow residual. 100% Cut 60' Core Recovered 60' Core DAILY ACTIVITY SUMMARY: RIH with Core Bit #3; RIH to 60' above core point; circulate and ream last 60' to bottom; drop ball; core from 7276' to 7336'; circulate bottoms up; POOH; lay down core; RIH with coring assembly for another core run; RIH to 60' above core point; circulate and ream to 7' above core point; lose circulation at this point; lose estimated 50 barrels in 6 minutes; no returns to surface; pick up and monitor mud system; POOH 3 stands and monitor while making up LCM pill; POOH another 7 stands; monitor mud loss while building mud in dewatering unit pump latter mud to active system; build and pump two pills(160bbls); after last pill stop pumping and monitor well. ' E~p~'(~' P'e~;~'~;i ;;"';';t;;.' ' ' '4 ........ !iii!i!!!!iii!!!ii!i!iii!!!iiiiiii!iii]'A'R~O'' ~U'PE'R~is~)~:' Da'ye' Bumgar~e'r''' !i!!!ii!!!!!iii!i!i!iii!!i!:!:!:!:!:!iii!. 'R'eP~ff' 'bY'.' 'C'r~ig' ' ~ii& ....... :~:.:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:`:~:~:~:~:~:~:~:~:~:.:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~: :~:~:~:~:~:~:~:~:.:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~: DATE: MARCH 2, t996 i:!:!:!:i:i:i:!:i:!:!:i:!:i:!:i:i:!:i:i:i:i:!:!:i:i:i:!:i:i:i:i:i:iii:!:i:!:!:i:i:!:!:i:i:i:i:!:i:i:! Casing to Date: 16' at 108', 9 5/8' .a.t..1.860!:!i!i!ii ::::::::::::::::::::: ::::: ::::::::::::::: ::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .uo'""",,.: ............................................................................................................... ,o., .,. ii; iiii ; i ;ili ........ :i:i:i:i:i:!:i:i:i:i:i:i:!:i:!:i:!:!:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:!:i:i:i:!:i:i:!:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:!:!:!:i:i:i:!:!:i:!:!:i:~:i:i:i:!:i:i:i:1:i:i:i:i:i:i:!:i:!:!:i:!:i:i:i:i:i:i:!:i:i:i:i:!:i:i:!:!:!:i:i:i:i:!:i:i:i:!:!:!:i:i:i:i:i:i:i:!:!:!:!: co,, GAs: ,~A .... Iiii::!i!::ili!::::ii::::lTeIe GAS: ,~A iiii!i!!::!!!!iiiiiiil~x~,~UM........., aRS: SS~u I~¢~ff~::~¢~::~::~::~fOC EXPO,~,T: Est PORE PRESSURE: 9.5 l~::~::}~tROP.($.mE}: ~A [~::::~::::::~~IA ~:~:~:~:~;~:~:~:~:~:~:~:~:~:~:~:~::::::::::::::::::::::::::::~::::::::::~::::::::::::::::::::~:::::::~:::::::::~:~::::~::::::::::::~:~:::::::::::::::::::::::::::::::::::::::::::::::~:::::::~:::::~:~:~:~:::::::~::::::::~::::::::::::::::::::::::::::::::::::~:::::::::~::::::::::::::~::::::::::::::::::::::::::::::::~::::::::::::: BIT INFOR~TION: No. She T~e Serial No. Jets I~e~l Footage Hours CondEion 4 8.5' ~C ATJP05 C08XK 3-13's 7336'- In Hole ~.~~~~:~~~:~:~~~~~~~~~~~~~~~~.~~:~~~~~~~~~~~~~~~~~~~:~:~~~~~~~~~:~~~:~:~:~~~~~~~~~~~~~~~~~:.~.~.~~~~~~~~~~~~~~~~~~~~~~:~~~~~~~~~~~:~~~~~~~~~~~~~~~~~~~~~~~~~~~:~~~~~~~~~~~~~~~~~~~~~~~~~:~~~~~~~~~~.~~:~~~~~~~~~~~~.~~~~~~~.~.~.~~~~~~~~~.~~~~~.~~~~~~~~~~~~~~:~~~~~~~:`~~~~:.~~~~~~~~ ~:~~~~.~.~~~~~~~~~~~~:~~~~~~~~~~~:~:~~~~~~~~~~~~~~~~~~~~~~.~~~.~~~~:~~~~~~~~~~~~~~~~~~~~~~~:~~~:~~~~~~.:~~~:~~~:~:~~~~~~~~~~~~~~~~~~~~.~~~~~~:~~.~~~~~~~~~~~~:':~~~~~~~~~~~~~:~~~~~~~~~~~~~~~:~~~:~~~~~:~~~~~~~~~:~~~~~~~~~~~~.~.~.~~:~:~;.:~~~~.~~:~~~~~:.:~~~~~~.:.~.~~~~~~:~~~~~~.:~ MUD INFO: MW VIS ~ YP GELS FL FO SOL OIL SD MBT pH Cl Ca+ Depth ' 7336' 10.5 73 24 15 ~ 3.4 2 10.5 0 Tr 9.0 8,2 28,000 112 DRILLING P~ETERS: High Low Average Rate of Penetration at at Su~ace Torque at at Ft-lbs ~eig~ on BE at at ~bs BR RPM at at RPM Pump Pressure at at psi ,3AS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 15.0 at 28.0 units Methane (C-1) at at ppm Ethane (0-2) at at ppm Propane (0-3) at at ppm Butane (0.4) at at ppm Pentane (0.5) at at ppm Total Cuttings Gas: at at units Connection Gas: None units average units max. Tdp Gas: units HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Monitor well 10 stands off bottom alter losing circulation; pull 8 more stands, slow circulate and observe mud volume losses; pull 8 more stands and do same; pull up to shoe and break circulation and monitor; continue to POOH; while building new mud bring mud weight down to 10.5ppg; lay down coring tools; make up new BHA; RIH with NB fl4 (insert bit) and drilling assembly; stop at 2978' and circulate out; receive 356 units of gas from zone at 2350' to 2850'; (cuttings sample was taken to verify that it was this zone); continue to RIH, stopping to break circulation every 10-15 stands. 07 ~~/~h~.h~h~h~ DEPTH: 7336' 1(4:00AM) Yesterday: 7336' 24 Hour Progress: ~~~~============================================================================================= MUD WT: 10.5 fiiiiiiiiiiiliiiiiilFORIVIATION: N/A I!i!iiiiiii!iiiiii!!i!!]BKGRND...................... GAS: 15u CONN GAS: N/A I!iiii!!ii!i!i!i!i!lTR~P GAS: N/A }i!i!ili!i!!ii!i!!!ilMAX~MUM GAS: ~58u_............____________ii!i!i!i!i!i!i!i!i!i!i!iDCEXPONENT.._N/A BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 4 8.5' HTC ATJP05 C08XK 3.13's 7336'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth: 7.336' . 10.5 68 24 19 3/7 3.2 2 10.6 0 Tr 10.0 8.0 26,000 140 DRILLING PARAMETERS: High Low Average Rate of Penetration at at ~t/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM Pump Pressure at at psi , A~,S SUMMARY: High Low Average Total Ditch Gas Out: ~ at 15.0 at 26.0 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units :Background Gas: ~ units Wiper Gas: units Connection Gas: None units average units max. Trip Gas: units HYDROCARBON SHOWS: N/A LITHOLOGY: N/A !DAILY ACTIVITY SUMMARY: Continue to RIH, stopping to break circulation every 10-15 stands; circulate and wash to 7236'; ream to 7255'; lose mud; circulate and stabilize mud loss; POOH to 6750'; wash to 6790'; POOH to 6283'; lay down 5 stands; start washing and reaming back down; note frequent packing off a~er 7120'; pump repeated high viscosity sweeps to clean hole while reaming in; ream to 7286' at report time. NOTE that the ratios of the heavy gases indicates that most of the gas is coming from uphole (probably from the C-30 at 2350'-2650'). !:!:i:i:i:i:!:i:i:i:i:i:i:!:i:i:!:i:i:!:i:!:i:!:i:i:!:!:!:!:i:i:i 8 !8 i:i:i:!:!:}:!:!:i:!:!:!:!:!:!:!:i:!:i:!:i:i:!8 i:!:!:!:!:!: i:!:i:!:i:!:!:!:!:!:i:!:i:i:!:i:i:!: i:!:!8 !:!:i:!:!:i:!:i:i:i:!:i:i:!:!:!:!:!:!:i:!:!:!:!:i:!:!:!:!:!:!:!:i:!:i:!:!:i:!:!:}:!: !:!:i:!:i:i:!:i:i:! 8 !8 i:i:!:!:!:!:!:i:!:i:i:i: MUD ~: ~0.6 Cl~stone, Siltstone, ShMe, S~dstone No eAS: ~4u CONN GAS: None I?~;~?~?~;::?~;~;~ITmP GAS: None i~::~::~[~~ GAs:"137U'-~ ~ ,~I::~::~::::~FD~'~X~ONENT: 1.~ :~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:::~:~:~:~:~:~:::~:::::::::~:~:~:~:~:~:~:~:~:::::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::~:~:~:~:~:~:~:~:~:~:::::::::::::::::::::::::::~:~:~:~:~.:::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 811 4 8.50' ~C ~TO~05 C08XK ~3'~ 7335'- In Hole MUD INFO: MW ViS ~ YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth' 7530' 10.6 60 21 21 4/12 3.8 2 10.6 0 0.25 10.0 8.0 27,000 140 DRILLING P~ETERS: High Low Average Rate of Penetration 25.9 at 7358' 4.3 at 7338' 12.8 Su~ce Torque 157 at 7478' 101 at 7339' 1 ~ Ft-lbs Weig~ on B~ 30 at 7453' 2 at 7337' 25 B~ RPM 126 at 7481' 65 at 7351' 115 RPM Pu~ Pressure 2635 at 7403' 1826 at 74g0' 2328 psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 7378' 14.1 at 7419' 32.6 units Methane (C-1) 14819 at 7378' 1651 at 7419' 4134 ppm Ethane (0,-2) 1947 at 7378' 133 at 7556' 424 ppm Propane (C-3) 2141 at 7378' 86 at 7556' 403 ppm Butane (C-4) 962 at 7378' 23 at 7538' 178 ppm Pentane (C-5) 234 at 7377' 3 at 7556' 21 ppm Total Cuttings Gas: 250 at 7370' 12 at 7550' 42.1 units ....... ' ....................... .................. ......................... Connection Gas: None units average units max. Trip Gas: units @ HYDROCARBON SHOWS: :LITHOLOGY: Ciaystone Siltstone Shale Sandstone Tuffaceous claystone Continuation of show interval that was cored; good to strong fair show; pervasive light brown oil staining; very fine upper to fine lower sandstone; good petroleum odor; porosity is good to poor; permiability ranges from fair to very poor; oil is penrasive in unwashed mud; visible oil pops; 50-90% moderately bright whitish yellow to yellow natural fluorescence;the best cuts are very pale straw color with very light brown residual ring;the best air dried cuttings fluorescence is bright instant yellowish white with good blooming, and bright yellow residual ring. 32% 25% 24% 18% 1% DAILY ACTIVITY SUMMARY: Ream from 7286' to 7336'; tag bottom; circulate bottoms up; pump and circulate around a high viscosity pill; work on mud pump #2; drill from 7336' to report depth. :~:;:~:::::~:~:~:..:::::::~:::::::::..:~:..:::..:::::::::::::~:::~:~:~:~:~:~:::..:::~:::~:..:::::::::..:~:::~:~:~:~:~:~:~:::::~:~:::~:~:..:~:..:::..:::::::::::::~:::::::~:~:~:~:~:~:..:~:..:::::::::::~:..:~:~:~:..:::~:::~:::~:::::::::::::~:~:~:..:~:..:~:~::: ::~:~:~:~:..:~:::..:::..:::::~:..¥..:..:~:~:::::::~:::~:~:..:~:::~:~:..:~:~:::;¥..:..:::..:~: :::: !.:.:.:.:~:.:~:~:.:.:.:.:.:.:.:~:.:~:.:.:.:~:.:.:.:.:.~:.:~:.:~:~:.:.:.:.:.:~:.~.:~:~:~:.:~:.:~:.:~:.:.~.:.:.:.:.:.:.:.:.:~:.:.:.:.:.:~:.:.:.:.:.:.~.:~.:.:~.:.:~:~:.:~:.:.~.:~:.:~:.:.:.:.:~:~:~:~:~:.:.:.:.:.:.:.:.:~:.:.:.:.:.:.:.:.:.:.:~:.:.:.:.:.:.:.:.:.:.:.:~:.:.:.:.:.~.:~:.:.:.:.:~.:~:.:.:.:.:.:.:~:~.:~:~:.?:~:.:~:.:~: :i:i:!:!:i:!:i:i:!:i:!:!:!:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:!:i:!:!:!:i:!:i:i:i:i:i:i:i:!:i:i:!:!:i:i:!:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:!:i:i:i:i:!:i:i:!:i:i:i:!:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:!:i:i:!:!:i:i:i:!:!:i:i:!:!:!:i:!:i:!:i:i:i:i:i:i:i:i:!:i:i:i:!:i:!:!:i:!:i:i:i:!:i:i:!:i:i:i:i:i:i:i:i:i:!:i:i:i:!:!:!:i:i:i:!:i MUD WT: 40.5 liiiiiiiiiil-iiiiiiil~oRMAT,3N:. C~ay~to.e. ShOe, si,etone li:.ii!:.ii!i!iii!iiiiiii~lBl<GRND...................... GAS: 8u :!:!:!:!:i:!:!:i:!:!:!:!:!:!:!:!:!:i:!:!:!:!:!:!:i:!:!:!:!:!:!:!:!:!:!:i:!:!:!:!:!:i:!:!:!:i:i:i:!:i:!:!:i:!:!:!:i:i:i:!:!:!:!:!:!:!:!:!:i:!:i:!:!:i:i:!:!:!:!:!:i:i:!:!:!:!:!:!:i:!:i:!:!:!:i:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:i:!:!:i:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:i:i:i:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:i:!:!:!:!:!: GA~: None [?!!i!!!!?iTRIP............... C~S: 40u I::i::ii?:i::?:?:i!.?:iii~X"~UM US: ~Tu I!~!~!~!~!~!~!i~i!~!~!~IDC.................... EXPONENT: 1.70 :.::.::.::.::.::.::.::.::.::.:i::.::.::.::.::.::.::.:i::.::.::.:i::.::.::.:i::.::.::.::.::.::.::.::.::.::.::.::.::.::.::.::.:i:i::.::.::.:i::.:i::.:i:i::.::.:i:i::.:i::.::.::.::.::.::.::.::.:i::.::.::.::.:~::.::.::.:~:i:~::.::.:i:i::.::.::.::.::.::.::.::.::.::.::.::.::.::.::.::.::.::.:i::.::.::.::.:i::.:i::.::.::.::.::.::.::~:i::.::.::.::.::.::.::.::.::.::.::.::.::.::.:i::.::.:i:i::.::.::.::.::.::~::.::~::.::~::.:i::.::.::.::.::.::.::.::.::.::.::.::.::.:.::i:i::.::~: /. .:.:. .:. i.i.mi.: ..... : ......... BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 4 8_50' HTC ATJP05 C08XK 3-13's 7336~7700' 364' 32.554 in Hole ....................................................................................................................................................................... :.,-.:. :..-..'..'..-..-. :. :..'.;.:..'..-.... ;. :. :..',:..'..'..-..'. :. :. :.:.:.:.:..'..'.:.:.:. :.:. :. :..'.:..'. ;..'. ;. :..'. :,:.:.:,:,:. ;.:..'..'.:..-. :. :..-.....-. :..-..'..-. ;. :. ;..-.:..-..'. ;. :.:..'..'.:. :.,'.:. :.:. :. :.;..'. :..'. :..'. :..'.:. :. :. :. :. :. :. :. :..'..-. :.:. :..-.:..-. :. :.:..-. :..-. :. :.:..-. :. :..'. :. :. :..-. :. :..'. :. :. :.:.:.:. :. :. :. :. :. :..'. :. :. ;-:. :. ,'. ;, .'. :. :. :.:-;. :-:-:..'.:.: MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth' 7700' 10.5 60 24 24 4/14 4.0 I 10.7 0 0.25 12.5 8.0 24,000 200 ....................................................................................................................................................................... ': ::.':.':::::::::.';:::::~.'::: :: :::::;:::~::::::::::::::::::::::.'::~:;.'::::;:;:~:::::::::: ::::.': ::::::.'~:::::::~ :;:; :: :::::::::::: :.::.':.':.':.':::.':::,':::::.':.':.'::; :: :; :: :: ::::.': :::::::::: ::.':::::::.':.'::: :: :::: :: :;:::: :::::::::::::::: ::.'::: ::.'::: :::::::: :'. :: :: :: ::.'::: :::::: :: :::: .': ::::.'::::::: :'. :: .':::.': :::::: ::::.':.'::::: :: ;: :: :::: .':::::: DRILLING PARAMETERS: High Low Average Ea!e of Penetration 14.1 at 7656' 5.2 at 7631' g.g ftJhr Surface Torque 161 at 7667' 109 at 7632' 155 Ft-lbs Weight on Bit 31 at 7638' 23 at 7570' 30 KJbs Bit RPM t26 at 7663' t08 at 7570' t20 RPM p....~....P.r?.? ............................ ~3.7. .... a..~ .... 7..5.7.0'. ............................ 20~e. ..... a! .... 7.~..~'. ............................. .~.~.~..~ .... p.~! ....... ,GAS $iJMMARY: High Low Average Total Ditch Gas Out: ~ at 7595' 7.8 al: 7685' 11.5 units !Methane (C-1) 2603 at 7595' 1229 at 7685' t836 ppm :Ethane (C-2) 167 at 762T 73 at 7683' 118 ppm Propane (C-3) 111 at 7595' 44 at 7638' 80 ppm Butane (C-4) ~ at 7566' 4 at 7638' 16 ppm Perttarte (C-5) 4 at 7b"04' 0 at I ppm To~al Cuitir~s Ga~: 10 at 7700' 5 at 7670' 8.1 units Background Gas: [ ~4 [ units WrperGas: 40 ur~ts @ 7700' Cc,~'~ection Gas: None units average un/ts max. Trip Gas: units @ HYDROCARBON SHOWS: None :LITHOL~Y: Silts[one Sandstone Calcareous tuff Tuffaceous ctaystor~ Tuff/bentoPJle 39% 18% 4% 4% 2% 2% DAILY ACTMTY SUMMARY: Drill from 7560' to 763t'; circulate bottoms up;. do 5 stand wiper trip; drill from 763t' to 7700' (T.D.); circulate bottoms up and a half; pum~p high viscosity pill and do arkother one and a half circulations; do 7 stand wiper trip; circutate bottoms up; pump h/gh ~iscosity pili arid circulate up; POOH. :i! i i ! ii! i !i:: :: ::!iii::i i ! iiii!i! ::i!~~~~i~~:i~~!!i!!i~~~ii!i!i!ii!~i~~~!i~~:~!~i~!~ii~i!i!iii~i~iii~~~!i~~~:~~~i!i!~ii!!i~tl M O R N IN G R E P O R T 'liiiii i::i iii i ::::i::i i ili i!ii!!i::i::::i?:iiiii::i!i!ili!i!?:ii?:i::::::i::::::i::ili::iii::ii?:ili ..... :::::::::::::::::::::::::::::::::::: ..... ........ BIT INFOR~TION: No. S~e T~e Serial No. Jets Inte~l Footage Hours Condition 4 8.5~ HTO ATJP05 O08XK 3-13's 7336'-7700' 364' 32.554 2-2-NO-A-E-ImN~TD MUD INFO: MW VIS PV YP GELS FL FO SOL OIL SD MBT pH Cl Ca+ Depth: 7700' 10.6 65 24 25 4112 4.2 1 11.2 0 0.25 12.5 8.0 25,000 240 DRILLING P~ETERS: High Low Average Rate of Penetration at at ~r Su~ce Torque at at R-lbs Weight on B~ at at ~bs B~ RPM at at RPM Pump Pressure at at psi 3AS SUMMARY: High Low Average Total Ditch Gas Out: ~ at 8.0 at 24.0 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units ........ : ....... : .... ~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ .- ......... : .................................. : .... :. + ,.........-.'.-.-.'...'...'...'.'.'...'.'.-.'.'.-.'.'.'.'.'.'.'.'.,.,.,.'.,.,.,.,.,.,.'..:.:+:..: ............ : .................................. : .... : ............ :. · ... ----~-------~-------------°---~---°-----.-----------~---~---.-~-----~---°-------~-----------°-------- Background Gas: ~ units Wiper Gas: units @ Connection Gas: None units average units max. Trip Gas: 56 units @ 7700' HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: POOH; rig up Schlumberger; run in with wireline tools; unable to get tools past 2380'; pull tools out of hole; rig down Schlumberger; RIH with drilling assembly to clean hole; break circulation at the shoe; work through tight spot at 2830'-2900'; continue RIH; work through tight spot at 4300'; continue to RIH to 7670'; break circulation and start circulating out; start losing mud above 80spm pump rate; increase pump rate to 120spm and lose 50 bbls in 6 minutes; lower pump rate to reduce mud loss; pump LCM pill; circulate around; bring pump rate up slowly when hole is stabilized; net mud Ioss=100 bbls; circulate and condition; POOH; pull ti~lht at 2780'. '~p~)'(~l~'P'~;~m'r;;i'~r~';E;;: .... ~ ........ !!!ii!ii!!::i::i!i!i!iiiiiiiiiiiii!i!il ~~'R~"'-'?i!!!i!ii!i::iiiiiiiii::iiiii!!!!!iiii!i!i"R';l~;~''b~/':' 'C'r~i~' Silva'" :-:.:-:-:.:.:.:.:.:*:. :.:.:.:.:.:.:.:.:.:.:.:.:-:.:.:.:.:.:.:.:,:.:.:.:-:.:.:.:-:-:.:. :-:.:.:.:.:.:.:.::!:i:!:!:!:!:!:i:!:i:!:i:!:!:!:i:!:!:!:!:!:!:!:!:! 8!:! 3!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:?!:!:!:!:!:i:!:!:!:!:!:! :!:!:!:!:!:!:!:!:!:!:!:!:!:::!:!:!:!:!:!:!:!:!:i:i:!:!:i:i:!:!:!:!::-:.:.:. :.:. :.:-:. :.:.:.:.:.:.:.:. :. :-:. :, :-:. DATE: MARCH ?, 1996 iiiiiii{iiiiiiiiii!i!iii!iii!iiiiiii!ii!iiiiii!iiiiiii!i!i!ii!!i!!!iiiii!ii!!}!iii!iiiii!!ii!i!i!ii!! Casing to Date: 16" at 108', 9 5/8" at EXP~ ' ~::~~~;;:;:::~~~~~~~~~~::~~~::~:~::~~~~~~~~:~~~~:~~~~~~~~~~~:~~~~~~~~~:~:~:.:~~~~~:~~~~~~~~~~.~~~~~~~~~~:~:~:~~~~~~'~~~~~.~~~~~~~.:.:~~~:~~~:~:~~~~~~~~~~~~~~~:~~.~~~~~~~~:.~~:~:~~~~~~~~~~~~~~.~~:~~~~~:~:~:~~~:~:~:~~~:~~~~~:~:~:~~.~~:.~~:.:~:.~~ BIT INFORMATION: No. She T~e Serial No. Jets Inte~al Footage Hours Cond~ion 4RR 8.5" ~C ATJP05 C08XK 3-13's Ream 7000'- In Hole ?~:i:~:~:~:~:~:~:~:?~:~:~:~:~:~:E:?~:~:~:~:~:~:E:~:~:i:E:~:~:~:~:E:~:~:?~:~:i:~:~:E:~:~:~:~:~:~:~:E:E:~:~:~:E:~:?~:~:E:?~:E:~:~:~:i:~:~:i:~:E:~:E:E:~:E:~:~:~:~:~:E:~:~:~:~:~:~:E:~:~:;:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:?~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:;:~:~:~:~:~:?~:~:~:: MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth' 7700' 10.7 70 25 22 3/12 4.2 1 11.6 0 0.25 12.5 8.0 27,000 200 :DRILLING P~ETERS: High Low Average Rate of Penetration at at ~hr Sudace Torque at at Ft-lbs Weig~ on B~ at at B~ RPM at at RPM Pump Pressure at at psi -~.~~~~~:~~~:~~.~~:~~~~~~~~~:~~~:~~~:~:~:~~.~~:~:~:~:~~~~~~~~~~~:~~~~~~.:~:~:~:~:~~~:~~~~~~~~~~~~~~~~~~~~~:~:':~:~:~:~:~~~~~:~:~~~~~:~:~:~~~:~:~~~:~~~~~~~:~:~:~:~~~:~:~~~~~~~:~:~~~:~~~~.~~~~:~~~~~~~~~~~:~~~:~~~~~:~:~:~:~~~:~:~~~~.~~~~:~~~~~~~:~:~~~:~:~:.:~:~:~:~~~~~~.:~~~~~:~~.:~:~~~:~~~:.~~~.~~~.~~:~:~:~:~~~~~:~:.:~~~~.:~~~:~:.~~~~: GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ from 2350'-2850' 12.0 at 23.0 units Methane (C-1) at at ppm Ethane (C--2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Background Gas: ~ units Wiper Gas: units @ Connection Gas: None units average units max. Tdp Gas: 125 units @ 7000' HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: POOH; rig up Schlumberger; run in with wireline tools; unable to get tools past 2854'; pull tools out of hole; dg down Schlumberger; pick up RRB #-4, drilling assembly, and Anaddll LWD triple combo tool; RIH; break circulation at the shoe; work through tight spot at 2750'-2950'; continue to RIH to 6950'; circulate bottoms up; pump pill and circulate out; ream to 6980'; very tight going to 7000'; lay down a joint and ream and clean hole back to 7000'; control ream on MAD run from 7000' to 7186' at report time. DATE: MARCH 8, 1996 5:!:5:!:i:i:!:J:J:!:5:J:5?5:J:J:!:5:!:!:i:J:5:!:!:5:J:J:5:!:!:J:i:5~!:5~5:5:!:J:i:5:!:i:5:!:i:i:~:i Casing to Date: 16" at 108', 9 5/8' at :j:j:!:!:!:!:!:j:j:!:j:!:j:!:!:!:j:j:j:i:i:!:!:i:!:!:!:!:!:!:j:j:!:!:!:i:!:!:!:!:j:!:j:!:j:!:!:!:j:!:j:j:j:i:!:!:!:!:~:j:!:!:!:!:!:!:j:j:!:!:j:j:j:!:!:j:!:!:!:!:!:!:i:j:i:!:!:!:!:j:!:j:!:!:!:!:j:!:i:!:!:j:j:j:!:!:!:!:j:i:i ~i~i .......... ~7~:~ii~.i~.~i~i~.~.......~..........~.~;;.;~.;;~;;~;;.~....~.~..~.~.;~.~.~.~.~...~..~....~....~..~.~;;.~.;.~;;~.~;;;;;~.~..~.~....~~ ~ ~: ~o.e t::~::~::~::~I~T~ON: ~A I~%~%~taKORND...................... OAS: C~ ~': ~A i::?:?:~?:?:?:~TR~ ~: ~u i~?:~::::~?:::~?:1~UM °A~.=..~U .......... [?:~?:?::?:~::::~OC~XP~N~.:..~A BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition 4RR 8.5" HTC ATJP05 C08XK 3-13's Ream 7120'- In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Ci Ca+ Depth: 7700' 10.9 65 25 21 3/10 4.0 1 12.6 0 0.25 12.5 7.8 26,000 360 DRILLING PARAMETERS: High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM =ump Pressure at at psi SAS SUMMARY: High Low Average Total Ditch Gas Out: ~ from Trip Gas 8.0 at 17.0 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (0_,-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Background Gas: I 8 J units WiperGas: units @ Connection Gas: None units average units max. Tdp Gas: 50 units @ 7120' HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Control ream on MAD run from 7186' to 7218'; hole is very tight reaming to 7218'; pulling as much as 100K lbs over normal hookload several times while picldng up; pick up and circulate bottoms up; pump dry job; POOH; pull tight at 5910'; remove radioactive source and lay down Anaddll LWD tool; test BOP's; RIH with RRB ~4 and rotary ddlling assembly to clean up the hole; break circulation at shoe and at 4000'; continue RIH to 7120'; pick up kelly and break circulation; ream from 7120' to 7599' at report time. Note raising mud weight to 11.0ppg. Epoch Personnel on site: 3 !i!i!i!iiiii!i!i!i!i!i!i!ii!i!i!ii!iiiARCOSUPERvIsOR:DoUgStoltz ii!!iii!!!ii!iiiiiiiii!!!i!!!iii!i!iii!ii Report by: Craig Silva :, ~D ~: 11,0 I~IFOR~T~: ~A I~~IBKGRND GAS: 7u ;:~:.:.~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:.~:~:~:~:.:~:~:~.:::~::~:~:~:~.~:~.~.:~:.::~:~:~:.~.~.:~:~22~:~.~:~:~:~::~:~:::~:~:::~.~:.~:~:~:::::::~:::~:~.~:~::::~:::::::::::~:::::~:~:~:::::~:¥:::::::::::::::::::::::::::::::::::¥::~:::: BIT INFORMATION: No. She T~e Serial No. Jets Inte~l Footage Hours Cond~ion 4RR 8.5" ~C ATJP05 C08XK 3-13's Reaming N/A N/A In Hole MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH Cl Ca+ Depth: 7700' 11.0 82 28 25 4/14 4.2 1 13.1 0 0.25 15.0 7.8 27,000 320 DRILLING PA~ETERS: High Low Avenge Rate of Penet~tion at at ff~r Su~ace Torque at at R-lbs Weig~ on B~ at at BA RPM at at RPM Pump Pressure at at psi -~A$ SUMi~AARY: High Low Average Total Ditch Gas Out: 32L~_J.o from Wiper Tdp Gas 7.0 at 17.0 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (0,;-3) at at ppm Butane (0,-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units :Background Gas: ~ units Wiper Gas: 32 units @ 7700' Connection Gas: None units average units max. Trip Gas: units @ HYDROCARBON SHOWS: N/'A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Ream to 7700'; circulate bottoms up; do 10 stand wiper trip; pulling tight during trip; circulate bottoms up; pump pill and circulate around; pump second pill and circulate around; circulate till hole is reasonably clean; POOH to shoe; run back in; break circulation at the shoe and at 4400'; run in with only very minor resistance till 7350'; pick up kelly and ream and wash to 7700'; circulate bottoms; continue circulating to clean hole pdor to special pill for casing run; experience major electrical problem, all power and control is lost at ddlleds console; down for 1 hr 20 minutes without drawworks, pumps and rotary; regain power; continue circulat!ng. :~:~:~:~:~:~:~:~:.:~:.:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:.:~:~:.:.:~:~:~:~:~:~:~:~:~:~:~:~:~:~: DATE: ,MARCH t0, 1996 !:!:!:!:i:i:!:i:!:!:!:!:!:!:!:!:!:!:i:!:!:!:!:!:!:!:!:i:!:!:!:!:!:!:!:!:i:!:!:i:!:!:!:!:!:!:!:!:!:i:! Casing to Date: 16" at 108', 9 5/8" at :~:~~.:.~~:~:~:.:.~~:~~.:.:~~~:~~.~.:~:.:~~.:.~.:.~~:.:~~~:.:.:.~.:.:.~.:.:.~.~.~.~.:.~~:.:~:~~.~.:.:~:.:.:.:.~.~.:~~~~~~~~~~.~.~~~.:.~~:.~.~.~~~.:.:~~~:.:~~.:~:~~~:~~~:.:~~~:.~~~~:~:~~~~.:~:.~~:~~.~.~.:.:~:.~.:~:.~.:.:~~.:.:.:.~.~~~.~.:.~.~.~.:.~.:.:~~.:~hFh:E.:.h:~F F co.. i:i:i:!:!:i:!:E :!:i:!:!:!:!:!:!:E:!:!:;:!:!:i:!:i:i:!:i:i:!:i:!:i:!:!:!:!:!:!:!:i:;:!:i:i:i:!:!:;:!:!:i:!:!:!:!:!:!:!:i:!:!:!:!:!:!:!8!:!:!:!:!:!:!:!:!:!:!8 !:!:!:!:!:!:!8 !:!:;:!3 !:!:!8 !:;:;:!:;:!:!:!: ;:;:;:!:i:!:!:!:!:!:!:i:;:;:!:i:i:!:!:;:!:!:!:;:!8 ;:!:!:;:!:!:i: BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition i;;i:i:i:i;i~!:i:i:i:i:i:i:i:::::::::::::::::::::::::::::;:i:!:i:i:i:i:i:i:i:;:!:;:i:i:i:i:i:i:i:!:!:i:!:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:;:i:i:i3i: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:!:E:i:~:i:i:i:i:i:i:;:i:;:~:i:i:;:;:i:i:i:~:;:i:i:i:i:i:;:i:;:;:;:;:i:i:i:i:;:i:!:i:~:~:i:i:i:i:!:i:i:i:i:i:i:!:i:: MUD INFO: MW VIS PV YP GELS FL FO SOL OIL SD M BT pH Cl Ca+ Depth · 7700' 11.0 76 24 20 :3/10 4.6 1 12.5 0 0.25 15.0 8.0 27,000 480 DRILLING PARAMETERS: High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM Pump Pressure at at psi ,3AS SUMMARY: High Low Average Total Ditch Gas Out: ~ from Circulating last pill 6.0 at 13.0 units Methane (C-1) at at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm 'Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Background Gas: L__LJ units Wiper Gas: units @ Connection Gas: None units average units max. Trip Gas: units @ HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Continue circulating after regaining power to the ddllers console; pump 100 bbl pill of special mud for casing run; pump dB/job; POOH; rig up to run casing; run 7" casing; land shoe at 7678'; rig up circulating head and break circulation; start with 30spm pump rate; increase to 60spm rate and start losing mud (apparently packing off uphole); lower pump rate until no longer losing mud to the hole; mud is no longer lost at rate of 12spin (1 bbl/min); circulate at slow rate 'while waiting for brine truck to arrive; displace mud in suction lines with brine; blow clean rig lines with air; pressure test lines; pump brine spacer, Arco preflush, and cement; displace with brine. GAS: gu CONN GAS: N/A Iii::i::i::i::ili!ii!i!l?mP GAS: N/A ::::::::::::::::::::::::::::::::::: GAS: tau l!iiii::::ilili::iii::i::ilitDCEXPONENT: N/A ~~.:~~~~~:~:~:~~~:~~.:~:~~~~~:~:~:~:~:~:~:~~~:~:~~~:~:~:~~~~~~~:~~~:~:~~~:~:~:~:~:~:~:~:~~.~~:~:~:~:~~~:~:~:~:~:~:~:~~~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~~.:~:~:~~~~~:~:~:~:~:~:~:~:~:~~~:~~~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~~~:~:~:~~~:~:~:~:~:~:~~.:~:~:~:~h: E':':':':::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth · 7700' 10.6 N/A 1 0 0 0.0 0 0.0 0 0 0.0 0.0 0 0 DRILLING PARAMETERS: High Low Average Rate of Penetration at at ft/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM Pump Pressure at at psi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ from Last mud returns 9.0 at 11.0 units Methane (C-1) at before cementing, at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Background Gas: L__LJ units Wiper Gas: units @ Connection Gas: None units average units max, Tdp Gas: units @ HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Do cement job for 7" casing: pump 20 bbl water spacer, 50 bbl Arco preflush, drop bottom plug, pump 85 bbl class G cement slurry, drop top plug, displace with 10.6ppg brine; bump plug; pressure up to 1500psi, hold for 5 minutes, and then pressure off. Note that there were no returns to the surface during the entire procedure. Rig down Dowell; break off lines to stack; pickup stack; set slips; lay down stub and bell nipple; cut 7" casing; install packoff; make up tubing spool; install wellhead; test to 3000psi; nipple up stack, reconnect all lines and test to 3000psi; pump deisel down 9 5/8"x20" annulus for freeze protection; lay down BHA and 5" ddll pipe. Epoch Personnel on site: 3 !iii!!!i!i!i!i!i!iii!i!i!i?ii!i!!!i. iiiiiiiiiii!i!!i!!!!i!iii!i!iii!i!ii!iiii Report by: Craig Silva ::!i!!iiii iii ii:ii iiii:iii:i!iii:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:it M O R N I N G R E P O R T !!! ? ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: BIT INFORMATION: No, Size Type Sedal No. Jets Interval Footage Hours Condition MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth: 7700' 10.6 N/A 1 0 0 0.0 0 0.0 0 0 0.0 0.0 0 0 DRILLING PARAMETERS: High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM Pump Pressure at at psi .,AS SUMMARY: High Low Average Total Ditch Gas Out: ~ from No mud returns at units Methane (C-1) at in last 24 hours, at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Background Gas: ~ units Wiper Gas: units @ Connection Gas: None units average units max. Trip Gas: units @ HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Lay down 5" drill pipe; rig up Schlumberger; RIH with gauge ring and junk basket; tag up at 7565'; POOH; pick upwire tools CET-CBT-CNL-GR and RIH; tag at 7585'; log; POOH; lay down logging tools; rig down Schlumberger; waiting on Schlumberger lubricator; test casing to 4500psi; rig up Schlumberger; pick up Schlumberger lubricator and test to 500psi; pick up Schlumberger perforation guns and RIH on wireline; fire guns at depth of 7222'-7220'; POOH; wait and watch to ensure that the well is stable; pick up cement retainer and RIH on wireline; set retainer; POOH; rig down Schlumberger; prepare for squeeze job. ·:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.: .............................................. :i!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:!:i:i:i:i:i: M O R N I N G R E P O R T ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: A R C O A L A $ K A ! N C. :::::::::::?:?::::::::::::?::::::::::::?:::::::::::::::::?::::?::::?:::::::?:::?:?::::::?::::?:?:?:?:?:::?:?:?:::::?:::?:::?:::::::::::::?:?:?:?:::?:?:?::::?:?:::?:::?::::::::?::::::::::::?:::::::?::::?:?::::::::::: N E ¥ E # 1 ............. · _ ;,....,~,.~.;. :. ;, '._.:' ,¥..;~.~ ......... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..... . ........................... , .......... ;~ ......... , ..................... DATE: ,,~, ,,w,[-jj,~, ! ~, ,~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Casing to Date: 18 at 108, 9 5/8 at 1880 DEPTN; ?'150' li4:00AM) "~,e;St~r:~l&~;: ...... '~i~0; .............~4'H~U~.'P~-~'g~e~'s: ......... CON , "::::::::::::::::::::::::::::::: , ;: :: .':.': ;:.': .': :: :: .': .': .': .': .': .': .': .': :: ;: ;: ;: ;::: .': :: ;: ;: .': .': .': ;::: .': :: .': .': :: :: .': :: :: ;: .': ,': .': ;: .¥: .':;~ :: .': ::;: :: .': :: .': .': .': :::: .': ;: :: :: .': :: .': .':;:;: :: ::;: ;: .': :: .':.': ;: :: ;: ;: .': .': ;: ;: .': :: :: ;:.': ;: ;: .':.':.': .': :: :: ;: .': ;: ;: ;: .': ;: .': ;: .': ;: ~: ;: .': .': ;: :: ;: .': .':;:;:;:.':.': .':.¥: .': .': .': .': .':.': :: :: ;:.': ::;: :: ;: .¥: ;;:: .¥ :.': ;:;:.': ;: ,': .':;:;: .': .': ;: .... ..................................................................................................................................................................... BIT INFORMATION: No. Size Type Serial No. Jets Intenral Footage Hours Condition MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth' 7150' 10.6 N/A 1 0 0 0.0 0 0.0 0 0 0.0 0.0 0 0 :.: DRILLING PARAMETERS: High Low Average Rate of Penetration at at fi/hr Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM Pump Pressure at at psi · ~AS SUMMARY: High Low Average Total Ditch Gas Out: ~ from While circulating 0.0 at 6.0 units Methane (C-1) at aEer tagging packer, at ppm Ethane (C-2) at at ppm Propane (C-3) at at ppm Butane (C-4) at at ppm Pentane (C-5) at at ppm Total Cuttings Gas: at at units Background Gas: ~ units Wiper Gas: units @ Connection Gas: None units average units max. Trip Gas: units @ HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTMTY SUMMARY: Set retainer at 7150'; POOH; dg down Schlumberger; pressure test casing and retainer; pick up stinger and 3 1/2" ddll pipe; RIH with stinger and stab into packer at 7156'; do cement squeeze job; POOH 5 stands to 6672'; reverse circulate; displace 46 bbls; POOH; lay down stinger; pick up 6 1/8" bit and junk basket; RIH; lay down 19 joints of ddll pipe; run in to 6635'; pick up kelly and wash in; tag top of packer; pull up off of packer and circulate. i ~iiiiiiiiiiii;iii;iiiiiii!i!iiii!iiii;iiiii;ii!;.iii!ii;~!iii~i?~i~i~~~~~~~~~i.~~i~.~i!?:;;ii.-..~;ii~-.iii ii! ii ;ii~!i -'"""""""""""""""""""' ................................... DATE: MARCH 14, 1996 i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i Casing to Date: 16" at 108', 9 5/8" at 1860', 7" at 767.8!:i:i:i:i:!:i:i: i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:!:i:!:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:!:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i~i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:!:i:!:!:i:i:i:!:i:i:i:i:i:i:i:i:i:!:i:i:i:!:i:i:!:!:i:!:i:!:i:i:i:i:i:!:!:!:!:i:i:!:!:!:!:!:i:!:!:i:i:i ,.,......,.-.-,.,- BIT INFORMATION: No. Size Type Serial No. Jets Interval Footage Hours Condition MUD INFO: MW VIS PV YP GELS FL FC SOL OIL SD MBT pH CI Ca+ Depth' 7576' 10.6 N/A 1 0 0 0.0 0 0.0 0 0 0.0 0.0 0 0 DRILLING PARAiVIETERS: High Low Average Rate of Penetration at at ft/hr :Surface Torque at at Ft-lbs Weight on Bit at at Klbs Bit RPM at at RPM ,~-~. Pump Pressure at at pSi GAS SUMMARY: High Low Average Total Ditch Gas Out: ~ from While circulating after 5.0 at 8.0 units Methane (0-1) at drilling out retainer, at ppm Ethane (0-2) at at ppm Propane (0-3) at at ppm Butane (0-4) at at ppm Pentane (0-5) at at ppm 'otal Cuttings Gas: at at units ia~i~'i;,hi:i 'O~;i' ' ~ .......... i~,~; ....................................................... ~¢~; ~h~i .................. i~',ii;' ' '@ ......................... Connection Gas: None units average units max. Trip Gas: units @ HYDROCARBON SHOWS: N/A LITHOLOGY: N/A DAILY ACTIVITY SUMMARY: Wash to 7153'; tag top of retainer; circulate out; ddll out the retainer; drill cement to its base at 7231'; wash down to 7270'; circulate bottoms up; RIH to 7572'; tag up; circulate around a hig viscosity pill; pull up 4 stands to 7165'; test 7" casing thru the choke to 500psi for 10 minutes; POOH; lay down junk basket; pick up 7" casing scraper; RIH to 7576'; circulate bottoms up; circulate around a high viscosity pill; POOH laying down 3 1/2" ddll pipe. DRiLLiNG TiME SCHEDULE DEPTH {THOUS~'DS} 0 ~2 ~4 ~6 ~8 ~10 0 2 4 2~14~96 to 3-04~98 6 8 10 12 14 16 18 20 22 24 26 28 30 DAY S EPOCH WELL LOGGING iNC ARCO 1,200 I ,000 80O 600 400 2O0 0 0 5 10 15 20 25 30 35 EPOCH ~¢ELL LOGGING C~her Acti~4~Jes ]1% Cut and Slip Drill Line BOP Testir~glRig-Up 7% C~.singtOementing 4% Work on Rig O% Cir~,~late 14% Trip/BHA 28% ARCO ALASKA, Drill / Core 3O% B Drill / Core Iii Trip/BHA D Circulete [] ReAm [] Work on Rig [] CAsing/Cementing BI BOP Testing/Rig-Up [] Cut And Slip Drill Line [] Other Activities ARCO Alaska, Inc. AtlanticRichfieldCompany TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: April 18, 1996 Transmitted herwith is the followinq data: --- SQUEEZE PERF & CEMENT RETAINER RECORD - 12-MAR-96 - TEMPERATURE LOG - TEMP / PRESS ! GR ! CCL - MARCH 28, 1996 DIGITAL DATA: Neve 1 ~ 6" Open Reel Tape -LDWG Format-"Open Hole Edit" CDR CDN DSI with paper listing copy ~1/3.5 Floppy-Ascii Format-Directional Data ( Meas Depth, Devi, Hazi) REPORTS: ~'Alpine 3 BASIC ROCK PROPERTIES - FINAL REPORT containing I 3.5 floppy disk with 97076.XLS files If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: ~-\PP, "~ 9 1996 ~p_,p~oved for transmittal by: Manager, N o ~hF'AIMa~kHa ~lo~tn TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 ,/, DATE: April 18, 1996 ARCO Alaska, Inc. · AtlanticRichficldCompany FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Transmitted herwith is the following data: Enclosed is the following data: LOGS: I Sepia Copy Displayed by EPOCH: Bergschrund 2A Formation Log 1" = 50' (2000' to 7896') I Blueline Copy Displayed by EPOCH: Bergschrund 2A Formation Log 1" = 50' (2000' to 7896') I Sepia Copy Displayed by Schlumberger: Neve I 't~p,I,.p, IL1 · .i"~l'-~Li,., iai llll I CEMENT BOND LOG - CEMENT EVALUATION -" COMPENSATED NEUTRON LOG (EPITHERMAL & THERMAL) RUNS 1 & 2 -- PACKAGE SETTING RECORD (BAKER FB -1/TCP ASSEMBLY)- 14-MAR-1996 - SQUEEZE PERF & CEMENT RETAINER RECORD - 12-MAR-96 "TEMPERATURE LOG - TEMP ! PRESS ! GR / CCL - MARCH 28, 1996 I Blueline Copy Displayed by Schlumberger: Neve I CEMENT EVALUATION COMPENSATED NEUTRON LOG (EPITHERMAL & THERMAL) RUNS I & 2 PACKAGE SETTING RECORD (BAKER FB -1/TCP ASSEMBLY)- 14-MAR-1996 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 11, 1996 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 (907) 276-7542 (fax) Re: Sundry Notice to Plug and Abandon ARCO Neve #1 Permit No. 95-215 Dear Commissioner Johnston, The ARCO Neve #1 well has been drilled, completed, and tested as planned, and now plans are being made to plug and abandon the well. ARCO Alaska, Inc. hereby applies for sundry approval to plug and abandon the ARCO Neve #1, permit number 95-215. A detailed plug and abandonment procedure and wellbore schematic are enclosed. ARCO requests a variance to the requirements of 20 AAC 25.105 PLUGGING, SUSPENSION, AND ABANDONMENT OF WELLS. As indicated on the attached schematic, the current PBTD in the Neve #1 well is 7408' which is only 32 feet below the bottom test perforation. This PBTD is a result of fill above TCP perforating guns which were dropped into the well's rathole during completion operations. 20 AAC 25.105 (h) (1) (A) requires 100 feet of cement to be placed below the bottom perf in perforated intervals for P&A~--~oses. ARCO ~proval to .pi c~J~~e_et o~f~c~e~g__t~.e~lgw the bottom_perf which Will still provide the necessary degre~'~of isolation required. ARCO also requests a variance to the requirements of 20 AAC 25.120 Well Abandonment Marker. Rather than place an above ground marker over the wellbore, ARCO proposes to weld a cover plate to the casing stub 3' below ground level with the information required in 20 AAC 25.120 (b) bead welded to the top. The location will then be backfilled with ~avel. If you have questions or require additional information, please contact Tom McKay at 265-6890 in our Anchorage office. Sincerely, Tom McKay ~.J Senior Drilling Engineer KRU Drillsite Development ~??, ~ ~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension Stimulate Perforate Other Pull tubing _ Variance _ _ 2. Name of Operator ARCO Alaska, In(;;, 3. Address Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2440' FWL, 465' FNL, Sec. 14, T12N, R4E, UM At top of productive interval 6. Datum elevation (DF or KB) RKB 35' Above SL 7. Unit or Property name N/A 8. Well number Neve #1 9. Permit number feet Same At effective depth At total depth Same Total Depth: Present well condition summary measured true vertical Effective depth: measured true vertical 0p, G/NAL 7700' feet 95-215 10. APl number 50-1 03-20231 11. Field/Pool Wildcat 12. 7700' feet feet feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 1 80 6' 9 - 5 / 8" Intermediate Production 765 2' 7" Liner Perforation depth: measured: see under true vertical Cemented Measured ~.~t Tru AyltttlliCal~ p 300SxAS I 120' 325 Sx AS III & 1841' 575 Sx AS I 405 sx Class G Latex 76 7 9' 120' 1841' 7679' true vertical' J-4 Sand Test Perfs, 7268-7376'; 7" Casing Squeeze Perfs, 7220-7222' Tubing (size, grade, and measured depth: 3-1/2" 9.3# L80 EUE 8rd Mod, to surface with tail at 7265' Packers and SSSV (type and measured depth): Baker FB-1 @ 7240' and Baker FHL @ 7145' 13. Attachments P&A Wellbore Description summary of proposal Detailed operation program BOP sketch 14. Estimated date for commencing operation April 14, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Drill Site Development Supervisor FOR COMMISSION USE ONLY Conditions of approval' Notify Commission so representative may witness Plug integrity ~. BOP Test m Location clearance __~ Mechanical Integrity Test Subseauent form require - ,jrig na. rb gnea David W. ,Johnston Approved by the order of the Commission Form 10-403 Rev 06/15/88 JApproval 1~9.. ,. . roved Cor y I / (, .... o- Commissioner Date SUBMIT IN'YRIPLI'CATE NEVE #1 PLUG AND ABANDONMENT PROCEDURE Notify AOGCC 24 hrs. prior to beginning any P&A activity (907) 279-1433 Procedure: . . , . o , Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. AOGCC has option to observe all plug setting operations. AOGCC Field Inspector Contact Numbers: Pager: 659-3607 Truck: 659-3870 Office: 279-1433 Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. , Rig up slickline unit. RIH and set blanking plug in XN profile at 7092'. Pull up hole, and latch Petredat gauge in gas lift mandrel (GLM) at 7046'. Pull Petredat guage from GLM and POOH. RIH with dummy valve and seat same in GLM. Pressure test tubing to 1500 psi for 10 minutes to ensure dummy valve is properly seated. RIH with slickline and pull blanking plug set in XN profile. POOH. After pulling blanking plug, tag plugback depth with slickline and correlate back to RKB depths. Current top of fill or PBTD is 7408'. Use Tubing End Locator (TEL) on slickline to assist in correlation. POOH with slickline. NOTE: Top of TCP guns previously dropped is 7458'. Bottom perf is at 7376' (see attached schematic). Therefore, there is 50 feet of fill above perf guns left in hole. AOGCC regulations require 100 feet of cement below bottom perf; thus, ARCO has asked AOGCC for a waiver on this requirement to eliminate the need to clean out fill in well down to top of perf guns. Mobilize and rig up Coiled Tubing Unit (CTU) for well P&A operation. Nipple up CTU to 3-1/2" Otis union above swab valve. handle returns from well. Nipple up CTU "Quad" BOP Stack with: Rig up CTU as required to a. Two (2) sets of blind / shear rams b. One (1) set of pipe rams c. One (1) set of slip rams Rig up stripper above BOP Stack. Rig up to take returns from annulus as required with choke and route into horizontal tiger tank. o , 10. 11. 12. 13. 14. 15. 16. Pressure test all surface equipment and lines to 300 psi Iow and 4000 psi high. Be sure to use diesel or other non-freezing fluid for pressure testing. RIH with coiled tubing with 2" or 2.25" cementing / jetting nozzle with no check valve. Circulate diesel at minimum rate while RIH to keep system from freezing at surface. Circulate seawater on choke at high rate. Clean out well 'to current PBTD at 7408' (top of fill), correlating off plugback depth tag. Flag coil at PBTD. Circulate and condition for spotting of cement P&A plug across perforations. Rig up cementing unit and batch mix cement plug #1, and pump down coiled tubing in well from PBTD and upward to cover perforations. Spot plug #1 in stages as required. Cover all perfs with cement, bringing cement up in to tubing tail (Note that there is only 3 feet between top perf and tubing tail, so exact cement placement using CTU will be difficult). Hesitate squeeze cement into perfs as required. Circulate any residual cement (using biozan)in tubing across XN nipple at 7092' out of well. WOC. "Dry" tag top of cement plug to verify placement after WOC (AOGCC has option to witness tag). Displace tubing to 10.6 ppg kill weight brine. POOH with coiled tubing. Pressure test cement plug across perfs to 1500 psi for 10 minutes, record and report results. Release CTU. Rig up slickline unit and run in hole. Set blanking plug in 'XN' nipple above upper packer and below gas lift mandrel (GLM). Pull up hole with slickline. Pull dummy valve from GLM above blanking plug to allow annular circulation. POOH with slickline. Rig up cementing unit and break circulation pumping kill weight brine through GLM and take returns of kill weight brine on 3-1/2" x 7" annulus. Batch mix and pump cement plug #2 and lay in 200 foot long balanced cement plug across GLM and above packer. This plug will isolate tubing and tubing/casing annulus immediately above the upper packer. Displace cement plug #2 with kill weight brine. WOC. After WOC, pressure test annulus to 1500 psi for 10 minutes to confirm cement plug integrity. Record and report results. Rig up e-line unit on well. RIH and tag up on top of cement plug #2 to verify placement (AOGCC has option to witness tag). POOH with e-line. Rig up tubing perf guns and RIH to 250'. Perforate tubing with circulation holes at 250'. POOH with e-line. Rig up cementing unit and break circulation pumping kill weight brine through perfs and take returns of kill weight brine on 3-1/2" x 7" annulus. Batch mix and pump cement plug #3 (surface plug) and lay in 250 foot long balanced cement plug to surface in tubing and tubing/casing annulus. WOO. ~ ~. E ~ 1\*i~ ~- ~ 17. 18. 19. 20. 21. 22. Rig up cementing unit on 7" x 9-5/8" annulus. Pressure test lines to 3000 psi. Pump into 7"x 9-5/8" annulus using kill weight brine. Establish injection rate into 7" annulus. Monitor wellhead gauges. Batch mix and pump Arcticset cement plug #4 into 7" annulus to fill up from 9-5/8" shoe at 1841' to surface. Do not exceed 2000 psi injection pressure while placing cement. Pump lead and tail Arcticset slurries to minimize hydrostatic pressure of cement column at 9-5/8" surface casing shoe; pump tail slurry last into well during downsqueeze operation. -- Clear lines and shut down pumps. Break off cementing unit and clean up. Shut in 7" annulus. Monitor and secure well. WOC. After WOC, pressure test 7" x 9- 5/8" annulus to 1500 psi for 15 minutes. Record and report results of test. Rig up and cutoff wellhead and all casing strings at or below 3 feet below ground level. Fill all annuli and the tubing to surface with cement. Remove cellar. Back fill cellar with gravel as needed. Send casing head with stub to Materials for repair / re-dressing. Weld cover plate over all casing strings with the following information bead welded into the top' ARCO ALASKA, INC NEVE #1 ADL 380075 APl# 50-103-20231 2440' FWL, 465' FNL, S14-T12N-R4E,UM Note: ARCO has requested the AOGCC waive the requirement for an above ground P&A marker per 20 AAC 25. 120. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all material and equipment for season. Prepared by' Approved by' Senior Drilling EngiCeer KRU DS Development Supervisor PROPOSED NEVE #1 P&A SCHEMATIC - FINAL CONFIDENTIAL KILL WEIGHT BRINE BETWEEN ALL PLUGS AND IN 3-1/2" X 7" ANNULUS, 10.6 ppg P&A CEMENT FILL 9-5/8" CSA 1841' RKB CEMENTED TO SURFACE 3-1/2" 9.3# L80 EUE 8RD MOD TBG 11.0 ppg MUD IN 7" X OPEN HOLE ANNULUS GAS LIFT MANDREL @ 7046' BLANKING PLUG IN XN NIPPLE @ 7092' ! UPPER PACKER @ 7145' -- ~-'---":/ ~ -"~ SQUEEZE PERES @ 7220' (SQUEEZED 3/12/96) LOWER PACKER @ 7240' TUBING TAIL @ 7265' J-4 SAND TEST PERFS 7268-7376' TOP OF FILL @ 7408', CURRENT PBTD EXPENDED TCP PERF GUNS @ 7458' ORIGINAL PBTD = 7576' 7" CSA 7679' RKB TWM, 4/11/96 ARCO Alaska, Inc. AtlanticRichfieldCompany TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: March 27, 1996 Transmitted herwith is the followinq data: Enclosed is the following data: LOGS: I Sepia Copy Displayed by EPOCH: %--00~ Alpine 3 Formation Log 2"= 100' (108' to 7649') 0)'5~7, t~ Bergschrund 2 Formation Log 2" = 100' (107' to 8600') q~. ~?'~ Nanuk 1 Formation Log 2" = 100' (110' to 7630') q)-._~'-Neve 1 Formation Log 2" = 100' (108' to 7700') Blueline Copy Displayed by EPOCH: Alpine 3 Formation Log Bergschrund 2 Formation Log Nanuk 1 Formation Log Neve 1 Formation Log 2"= 100' (108' to 7649') 2" = 100' (107' to 8600') 2" = 100' (110' to 7630') 2"= 100' (108' to 7700') Sepia Copy Displayed by Schlumberger: Berg~schrund 2 ~-CDN FINAL PRINT L/T~RUE VERTICAL DEPTH CDN FINAL PRINT ~DR FINAL PRINT ~--'I~RUE VERTICAL DEPTH CDR FINAL PRINT ~DIPOLE SONIC IMAGER - P & S AND UPPER DIPOLE - 21-FEBRUARY-1996 ' (.~RUE VERTICAL DEPTH DIPOLE SONIC FINAL PRINT t~AR 2 9 ~996' Alaska 0il & Gas Cons. Commission Anch0rage ARCO Alaska, Inc. AtlanticRichfieldCompany TO: AOGCC Attn.: Mr. Robert P Crandall 3001 Porcupine Dr Anchorage Alaska 99501 FROM: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 DATE: March 27, 1996 Transmitted herwith is the followinq data: I Blueline Copy Displayed by Schlumberger: qC-~.[~ Bergschrund 2 --CDN FINAL PRINT ~"~RUE VERTICAL DEPTH CDN FINAL PRINT ,--~0DR FINAL PRINT ¢'I'RUE VERTICAL DEPTH CDR FINAL PRINT "I~IPOLE SONIC IMAGER - P & S AND UPPER DIPOLE - 21-FEBRUARY-1996 ~-I'RUE VERTICAL DEPTH DIPOLE SONIC FINAL PRINT DIGITAL DATA: ~-~t ~ Bergschrund 2 ~ 6" Open Reel Tape-LDWG Format-"Open Hole Edit" CDR CDN DSl wwjth paper listing copy .5 Floppy-Ascii Format-Directional Data ( Meas Depth, Devi, Hazi) If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Keili A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Received by: DATE: RECEIVED MAR 2 9 Ap~ro~ved for transmittal by: ' - - "F.M~.P~neycutt Manager, North AI~ Exploration TO' DATE: ARCO Alaska, Inc. AtlanticRichfi¢ldCompany Alaska Oil & Gas Consveration Commission Attn.: Blair Wondzell 3001 Porcupine Dr. Anchorage Alaska 99501 FROM: March 21, 1996 Ms. Kelli A. Thibodeau ATO-1466 ARCO Alaska, Inc. 700 G. Street Anchorage, Alaska 99510 (907) 265-6240 LOGS: Transmitted herewith is the following data: I Blackline Preliminary Copy Displayed by SCHLUMBERGER · Neve 1 CEMENT EVALUATION LOG (CET) 11-MAR-1996 CEMENT EVALUATION LOG (CET) 14-MAR-1996 CEMENT BOND LOG (CBT) 11-MAR-1996 CEMENT BOND LOG (CBT) l 1-MAR-1996 If you have any questions please call me at (907) 265-6240. Kelli RETURN SIGNED COPY TO: ARCO Alaska, Inc. Attn.: Ms. Kelli A. Thibodeau-ATO-1466 700 G. Street Anchorage, Alaska 99510-0360 (907) 265-6240 Ap. Eroved for transmittal by: Manager, North Alaska Exploration 3'38PM ARCO ALASKA INC ARCO Alaska, ~. Post Office .-,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 18, 1996 No. 8267 P. 2/4 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Weekly Operations Report ARCO Neve #1 Permit No. 95-215 ARCO Nanuk gl Permit No. 96-57 Dear Commissioner Johnston, Attached is the weekly operations summary for the ARCO Nanuk #1 and Neve #1 wells being drilled in the Colville delta area. The Nanuk #1 was spudded on March 12 and is presently drilling at 6800'. The Neve #1 well was completed with robing and packer in preparation of well testing operations. The Pool drilling rig is now being moved to the Temptation well location. If you have questions or require additional information, please contact Fred Johnson at 265-1492. Sincerely, Fred Johnson Drilling Engineer R£CEIVED MAR 1 9 1996 0il & ~as Cons. commission Anchorage AR38-6005-93 242 2693 i8.1996 3'36PM ARCO ALASKA INC No, 8215'1 ?. J/4 Date: 3/18/96 ARCO ALASKA INCORPORATED WELL SUMMARY RgPORT Page: 1 W~LL:NEVE #1 RIG:NO RIG WELL ID: AX9337 AFC: AX9337 STATE:ALASKA AREA/CAVI"f: NORTH SLOPE WEST FIELD: WILDCAT SPUD' START COMP; BLOCK: FINAL: TIGHT HOLE API NUMBER: 50~103-20231-00 03/11/96 (41) PBTD: 7590.7' ( SUPV; PBS 0) MW: 10.6 PV/YP: APIWL: LAY DOWN 5" DRILL PIPE Install 7" packoff. Test to 3000 psi f/15 min. N/U stack test to 300/3000 psi. Inject diesel down annulus. LD DiP. 03/~2/96 (42) PBTD: 7590.7' ( SUPV: DBS 0) MW: 10.6 PV/YP: APIWL: P/U AND SINGLE IN 3-1/2 DP RIM w/gauge ring/Junkbasket, Tag bottom at 7570 W.L. depth. Run CET/CBT/CNL/GR, CET showed no cement across sands or above. Good cement indicated from 7400'-down. Pressure test casing to 4500 psi for i5 min., test good. Perf holes at 7220', Set cement ret~ner at 7150', Test retainer to 3500 pis, good. P/U 3-1/2 dp and single in hole. 03/13/96 (43) PB%'I)' 7150'( SUPV;DBS 0) MW; 10,6 PV/YP: APIWL: DRiLL C_MT. RETAIA~R @ 7156' Run stinger in hole and stab into retainer @ 7156',Pump cement in perfs to squeeze. Sting out. Reverse circ. POH. Wash down to 7150'. Drill on cement/cmt retainer at 71561 03/14/96 (44) PBTD: 7591'( SUPV:DBS 0) MW: 10.6 PV/YP; APIWL: R/U SWS FOR LOGS Drill up cement retainer at 7153 and hard cement to 7231, Shut in and test squeeze perfs 7220-7222 to 500 psi for 10 min., lost 10 psi in 10 min, R/U for lOpS, 03/15/96 (45) PBTD: 7591~( SUPV:DBS 0) MW: 10,6 PV/YP: APIWL: RUNNING 3 1/2 COMPLETION GIH for CET/CBT/CBL/CNL. Log out, Stand down safety meeting for all personnel. RIH with gun assembly. Guns set at 7268- 7376'.Fire charges, set packer 8 7240. RIH with completion, 03/16/96 (46) MW: 10.6 PV/YP: APIWL: PBTD: 7591'( 0) RIG RELEASED TO TEMPTATION 91 SUPV:DBS Finish running 3.5" tubing in hole. Set packer at 7145', Displace tubing with diesel, Test surface lines and pressure test 7" x 3.5" annulus to 3000 psi for 10 min. OK. Rig release at 0600 hfs 3/16/96. End of wellSumma~y for Well:AX9338 RECEIVED Date: 3/18/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:NEVE %1 RIG:NO RIG WELL ID: AX9337 AFC: AX9337 -- STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: WILDCAT SPUD: START COMP: BLOCK: FINAL: TIGHT HOLE API NUMBER: 50-103-20231-00 01/31/96 ( 1) TD: 120' (120) SUPV:WJP 02/01/96 (2) TD: 120'( 0) SUPV:WJP 02/02/96 (3) TD' 120'( 0) SUPV:WJP 02/03/96 (4) TD: 120'( 0) SUPV:DCB 02/04/96 (5) TD: 120'( 0) SUPV:DCB 02/05/96 (6) TD' 120'( 0) SUPV'DCB 02/06/96 ( 7) TD: 120'( 0) SUPV:DCB 02/07/96 (8) TD' 120'( 0) SUPV:DBS 02/08/96 (9) TD' 120'( 0) SUPV:DBS MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP CAMP Mobilized camp from 2M pad to Neve location. Conductor is installed and cemented. MW: 0.0 RIGGING UP Continuing to rig up. PV/YP: O/ 0 PV/YP: O/ 0 APIWL: 0.0 APIWL: 0.0 MW: 0.0 RIGGING UP Rigged up shop and mobilized rig-up crane and sub-base. Set sub-base over well. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP Complete setting sub base, move in drawworks and set on sub. Camp and shop rigged up. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP Continued R/U operations. Began assemblying derrick. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP Continued R/U operations. Continue derrick construction. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP Continue to rig up. Finish derrick construction. MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIGGING UP String up air hoist lines, catlines, tong lines and block hanging lines. MW: 0.0 PV/YP: 0/0 APIWL: 0.0 RIGGING UP Finish stringing derrick cables. Raise derrick. Date: 3/11/96 ARCO ALASKA INCORPORATED WELL S~Y REPORT Page: 2 02/09/96 (10) TD: 120'(0) SUPV: DBS 02/10/96 (11) TD: 120'(0) SUPV:DBS 02/11/96 (12) TD: 120'( 0) SUPV:DBS 02/12/96 (13) TD: 120'( 0) SUPV:DBS 02/13/96 (14) TD: 120'( 0) SUPV:DBS 02/14/96 (15) TD: 135'( 25) SUPV:DBS 02/15/96 (16) TD: 1050'( 915) SUPV:DBS 02/16/96 (17) TD: 1860' ( 810) SUPV:DBS 02/17/96 (18) TD: 1860'( 0) SUPV:DBS 02/18/96 (19) TD: 1860'( 0) SUPV:DBS 02/19/96 (20) TD: 1841'( 0) SUPV:DBS MW: 0.0 PV/YP: 0/0 RIGGING UP Raise substructure. Set cheke manifold. APIWL: 0.0 iv~: 0.0 RIGGING UP Continue R/U operations. PV/YP: 0/0 APIWL: 0.0 MW: 0.0 PV/YP: 0/0 APIWL: 0.0 RIGGING UP Work on mud pumps. Continue R/U operations. MW: 0.0 PV/YP: 0/0 APIWL: 0.0 RIGGING UP Finish working on mud pits. Continue R/U operations. MW: 0.0 PV/YP: 0/0 APIWL: 0.0 RIG UP Finish installing std. pipe. Hang kelly hose. Continue to rig up. MW: 10.0 PV/YP: 50/34 APIWL: 10.0 RIGGING UP Function test diverter. Accept rig @ 1800 hrs. 2/13/96. Drill from 110' to 135' MW: 10.0 PV/YP: 26/35 API~TL: 9.6 DRILLING Drill from 135' to 221', lost 600 psi press. POH looking for washout. Wash to bottom and drill from 221' to 253', plugged bit jet. Attempt to unplug jet, not successful. POH, unplug jet, RIH, wash to bottom from 230-253'. Drill from 253' to 1050' MW: 10.0 PV/YP: 19/23 APIWL: 9.6 SHORT TRIP TO CONDUCTOR Drill from 1050' to 1860'. Control drill and survey as needed. POH, drug @ 1630' & 640'. Wash and ream through tight spots. Fill @ 1797'. Wash to bottom at 1860'. 63' of fill. Pump pill. Short trip. MW: 10.1 PV/YP: 24/27 APIWL: 9.2 PUMPING 9-5/8 CEMENT Tag fill and wash out from 1805' to 1860'. Held pre-job safety meeting. Run 9-5/8" casing. Tagged fill @ 1834' Cement casing. MW: 10.1 PV/YP: 26/21 APIWL: 9.2 N/U BOPE Finish 9-5/8" cement job. R/U to do top job. Pump cement. MW: 10.0 PV/YP: 20/18 APIWL: 9.6 DRLG. FLOAT EQUIP. Test BOPE to 300/3000. TIH, tag soft cement at 1695'. Test 9-5/8" to 2500 psi for 30 min. Lost 75 psi. Test good. Break circ. and drill up float collar and float equip. Good Date: 3/11/96 02/20/96 (21) TD: 2930' ( 1089) SUPV:DBS 02/21/96 (22) TD: 3879'( 949) SU?V:DCB 02/22/96 (23) TD: 4844'( 965) SUPV:DCB 02/23/96 (24) TD: 5670' ( 826) SUPV:DCB 02/24/96 (25) TD: 6295' ( 625) SUPV:DCB 02/25/96 (26) TD: 7088'( 793) SUPV:DCB 02/26/96 (27) TD: 7259' ( 171) SUPV: DCB 02/27/96 (28) TD: 7259'( 0) SUPV:DCB 02/28/96 (29) TD: 7271' ( 11) SUPV:DCB 02/29/96 (30) TD: 7276' ( 5) SUPV: DCB ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 cement, no correction. MW: 10.2 PV/YP: 16/8 APIWL: 7.2 DRILLING 8-1/2" HOLE Drilling float equipment and 10' of new hole to 1870' Perform leak off test with rig pumps, EMW of 14.1 ppg. Drilling from 1870' to 2930' MW: 10.3 PV/YP: 16/12 DRILLING 8-1/2" HOLE Drilling from 2930' to 3879'.. APIWL: 6.8 MW: 10.2 PV/YP: 13/9 DRILLING 8-1/2" HOLE Drilling from 3879' to 4844'. APIWL: 6.6 MW: 10.3 DRILLING 8-1/2" HOLE Drilling from 4844' to 5670' PV/YP: 15/9 APIWL: 6.5 MW: 10.2 PV/YP: 14/8 APIWL: 6.4 DRILLING 8-1/2" HOLE Drilling from 5670' to 6142' POH, hole tight, intermitt- ent. Jar through several spots at 30' intervals. Tight from 6142'-5880'. Download MWD, had to lay down CDR to download at unit. Motor locked up. Break out bit. Erosion on stage 2 cutter backsides, minor chipped cutters, OK gauge. RIH, test motor at HWDP, fill pipe shoe and 4200'. Ream in 49' and relog hole 15'. Drilling from 6142' to 6295' MW: 10.3 PV/YP: 14/8 APIWL: 6.2 MAD PASS MWD Drilling from 6295'- 7088'. POH, tight from 6560'-6465'. RIH to 7022'. Break circulation, working tight hole, hole packing off and sticking. Clean up hole. Make mad pass last 60' of hole. MW: 10.2 PV/YP: 2/ APIWL: 6.2 TAKE ON CORE FLUID Drilling from 7088' to 7259', core point. Circulate, work pipe, and clean mud pits. Take on 900 bbl core fluid and haul old mud out. Prep for displacement. MW: 10.2 PV/YP: 22/16 APIWL: 3.4 TIH F/CORE %1 Displace hole with coring fluid. Test choke manifold. Test BOPE 250/3000 psi. RIH w/coring assembly to 1800' MW: 10.3 PV/YP: 26/18 APIWL: 3.2 CBU F/SAMPLES Coring from 7259-7267'. POH w/core. Core bbl jammed. TIH w/rotary assembly to clean hole and top sand unit. Wash and ream hole section. Drilling from 7267'-7271' MW: 10.6 PV/YP: 34/24 APIWL: 3.0 START CORE RUN #2 @ 7276' Drill from 7271' to 7276'. Short trip. Some minor tight hole; 16 std off bottom ahd tight spot. Overpull minor if Date: 3/11/96 03/1/96 (31) TD: 7336'( SUPV:DCB 30) 03/2/96 (32) TD: 7336'( SUPV:DCB 0) 03/3/96 (33) TD: 7336'( SUPV:DCB 0) 03/4/96 (34) TD: 7579'( SUPV:DCB 243) 03/5/96 (35) TD: 7700'( SUPV:DCB 121) 03/6/96 (36) TD: 7700'( SUPV:DBS 0) 03/7/96 (37) TD: 7700'( SUPV:DBS 0) ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 4 pipe pulled slowly. Drag induced with greater trip speed. Wash 16' fill, pump sweep, shale cavings over shaker in fair quantity. Increase mud wt. to 10.6 due to shale instability. POH, minor bobbles 7183, 7090, 6662, 5730'. No pipe rotation problem. RIH with coring BHA. Wash in core barrel from 7184' to 7276' Had 5' fill, worked through to bottom and re- reamed with no indication of fill. Drop ball prep to core. MW: 10.5 PV/YP: 28/17 APIWL: 4.0 MIX LCM PILL Coring from 7276-7336'. POH w/core. Lay down core (59.5'). Lost complete returns, hole not appearing to be trying to pack off and no increase of pump pressure or tight hole until after loss observed. Spot pill. Continue to monitor static loss. MW: 10.5 PV/YP: 24/15 APIWL: 3.4 WASH TO BOTTOM Monitor well, losing 10-15 bbl hr static loss. Pump LCM. Monitor well for static losses, hole stable. Break circu- lation, had small returns to 20%. Check well every stand, monitor displacement, losing mud to hole. Hole swabbing and packing off in several spots. Pump LCM. Monitor well, no static loss. MW: 10.5 PV/YP: 24/19 APIWL: 3.2 CIRC/SWEEP HOLE Wash in to 7256'. Lost partial returns. Work pipe at 6750', good returns, bringing lot of slough up. Wash and ream from 6750'-7336'. Difficult getting down; packed off 7121', 7215- 7336' Pumped several sweeps with LCM at hi-vis, hole clean- ing up. Mud volumes stable. MW: 10.5 PV/YP: 21/21 APIWL: 3.8 DRILLING 8.5" HOLE Wash/ream hard fill; trying to pack off frequently. Pump high-vis pull. Drilling from 7336-7579'. MW: 10.5 PV/YP: 24/24 APIWL: 4.0 POH F/LOGS Drill from 7579' to 7700' Drop survey. POH for logs. Hole good. Minor drag noticed std 3,4. MW: 10.6 PV/YP: 24/25 APIWL: 4.2 CHANGE LOGGING TOOL CONFIG. RIH w/DSI, DITE, GR. Hit bridge at 2380'. POH with logs. Work through tight area at 2800' Circ. and ream 20' to btm. 7680-7700' Swab from 2495-2400', work pipe, no drag, monitor well. GIH w/DSI, DITE, GR. Work through tight area at 2397'. Tool went to 2583' & stacked out solid. Work wireline tools, "No Go". POH. MW: 10.7 PV/YP: 25/22 APIWL: 4.2 PREP TO PULL OUT OF HOLE Finish attempt to log w/SOS. "No Go" @ 2553'. GIH w/MWD/LWD. Stop at shoe and fill DP. Hole tight from 2580'-2650', hole swabbing, DP corkscrewing through hole. Hole tight from 2700 to 2725, hole swabbing & corkscrewing. Tight from 2890 to 2990' Heavy returns across shakers. Ream @ 6983-7050', 03/8/96 (38) TD: 7671'( SUPV:DBS 03/9/96 (39) TD: 7700'( SUPV:DBS 0) 03/10/96 (40) PBTD: 7590.7'( SUPV:DBS 03/11/96 (41) PBTD: 7590.7T( SUPV:DBS 03/12/96 (42) PBTD: 7590.7T( SUPV:DBS 03/13/96 (43) PBTD: 7150'( SUPV:DBS 03/14/96 (44) PBTD: 7591'( SUPV:DBS 03/15/96 (45) PBTD: 75917( SUPV:DBS 0) 0) 0) 0) tight hole, bridges, sloughing shales. Log with Anadrill from 7000' to 7220'. Tight, bridges, sloughing at 7210. Prepare to pull out due to hole conditions and lay down. MW: 10.9 PV/YP: 25/21 APIWL: 4.0 REAM TO BTM @ 7671' POH, tight from 5930-5870. Test BOPE, 250/3000 psi. Wash and ream hole from 7154-7671'. Hole packed off with shales from 7184-7240. No fill from 7240-7360 (sds). Wash and ream shales, slt. stones from 7360 to present depth. Pack off problems from 7500-7520, and 7640-7661. MW: 11.0 PV/YP: 1/ APIWL: 4.2 CIRC., PUMP SWEEP FOR CSG. Ream to 7700', pump hi vis sweep. Hole tight from 7672- 7600 and f/7450-7400. Hole packed off, lost 30 bbls of fluid POH to 6750. Hole swabbed through entire shale section. TIH, hole slick, Wash in last 487, 10-15' of loose fill on btm. TOH to shoe, hole slightly tight f/7700-7650 and 7360. Hole clean through rest of shale sections, no swabbing, POH to shoe. TIH, fill pipe at 44007, hole slick. Cont. in hole to 7467, tight, ream last 207 to bottom. Pump sweep, build Soltex pill to spot on bottom. 0) MW: 11.0 PV/YP: 24/20 APIWL: 4.6 RIG DOWN DOWELL Spot Soltex pill. POH to 1100' Change top rams to 7", test to 300/3000 psi. Run 7" casing. Pump cement. 0) MW: 10.6 PV/YP: APIWL: LAY DOWN 5" DRILL PIPE Install 7" packoff. Test to 3000 psi f/15 min. N/U stack test to 300/3000 psi. Inject diesel down annulus. LD DP. 0) MW: 10.6 PV/YP: APIWL: P/U AND SINGLE IN 3-1/2 DP RIH w/gauge ring/junk basket. Tag bottom at 7570 W.L. depth. Run CET/CBT/CNL/GR. CET showed no cement across sands or above. Good cement indicated from 7400'-down. Pressure test casing to 4500 psi for 15 min., test good. Perf holes at 72207. Set cement retainer at 71507. Test retainer to 3500 pis, good. P/U 3-1/2 dp and single in hole. MW: 10.6 PV/YP: APIWL: DRILL CMT. RETAINER @ 7156' Run stinger in hole and stab into retainer @ 7156'.Pump cement in perfs to squeeze. Sting out. Reverse circ. POH. Wash down to 7150'. Drill on cement/cmt retainer at 7156' MW: 10.6 PV/YP: APIWL: R/U SWS FOR LOGS Drill up cement retainer at 7153 and hard cement to 7231. Shut in and test squeeze perfs 7220-7222 to 500 psi for 10 min., lost 10 psi in 10 min. R/U for logs. MW: 10.6 PV/YP: APIWL: RUNNING 3 1/2 COMPLETION GIH for CET/CBT/CBL/CNL. Log out. Stand down safety meeting for all personnel. RIH with gun assembly. Guns set at 7268- 7376'.Fire charges, set packer @ 7240. RIH with completion. 03/16/96 (46) MW: 10.6 PV/YP: APIWL: PBTD: 7591'( 0) RIG RELEASED TO TEMPTATION #1 SUPV:DBS Finish running 3.5" tubing in hole. Set packer at 7145' Displace tubing with diesel. Test surface lines and pressure test 7" x 3.5" annulus to 3000 psi for 10 min. OK. Rig release at 0600 hfs 3/16/96. End of WellSummary for Well:AX9338 OIL A ¥D GAS CONSERVATION COM31I$SION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 1V~rch 13.1996 Thomas W. McKay, P.E. Sen/or Drilling Engin~r Kupamk Drill Site Development ATO 1202 ARCO 'Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Requested annular disposal of cement washdown water from Colville Delta exploratory wells Dear Mr. McKay: The Commission has received your request fo.r'authorization for disposal of cement washdown water from certain Col~lle Delta exploratory wells in the nnnuli of wells currently being drilled in the Kupamk River Unit. The washdown water would be generated by drilling operations at the following exploratory wells during the 1996 season' Bergschnmd #2, Bergschrund #2A, Alpine #3, Nanuk #1, Neve #1, Neve #lA, and Temptation #1. Disposal would take place into the nnnuli of wells being drilled by Parker Rig #245, for which nnnular disposal has already been authorized. We understand that cement washdown water is produced as a result of blending and mixing cement used in drilling wells. It therefore appears that the cement washdown water you propose for annular disposal is a nonhazardous waste associated with the act of drilling an oil or gas well for exploratory purposes, w/thin the meaning of AS 31.05.030(e)(2). Ordinarily annular disposal is permitted in well ~¢nuli located on the same drill pad as the well generat/ng the waste in question You have explained that the Colville Delta exploratory wells will not have annuli available for disposal operations. The Commission authorizes ARCO Alaska, Inc., to dispose of cement washdown water from the above-listed Colville Delta exploratory wells in the nnnuli of wells currently being dr/lied within the Kupamk River unit by Parker Rig #245, subject to the existing terms and conditions governing annular disposal in the latter wells. This authorization is for the 1996 drilling season only. Sine. rely, f. David Norton, Commissioner rmau B~bcock Commissioner ARCO Alaska, Ir Post Office ,~o× 100360 Anchorage, Alaska 99510-0360 Telephone 90'7 276 'i215 TRANSMITTAL TO: State of Alaska AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Robert Crandall SAMPLES SENT: 120' - 7700' DATE: March 11, 1996 AIRBILL: AIRLAND646131 CHARGE CODE: 42366 AFT#: ABV-06-03-11-19 WELL NAME: Neve #1 SAMPLE TYPE: Dry cuttings SENT BY: Daniel Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: Arco Alaska, Inc. 619 E. Ship Creek Ave Suite 104 Anchorage, AK. 99510 Attn: Dan Przywojski AR3B-6003-93 242-2603 ARCO Alaska, Ir Anchora.ge, Alaska 995!0-0360 Te!ephoc_,e 907 276 12!5 TRANSMITTAL TO: State of Alaska AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Robert Crandall SAMPLES SENT: 7259'- 7264' 7276'-7292' 7293'-7334' DATE: March 6, 1996 AIRBILL: AIRLAND646132 CHARGE CODE: 42366 AFT#: ABV-06-03-06-01 WELL NAME: Neve #1 SAMPLE TYPE: State core chips SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: Arco Alaska, Inc. 619 E. Ship Creek Ave Suite 104 Anchorage, AK. 99510 Attn: Dan Przywojski DATE: f",'IAR ''? 1996 AR3B-6003-93 242-2603 '~. i996 3'40PM ARCO ALASKA !NC Date: 3/4/96 ARCO ALASKA INCORPOPQXTED ~LL ID: ~9337 ~C: ~9337 STATE: ~/~: NORTH S~PE Page' TIGHT HOT NUMBER: 50-103-20231-00 FIELD: WILDCAT BLOCK: SPUD: START COMP: FINAL: 02/26/96 (27) TD: 7259' ( 271) SUPV; DCB 02/27/96 (28) TD; 7259' ( 0) SUPV: DCB 02/28/96 (29) TD: 7271' ( SUPV: DCB 02/29/96 (30) TD: 7276' ( 5) SUPV: DCB 03/1/96 (31) TD: 7336' ( SUPV: DCB 30) 03/2/96 (32) TD: 7336' ( SUPV: DCB 0) MW: 10.2 PV/YP: 2/ APIWL: 6.2 TAKE ON CORE FLUID Drilling from 7088' to 7259', core point. Circulate, work pipe, and clean mud pits. Take on 900 bbl core fluid and haul old mud out. Prep for displacement. MW: 10.2 PV/¥P: 22/16 APIWL: TIM P/CORE $1 DiSplace hole with coring fluid. Test choke manifold. Test BOPE 250/3000 psi. RIH w/coring assembly to 1800'. MW: 10.3 PV/YP: 26/18 APIWL: 3,2 CBU F/SAMPLES Coring from 7259-7267'. POH w/core. Core bbl Jammed. TIH w/rotary assembly to clean hole and top sand unit. wash and ream hole section, Drilling from 7267'-7271'. MW: 10,6 PV/YP: 34/24 APIWL: 3.0 START CORE RUN $2 @ 7276' Drill fro~ 7271' to 7276'. Short trip, Some minor tight hole; 16 std off bottom ahd tight spot. Overpull minor if pipe pulled slowly. Drag induced with greater trip speed, Wash 16' fill, pump sweep, shale cavings over shaker in fair quantity. Increase mud wt. to 10.6 due to shale instability. POH, minor bobbles 7183, 7090, 6662, 5730'. No pipe rotation problem. RIH with coring BHA. Wash in core barrel from 7184' to 7276'. Had 5' fill, worked through to bottom and re- reamed with no indication Of fill. Drop ball prep to core. ~W; 10.5 PV/YP: 28/17 APIWL: 4.0 MIX LCM PILL Coring from 7276-7336'. POH w/core, Lay down core (59.5'). Lost complete returns, hole not appearing to be trying to pack off and no increase of pump pressure or tight hole until after loss observed. Spot pill, Continue to monitor static loss. MW: 10.5 PV/YP: 24/15 ADIWL: 3.4 WASH TO BOTTOM Monitor well, losing 10-15 bbl hr static loss. Pump LCM. Monitor well for static losses, hole stable. Break circu- lation~ had small returns to 20%, Check well every stand, monitor displacement, losing mud to hole. Hole swabbing and packing off in several spots. Pump LC24. Monitor well, no static loss. 1996 3'40PM ARCO ALAS~fA iNC No. 7803 P, 5/6 Date: 3/4/96 ARCO ALASKA INCORPORATED WELL SUMMARY P~PORT Page: 2 03/3/96 (33) TD- 7336'( SUPV:DCB MW: 10.5 PV/YP: 24/19 APIWL: 3.2 CIRC/SW~EP HOLE Wash in to 7256', Lost partial returns, Work pipe at 6750', good returns, bringing lot of slough up. wash and ream from 6750~-7336'. Difficult getting down; packed off 7121~, 7215- 7336', pumped several sweeps with LCM at hi-vis, hole olean- lng up. Mud volumes stable. 03/4/96 (34) TD: 7579' ( SUFv: DCB 243) M~ 10.5 PV/¥P: 21/21 APIWL: 3.8 DRILLING 8.5" HOLE Wash/ream hard fill; trying to pack off frequently. Pump high-vis pull, Drilling from 7336-7579', End of WellSummary for Well:AX9338 ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Thomas W. McKay, P.E. Senior Drilling Engineer Kuparuk Drill Site Development P.~u 1202 Phone 265-6890 Fax 265-6224 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission .-:,-~r,,~ Porcupine Drive Anchorage, AK 99501 (907) 279-1 433 (907) 276-7542 (fax) Annular Disposal of Cement Washdown Water Colville Delta Exploratory Wells Re: Gentlemen' ARCO hereby requests a waiver to the AOGCC Regulations (20 AAC 25.080.) covering Annular Disposal of Drilling Waste recently adopted by the Commission on January 31, 1996. This waiver is requested to cover ARCO's Colville Delta exploratory wells currently being drilled during the 1996 winter drilling season. Cement washdown water is an integral part of any cement job. Cement is used as a means of pressure control in the wells being drilled. Each casing string, sidetrack plug, P&A plug, and other cement plugs mixed for use in drilling wells produce a relatively o,,,a,l~'~'' amount of cement washdown water as a result~,~'-" '~-t,,e csr,,~,,t' u,enc' ' ':,.~' and mixing operation. We are requesting the Commission determine under 20 AAC 25.080. that this washdown water is a waste associated with the act of drilling a well and permitted for annular disposal. Secondly, ARCO requests permission to transport cement washdown water from the Colville exploratory operations to approved disposal annuli in the Kuparuk River Unit. This waiver is required since cement washdown water is not exempt, and thus cannot be disposed of in Class 2 injection wells in the Kuparuk River Unit. It is also required because the Colviile Delta exploratory wells do not have annuli available for annular disposal operations. Normally, the amount of cement washdown water generated for any individual cement job is less than 250 bbls, although it an vary widely depending upon the operation. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany The wells generating cement washdown water needing a waiver this winter include' Bergschrund~,- Bergschrund #2A Alpine #3 Nanuk #1 Neve #1 Neve #lA Temptation #1 The destination of the waste would be the permitted annu!i of the wells currently being drilled within the KRU by Parker Rig #245. The cement washdown water would be pumped into the permitted annulus that Parker Rig 245 was connected to at that time. Again, the permitted well would be within the Kuparuk River Unit. We appreciate your consideration of th~s reau~S~. If you have any questions or require any additional information on this matter, please contact me at 265-6890. Sincerely, Thomas W. McKay, P.E.. Senior Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. AI,AS'KA OI~ 3~.N[D GAS C ONSERTA_'TION COM3~$SION / t .. TONY KNOWI..Z$, GOVERNOR 3C01 PORCUPINE ANCHORAGE.. ALASKA ~c9501-,3192 PHONE: (9073 27~1 FAX: (907) 276.-7542 February, 29, 1996 William S. Isaacson Dr/tling Eng4_ueer Kapamk Drill Ske De'~elopment ARCO Alaska, Inc. P.O. Box 100.360 Anchorage, AK 99510-0360 Re: r~.uest for waiver to 20 AAC 25.080(d)(4), .&~nular Dis~os~t of Dr/iling Waste Dear ,.Mr. Isaacson The Comm/ssioa ha~ received your request for waiver .*.o 20 AAC 25.080(d)(4), wh/ch re.srr/ca annular disposal of dr/iling wasm from ~ operations in we~ on the same pad. The reques~ for waiver is intended for wells 1Q-21 and 2X- t7. ARCO s~ks authorization to inje~ drilling wastes from the 4 3/4" hote section ofwe~ lQ-21 and 2X-17 into the annulus of a well at ekher 3H or 3F pad. T~e 4 ~/4" section of the iQ-21 and 2X- 17 we~s will be dr/i/ed by either Nordic ¢t or a ~il~xt tubing unk (CTU). Altho ~ugh annuli are available for injection purposes on the iQ and 2X pads, neither Nordic #1 nor the CTU have the ability to grind and inject cuttings for annular disposal purposes. Crrind and/njea capabiEu7 ks available on Parker 245, wkich ks drilling on the 3H and'~F oads. ~ A2~.CO has indicated that a Class H disposnl weft will ~,2so be aw~iiable for use during the above mentioned drilling operations. Please be advised, that in addition ro the c.~mem washdown water, mentioned in your request, other wasms gene.m~i ~ dr42I/ng a~vifi~ that are approved for annular dispos.ai may not be .approve. :%r dL~osai ~. ~, C'-~.z:: ~ .~w:,~~:--~ ~ wax. The Commission hereby grants a waiver m 'ARCO .~ Inc. for wells l Q-2i and 2X-t7 from the requ/remen~ of 20 AAC 25.080(d)(4). Sincerely, David Norton, ?£. Tuckerman Bab~ck Commissioner MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission / TO: David Johnsto~ DATE: Chairman ~ February 26, 1996 THRU: FILE NO: Blair Wondzeil, P. !. Supervisor ./t FROM: Bobby Foster,~~'~'''~ SUBJECT: Petroleum Inspector A9ZIBZDD.doc BOPE Test - Pool 6 ARCO - Exploratory Neve #1 PTD # 95-0215 Monday, February 26, 1996: ! traveled this date to ARCO's Neve #1 being drilled by Pool Arctic rig 6 and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows there was 1 noncompliance item that had to corrected. The accumulator pumps were shutting down before the pressure reached 3000 psig. After the pressure switch was adjusted the unit worked OK. The location was in very good shape. All tanks were bermed and liners were in place. Ali extra equipment was stored properly and there was good access to all areas of the rig. The rig was clean and ali equipment seemed to be in good working order. Summary: I witnessed the BOPE Pool Arctic rig 6 drilling ARCO's exploratory well Neve # 1 - Test time 3 hours - 1 failure. Attach: A9ZIBZDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: POOL ARTIC Operator: ARCO Well Name: NEVE # 1 Casing Size: 9.625" Set @ Test: Initiai~ Weekly X Rig No. 6 PTD # Rep.: Rig Rep.: 1841' Location: Sec. Other DATE: 2/26/96 95-0215 Rig Ph.# 262-3142 DAVE BUMGARNER RICK BRUMLEY 14 T. 11N R. 4E Meddian Urn. Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK PTD On Location YES Standing Order Posted BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Well Sign OK Upper Kelly / IBOP (Gen) Drl. Rig O.__..~K, Lower Kelly / IBOP 1 Hazard Sec. YES Ball Type 1 Inside BOP YES Test Quan. Pressure P/F 1 300/3,000 P 1 300/3,000 P 1 300/3,000 P 1 300/3,000 1 300/3,000 2 300/3,000 P I 300/3,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES Quan. Pressure I 3O0/3,0OO 300/3,000 300/3,000 I 300/3,000 P/F P P P P , , , CHOKE MANIFOLD: No. Valves 18 No. Flanges Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F 300/3,000 P 46 3OO/3,O0O P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 6 @ 2100 3,000 I P 1,200 P min~es 34 sec. minutes 50 sec. YES Remote: YES Psig. Number of Failures: I ,Test Hrs.: 3.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at: I 279-1433 I REMARKS: The accumulator pressure had to be set to 3000 psig. When first tested the charge pressure fell to f lO0 psig - after making some adjustments the unit passed the test OK. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) A9ZlB7_DD.XLT !996 !0' !!AM ARCO ALASKA INC 1'~o, 758~ ?. b/'! Date: 2126196 ARCO ALASKA INCORPORATED W~LL SU~MAI~Y REPORT Page: 1 W~LL:NEVE #1 RIG:NORIG WELL ID: AX9337 AFC: AX9337 STATE;ALASKA AREA/CNTY' ~ORTH SLOPE WEST TIGHT HOT,F. API ~ER: 50-103-20231-00 FIELD: WILDCAT ~LOCK: SPUD; START COF~; FINAL: 01/31/96 (1) TD: i20'(120) SUPV:WJP ~: 0,0 PV/YP: 0/ 0 A~IWI,- 0,0 P~GGING UP Cie/viP Mobilized camp from 2M pad %0 Neve location. Conductor is installed and cemented. 02/01/96 (2) TD' 120'( 0) SUPV:WJP 02/02/96 (3) TD: 120'( 0) SUPV:WJ? MW: 0.0 RIGGING UP Continuing to rig up. ~v/Y~: O/ 0 A~IWL; O. 0 '~: 0.0 Pv/YP: 0/ 0 APIWL: 0,0 RIGGING UP Rigged up shop and mobilized rig-up crane and sub-base. Set sub-base over well. 02/03/96 (4) TD: 120'( 0) SUPV:DCB 02/04/96 ( 5} TD: 120'( 0) SUPV;DCB 02/05/96 (6) TD: 120'( 0) SUPV:DCB ~4w: 0,0 PV/YP: 0/ 0 A~IWL: 0.0 RIGGING UP Complete setting sub base, move in drawworks and set on sub. Camp and shop rigged up. MW: 0.0 PV/YP' 0/ 0 APIWL: 0.0 RIGGING UP Continued R/U operations. Began assemblying derrick. MW: 0.0' ~V/YP: 0/ 0 APIWL: 0.0 RIGGING U~ Continued R/U operations. Continue derrick construction. 02/06/96 (7) TD' 120'( 0) SUPV:DCB 02/07/96 (8) TD: !20'( 0) SUPV:DBS ~: 0.0 PV/YP: 0/ 0 APIWL' 0.0 RIGGING UP Continue to rig up. Finish derrick construction, lv~,~: 0.0 PV/YP: 0/ 0 A~IWL: 0,0 RIGGING UP String up air hoist lines, catlines, tong lines snd block -hanging lines. 02/08/96 (9) TD: 120'( 0) SUPV:D~S MW: 0.0 PV/YP: 0/0 APIWL: 0,0 RIGGING UP Finish stringing derrick cables. Raise derrick. FEB 26 1996 Alaska Oil & Gas Cons. Commission Anchorage ~.i996 10'liAM ARCO ALASKA iNC No. '/b~lJ Date: 2/26/96 ARCO ALASF4% INCORPORATED WELL SUMMARY REPORT Page: 2 02/09/96 (10) TD: 120'(0) SUPV:DBS 02/10/96 (11) TD: !20'(0) SUPV:D~S 02/11/96 (12) TD: 120'( 0) SUPV:DBS 02/12/96 (13) TD; 120'( 0) SUPV: DBS 02/13/96 (14) TD: 120'( 0) SUPV: DBS 02/14/96 (15) TD: 135'( 25) SUPV:DBS 02/15/96 (16) TD' 1050' ( 915) SUPV :DBS 02/16/96 (17) TD' 1860'( 810) SUPV:D~S 02/17/96 (18) TD' 1860'( 0) SUPV:DBS 02/18/96 (19) TD: 1860'( 0) SUPV:DBS 02/19/96 (2O) TD: 1841'( 0) SUPV: DBS MW: 0.0 PV/YP: 0/0 RIGGING UP Raise substructure, Set choke manifold. APIWL; O, O MW: 0.0 PV/YP: 0/0 APIWL: 0.0 P~IGGING UP Continue R/U operations. MW: 0,0 PV/YP: 0/0 APIWL: 0.0 RIGGING UF Work on mud pumps, Continue R/U operations, MW: 0.0 PV/YP: 0/0 APIWL: 0.0 RIGGING UP Finish working on mud pits, Continue R/U operations. ~fw: O, 0 PV/YP: 0/0 APIWL: O. 0 i~IG UP Finish installing std. pipe, ~ang kelly hose. cOntinue tO rig up. MW: 10.0 PV/YP: $0/34 APIWL; 10,0 RIGGING UP Function test diverter. Accept rig @ 1800 hrs. 2/13/96. Drill from 110' to 135'. F/~: 10,0 PV/YP: 26/35 APIWL: 9.6 DRILLING Drill from 135' tO 221', lost 600 psi press. POH looking for washout, Wash to bottom and drill from 221' to 253', plugged bit jet, Attempt to unplug Jet, not successful, POH, unplug jet, RI~, wash to bottom from 230-253'. Drill from 253' to 1050'. MW: 10.0 PV/YP: 19/23 APIWL: 9.6 S~ORT TRIP TO COR~UCTOR Drill from 1050' to 1860'. Control drill and survey as needed. POH, drug @ 1630' & 640'. Wash and ream through tight spots. Fill @ 1797', wash to bottom at 1860'. 63~ of fill. Pump pill, Short trip. ~: 10.1 PV/YP: 24/27 APIWL: 9,2 PUMPING 9-5/8 CEMENT Tag fill and wash out from 1805' to 1860'. Held pre-job safety meeting. Run 9-5/8" casing. Tagged fill @ 1834', C~ent casing. ~: 10.1 PV/YP- 26/21 APIWL: 9.2 N/U BOPE Finish 9-5/8" cement Job. R/U to do top job. Pump cement. ~W: 10.0 pv/¥P: 20/18 APZWL; 9,6 DRLG, FLOAT BQUIP. Test BOPE to 300/3000. TIH, tag soft cement at 1695'. Test 9-5/8" tO 2500 psi for 30 min. Lost 75 psi. Test good. Break circ. and drill up float collar and float equip, Good Alaska Oil & Gas Cons, Commission Anchorage 995 i0'!iAM £~o.'/bUb r. ~/: ARCO ALASKA Date: 2/26/96 ARCO ALASKA iNCORPORATED W-ELL SUMMARY REPORT Page: 3 cement, no correction, 02/20/96 (21) TD' 2930'( 1089) SUPV'DBS 02/21/96 (22) TD: 3879'( 949) SUPV;DCB 02/22/96 (23) TD' 4844'( 965) SUPV:DCB 02/23/96 (24) TD: 5670'( 826) SUPV: DCB 02/24/96 (25) TD: 6295'( 625) $UPV:DCB 02/25/96 (26) TD: 7088'( 793) SUPV:DCB MW: 10.2 PV/YP: 16/8 APIWL: 7.2 DRILLING 8-1/2" HOLE Drilling float equipment and 10' of new hole to 1870' Perform leak off test with rig pumps, EMW of 14.1 ppg. Drilling from 1870' to 2930'. MW: 10.3 PV/YP: 16/12 DRILLING 8-1/2" HOLE Drilling from 2930' tO 3879',, MW: 10,2 DRILLING 8-1/2" HOLE Drilling from 3879' to 4844' PV/YP: 13/9 MW: 10.3 PV/YP: 15/9 DRILLING 8-1/2" HOLE Drilling from 4844' to 5670', APIWL: 6.8 APIWL: 6,6 APIWL · 6.5 MW: 10.2 PV/YP; 14/8 APIWL: 6.4 DRILLING 8-1/2" HOLE Drilling from 5670' to 6142'. POH, hole tight, intermitt- ent. Jar through several spots at 30' intervals. Tight from 6142'-5880' Download MWDr had to lay down CDK to download at unit. Motor locked up. Break ou% bit, Erosion on stage 2 cutter backsides, minor chipped cuEters, OK gauge, RIH, test motor at HWDP, fill pipe shoe and 4200'. Ream in 49' and relog hole 15', Drilling from 6142' to 6295'. MW: 10,3 PV/YP: 14/8 APIWL; 6,2 MAD PASS MwD Drilling from 6295'- 7088'. POH, tight from 6560'-6465' RIH to 7022', Break circulation, working tight hole, hole packing off and sticking, Clean up hole. Make mad pass last 60' of hole. 02/26/96 (27) MW: 10.2 PV/YP: 2/ APIWL: 6.2 TD: 7259'( 171) TAKE ON CORE FLUID SUPV:DCB Drilling from 7088' tO 7259', core point. Circulate, work pipe, and clean mud pits. Take on 900 bbl core fluid and haul old mud out. Prep for displacement. End of wellSummary for Well:AX9337 FEB 26 1996 A~,ka Oil & Gas Con~. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh..Q~~ DATE: Chairman~-'-' February 17, 1996 THRU: Blair Wondzell, ~.~,.~ FILE NO: P. !. Supervisor FROM: Doug Amos, "~ ~ SUBJECT: Petroleum Inspector a99hbqdd.doc BOPE Test Pool 6 Arco Neve No. 1 Exploratory PTD# 95-215 Saturday, February 17, 1996: ! received a call from Arco representative Doug Stholts and informed that they were ready to conduct a BOPE test at Arco Neve #1 well on Pool Rig No. 6. I was unable to witness the test due to Phase 3 weather conditions in Kuparuk. SUMMARY: I was unable to witness the BOPE test on Pool No. 6 at Arco Neve #1 Well due to Phase 3 weather conditions at the location. Attachment: None MEMORANDUM State of Alaska TO: THRU: / David John~~ Chairma'~,,,,'- Blair Wondzell, -~~ P. I. Supervisor Alaska Oil and Gas Conservation Commission DATE: February 15, 1996 FILE NO: e9zlbmdd.doc FROM: John Spauiding,r~,.. SUBJECT: Petroleum Insp. Diverter Function Test ARCO Neve #1 "Wildcat" PTD 95-215 Tuesday February 13, 1996: i traveled this date to witness the Diverter Function Test at ARCO's Neve #1 "Wildcat" well, on Pool rig #6. The AOGCC test report is attached for reference. The test went well with 1 failure observed on the annular preventer manual actuating valve, located on the accumulator system. C. Sheve the Pool Tool Pusher was in the process of exchanging this valve for a new one when I departed location. I have since received notification that the valve was re-tested and functioned properly. I found the location neat and orderly with good access. The rig was laid out in a manner that took good advantage of the prevailing wind direction. Summary: I witnessed the successful Diverter Function Test on Pool rig 6 with 1 failure, 6 hours test time. Attachments' e9zlbmdd.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Drlg Contractor: Pool Rig No. Operator: ARCO Oper. Rep.: Well Name: Neve #1 Rig Rep.: Location: Sec. 14 T. 11N R. 4E Development 6 PTD # Exploratory: 95-215 Rig Ph. # Doug Stoltz C. Scheve Merdian Umiat X 263-3142 TEST DATA MISC. INSPECTIONS: Location Gen.' ok Well Sign: ok Housekeeping: ok (Gen.) Drlg. Rig: ok - Reserve Pit: na Flare Pit: na DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted Long Radius: 20 in. yes yes 16" in. 130 ~' ft. ne yes yes na ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 2900 1500 min. 35 2 min. 33 8 @ 2350 avg. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: GAS DETECTORS: Methane Hydrogen Sulfide' Light Alarm ok ok ok ok ok ok Light Alarm ok ok ok ok psig psig sec, sec, psig DIVERTER SCHEMATIC Shop Camp Mo to rs Sub -base Pipe shed Mud pits 16" vent line 100' outside of rig with full opening knife valve North Wind Direction Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.: Doug Stoltz F1-022 E9ZLBMDD.XLS TONY KNOWLE$, GOVERNOF~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Janua~ 12,1996 Mike Zanghi, Ddll Site Develop. Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Company Permit # Surf Loc Btmhole Loc Neve #1 ARCO Alaska Inc 95-215 2440'FWL, 465'FNL, Sec 14, T11N, R4E, UM 2440'FWL, 465'FNL, Sec 14, T11N, R4E, UM Dear Mr. Zanghi' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other govemmental agencies, and does not authorize conducting ddlling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Exception to diverter vadance 20 AAC 25.035(b)(1)is approved. 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 -~-,eFu;ajssion-petroleum field inspector on the North Slope pager at 659-3607. ........ ,,,.-/? /% David W. Johnston Chairman BY ORDER OF THE'COMMISSION dl~encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-31 92 Re~ THE APPLICATION OF ~RC'O ) ALASKA, INC. for an order granting an ) exception to spacing requirements of ) Title 20 AAC 25.055 to provide for the ) drilling of seven delineation oil wells in ) the Colville Delta vicinity. ) IT APPEARING THAT: o Conservation Order No. 367 ARCO Alaska, Inc. Nanuk No. 1, Neve No. 1, Neve No. lA, Neve No. lB, Temptation No. 1, Alpine No. 3, Bergschrund No. 4, January 3, 1996 ARCO Alaska, Inc. submitted applications dated December 7, 1995 requesting exceptions to the well spacing provisions of Title 20 AAC 25.055 (3) to allow drilling the ARCO Neve No. 1, Neve No. lA, Neve No. lB, Nanuk No. 1, Temptation No. 1, Alpine No. 3 and Bergschrund No. 4 delineation oil wells to locations within 500 feet of a quarter-section line in the Colville Delta vicinity of the North Slope. 2..Notice of opportunity for public hearing was published in the Anchorage Daily News on December 15, 1995 pursuant to 20 AAC 25.540. 3. No protests to the applications were received. FINDINGS: , , , , , , The Neve No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, Umiat Meridian (UM). The Neve No. lA delineation oil well as proposed will be drilled as a deviated hole with a surface location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, UM and bottomhole location 2960' from the north line and 530' from the west line of Section 14, T11 N, R4E, UM. The Neve No. 1 B delineation oil well as proposed will be drilled as a deviated hole with a surface location 465' from the north line and 2440' from the west line of Section 14, T11N, R4E, UM and bottomhole location 640' from the south line and 3290' from the west line of Section 11, T11N, R4E, UM. The Nanuk No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 2290' from the north line and 1140' from the west line of Section 30, T11N, R5E, UM. The Temptation No. 1 delineation oil well as proposed will be drilled as a straight hole at a location 1890' from the south line and 540' from the west line of Section 16, T12N, R4E, UM. The Alpine No. 3 delineation oil well as proposed will be drilled as a straight hole at a location 2145' from the north line and 2115' from the west line of Section 25, T12N, R4E, UM. Conservation Order No.. January 3, 1996 Page 2 . The Bergschrund No. 4 delineation oil well as proposed will be drilled as a deviated hole with a surface location 960.' from the north line and 1620' from the west line of Section 9, T11N, RSE, UM and bottomhole location 535' from the south line and 20' from the west line of Section 4, T11N, R5E, UM. , All owners and operators of governmental quarter sections directly and diagonally offsetting the quarter section proposed for each of the subject wells has been duly notified. 9. An exception to the well spacing provisions of Title 20 AAC 25.055 (3) is necessary to allow the drilling of each of the above listed wells. CONCLUSION' Granting a spacing exception to allow drilling of the ARCO Neve No. 1, Neve No. lA, Neve No. lB, Nanuk No. 1, Temptation No. 1, Alpine No. 3 and Bergschrund No. 4 wells will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED' ARCO Alaska, Inc.'s applications for exception to the well spacing provisions of Title 20 AAC 25.055 (3) for the purpose of drilling the seven wells described above are approved. DONE at Anchorage, Alaska and dated January 3, 1996. · ii ~--- ...... ~ ,k~,.~'-:. [ i~}~.-: '~:'~~"' i Alaska Oil and Gas Con,vati°n Commission ~-~...~. - ~ ~. .".-. VL~ ol ' .... ~ ~. ~avid ~orton, ~[., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23'd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the lO-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonacdon of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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__ Deepen _ Service _ Development Gas __ Single Zone _ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. KB ht above sea level:40 feet Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-380075 4. Location of well at surface 7. Unit r property Name 11. Type Bond (see 20 AAC 25.025) 2440' FWL, 465' FNL, Sec. 14, T11N, R4E, UM N/A Statewide At top of productive interval 8. Well number Number Same Neve #1 #U63061 0 At total depth 9. Approximate spud date Amount Same 1-15-96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. NumbEr of acres in properly 15. Propose ri depth (MD and TVD) property line 2400 feet 2 Miles 4376 Lease Acres 8,180' RKB MD & TVD feet 16. To be completed for deviated wells N/A 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth feet Maximum hole angle Maximum surface 1075 psig At total depth (TVD) 3828 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity, of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~e data) 2 0" 16" 62.58# B PEB 8 0' 4 0' 4 0' 120' 120' Permafrost Cement 12.25" 9.625" 53.5# L-80 BTC 1760' 40' 40' 1800' 1800' +290 sx AS-Ill, 600 sx AS-I 8.5" 7" 26.0# L-80 BTCMoo 8140' 40' 40' 8180' 8180' _+200 sx Class G 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 Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEI',/ u Intermediate Production Liner J~EC 2 8 1995 Perforation depth: measured true vertical AJ~[8 ~J ~ ~,~ ~-",":-'- .,d~l'ml,~-'-'-'-'-'-'-'-'-'-~Ol~ 20. Attachments Filing fee X Property plat X BOP Sketch X Diverter Sketch ~ Drilling program X Drilling fluid program X Time vs depth plot X Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoin, g is true and correct to the best of my knowledge Signed ~.r ¢ ,~ Title KRU Drillsite Development Supervisor ' '~ ~/ .~ Commission Use Only - PermiLNumber _ ~ JtA,C~number _ _, J ApprovaJ date,_ ~_~ J See cover letter for .2./5 50 .,/0 ..2.(::~,~-,-~ ] othe ~r / - - I /-/.?--- I r requ' ements Conditions of approval Samples required .~__Y e s __ N o Mud Icg required ~_ Y e s __ N o Hydrogen sulfide measures__ Y e s __~/N o Directional survey required __ Yes ,~ N o Required working pressure forBOPE __2M;__ 3 M · _.~ 5 M ' __ 1 OM' 1 5 M Other:Original Signed By David W. Johnston by order of Approved by Commissioner the commission Date / Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. S':bsidiory of Atlontic Richfield Compony LOUNSBURY ASSOCIATES, INC. ~NEERS PLANNERS SURVEYORS NEVE //1 EXPLORATORY WELL PERMIT EXHIBIT ISHEET: 1 OF 2 I' REV: CADD FILE NO. ' LK601184 ! 12(/07/95 DRAWING NO: NSK 6,01 d184 liON ! RL'V t ,~A iL i m f ~'~' J¼ i Ar~P ~.. , ....? ~.. ._ :' - 92-8i -~ '..m:>''~' ~ ~ ; ", /~s : r N / ~ / ~ ii :~ : '. / / .... ,'. , . '.~. ,: ( ~ , ~3//I ~ ' ~~ ~: / / ~ I / ' ~ ~ ~ 5~'~ /I / ,< ~~~3-: ~ ~,,; ,>' ~: /~1 ~ ' ~ :, 93-22 --; ~ ~ ~~.h : ~,,~ ~ ~~ ~ ... -. ~ ~~ 92-82 ' :I ~ · . ~ / - / 'I · : ~ , ~ '[t ~ : ' /' /" -' : .'/~ · [ '~ix ~ .,. ~ : _: / ...~. :~ : ! OOATED W~TH~N PROTRACTED ,3_ . , . · ' UMIAT MERIDIAN , ~ ,o I~'~T - 70' 18' 49' :/ ' .... / ~ C , ~ ,, , ~z ~N6.~ -- 151 03 06 'f ~ X = 370,251 U ~ ' i ~ ~ ~II ', ", ". / ", / ~ "~X : 0~ ' il, :, ~ ~ ' '. ' '. , ~ ::',~ ', ~ ~ , ',~ Subsidiary of Atlantic Richfield Company CADD FILE NO. I DRAWING NO: ;K601184 I 12 LOUNSBURY & ASSOCIATES, INC. ENGINEERS PLANNERS SURVEYORS NEVE #1 1995 EXPLORATORY WELI~£c 2 8 PERMIT EX~I~IBtaT~, ~ ,,¢ NSK 6.01 d184 SHEET:2A.~FO~ REV: 7.5~ (CO{ ALK4715 ADL 25538 NEVE #1 APC 1-31 L 25558 AAI 72.5: UTP APC 20.0~; 1-3t-75 -T- (CONe) ALK471( ADL 255; (COND) B ADL 25557 AN 63.9~ UTP 16.1~ APC 20~ ADL 372096 APl , . ~- nFO.-- ,~ P, 1995 .AjB~kn Oil & Gas Anchorage E PROPOSED DRILLING PROGRAM ARCO NEVE #1 (Per 20 AAC 25.005(c)(10)) RECEI'Vt:L) DEC 2 8 ~995 Naska 0il & Gas Cons. Con, mission Anchorage Surface Hole Drilling Hazard Section Neve #1 No specific drilling hazards are expected. Normal drilling precautions should be taken. Minor drill gas and hole sloughing should be expected at the base of the permafrost. Base of permafrost is expected at-+850, RKB. Production Hole Mud weight should be 9.8-10.0 lb~gal prior to drilling the C-30/K5 interval at 2360'. This interval in offset wells contains gas that is thought to be slightly pressured at 9.6 lb/ga/. Normal drilling precautions should be taken throughout the hole. RECEIV -u DEC 2 8. 1995 Alaska Oil & Gas Cons. ~mmission Anchorage Neve #1 · General Drilling Procedure Application for Permit to Drill December, 1995 (All depths are measured from RKB unless otherwise noted) Move in rig and rig up over pre-installed 16" conductor and cellar. Nipple up and function test diverter. Rig up mudloggers. Make up 12-1/4" bit and bottom-hole assembly and drill surface hole to 1,800' RKB. Run and cement 9-5/8" surface casing. Nipple down diverter, make up casing head, nipple up and test BOP TO 3000 psi. Pressure test 9-5/8" casing to 2500 psi. Drill out cement and float equipment with 8-1/2" bit. Drill 10' of new hole and perform leak-off test. POOH. Make up 8-1/2" bit and bottom-hole assembly with MWD/LWD (GR-Res). Drill 8- 1/2" hole to anticipated core point at +7,340' or TD (approx. 8,180' RKB). Run open-hole logs from TD to the 9-5/8" casing shoe. If Icg results are favorable, run and cement 7" casing. Nipple down BOP stack, nipple up tubing head, nipple up and test BOP stack. Run cased hole logs if required. REC E iV b' Pressure test 7" casing to 3,500 psi. DE(:; 2 8 ]995 Freeze protect 9-5/8" X 7" casing annulus, f,~.a~ka0il Anchorage Run in hole with completion-type test string, space out and land tubing hanger. Nipple up and pressure test 5,000 psi tree, tool string and manifold. Perforate well underbalanced using tubing-conveyed guns. Flow up the tubing and through surface testing facilities. Test liquids will be stored in tanks on the drilling location and pumped back into the reservoir or hauled to Kuparuk and processed through Kuparuk facilities.. Gas will be flared. Testing will involve alternating flow periods and shut-in periods. Individual intervals may be tested separately or concurrently. For long-term flow testing, the rig will be moved off location prior to perforating and will be moved to a different, but nearby, drilling location. After completion of testing, abandon well per AOGCC regs. Rig down and release drilling rig. Thoroughly clean and abandon the ice pad and ice road on the way out. NEVE #1 STRAIGHT HOLE 1996 COLVILLE DELINEATION -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 .~--- DRILL 12-1/4" SURFACE HOLE TO 1800 -. -m~~~--~DRILLS-1/2" HOLETOCORE POINT--~~ ..... fi ............... [ .... ~ .... ' ' ~ '' ' ' ' ' i ......... ~ ~ ......... .......... ~~ ......................... : ~ ' , : ~' ~ ~ ~ r i j .......... ~ ...... ~ '~~ ~ ~__~ ~ COREJ-4eBJECTIVE(2R~NS)4--~ 0 5 10 15 20 25 30 DAYS DIAGRAM DIVERTER AND DESCRIPTION OF SYSTEM TO BE USED POOL RIG #6 (Per 20 AAC 25.005(c)(5)) Per 20 AA(; 25.005(c)(3)- DIAGRAM AND DESCRIPTION OF BOP EQUIPMENT TO BE USED (As required in 20 AAC 25.035(a)(1)) INFORMATION ON AND MAXIMUM PRESSURES (As required in 20 AAC 25.035(d)(2)) RECEiVEL) DEC 2 8. ~995 ,~aska 0it & Gas Cons. ~,;ornmission Anchorage DIVERTER SCHEMATIC POOL RIG #6 I Flowline I I HYDRIL MSP 21-1/4" 2000 psi %~nnular Prevente?(1) I 21 -1/4" 2000 psi 16" Outlet Spool (2) 1611~ 62#, PEB Conductor 16", 200 psi Hydraulic Knife Valve 16" OD Diverter Line RECEiV~-u DEC 2 8 1995 AJaska Oil & BOP SCHEMATIC POOL RIG #6 13-5/8", 10,000 PSI I I I I I I 4 I I I I See listing of individual 8 RECEIV -u DEC 2 8 1995 A~ch0rage components on following page Revised 1/31/95 Diverter System' , . , BOP COMPONENTS ALPINE #1 POOL RIG #6 13-5/8, 10,000 PSI 21-1/4", 2000 psi WP, Hydril Type MSP annular preventer with companion flange to diverter spool. 21-1/4", 2000 psi WP diverter spool with one 16" outlet. 16", 200 psi WP FNW knife valve with hydraulic actuator on diverter outlet. BOP Stack: 4. 13-5/8", 5000 psi WP, Hydril Type GK annular preventer with companion flange to bell nipple. 5. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with pipe rams. 6. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with blind rams. Single 13-5/8", 10,000 psi WP, Hydril type MPL ram blowout preventer fitted with pipe rams. 8. 13-5/8", 10,000 psi WP drilling spool with one 3"and one 4" 10,000 psi WP outlets Choke Valves: 9. 4", 10,000 psi WP McEvoy Type E gate valve with hydraulic actuator 1 0. 4", 10,000 psi WP McEvoy Type E manual operated gate valve Kill Valve: 1 1. 3", 10,000 psi WP McEvoy Type E manually operated gate valve 12. 3", 10,000 psi WP McEvoy Type E gate valve with hydraulic actuator . RECEIVI-_u · DEC 2 8 1995 Alaska Oil & ~,~ Revised 1/31/95 PRESSURE INFORMATION ARCO NEVE #1 The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Neve #1 well: Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (ft. RKB) (lbs/gal) (lbs/gal) (psi) (psi) 1 6 1 20 10.9 8.6 5 3 5 5 9-5/8 1800 13.6 9.0 842 1075 7 81 80 1 6.4 9.0 3828 N/A Procedure for Calculatinq 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 = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2) ASP = FPP-(0.11 x D) where: FPP = Formation Pore Pressure at the next casing point ASP Calculations 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11]D [(10.9 x 0.052) - 0.11] x 120 55 psi ASP = --. --,,. FPP- (0.11 x D) 842-(0.11 x 1800) 644 psi RECEIVbu DEC 2 8- ~995 Alaska Oil & Gas Cons. Commission Anchorage . Drilling below surface casing (9-5/8") ASP = [(FG x 0.052) - 0.11]D = [(13.6 x 0.052) - 0.11] x 1800 = 1075 psi ASP= FPP - (0.11 x D) = 3828 - (0.11 x 8180) = 2928 psi Casing Performance Properties Size Weight Grade (in) (Ib/ft) 1 6 62.58 B 9-5/8" 53.5 L-80 7 26 L-80 Cnxn PEB BTC BTC-Mod Internal Collapse Tensile Strength Yield Resistance Joint Body (psi) (psi) (1000 lbs) Conductor Casing 7930 6620 1329 1244 7240 5410 667 604 Casing Setting Depth Rationale 16" 120' RKB 9-5/8" 1800' RKB 7" 8180' 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. P. roUuction 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. RECEiVbu DEC 2 8 995 Alaska Oil & Gas ¢;ons. Commission Anchorage SUPPORT DOCUMENTS FOR REQUEST FOR EXCEPTION TO 20 AAC25.035(b)(1) (Bifurcation of Diverter Line) RECEiV -u DEC 2 8 ~995 Alaska Oil & Gas Con~. ARCO Alaska, Inc. hereby applies for an exception to the provisions of 20 AAC 25.035(b)(1), concerning bifurcation of the diverter line. Following are the major concerns associated with this request. 1) After extensive study of the 1992 Cirque blowout and the performance of the equipment on Cirque, ARCO Alaska, Inc. has determined that a combination of one 16" line with no 90° turns is the optimum design. 2) Effective operation of remote valves positioned 100 feet from the rig are limited. 3) Prevailing winds on the North Slope during the winter drilling season are generally in the direction of NE to SW. With perpendicular placement of the diverter line, there is minimum exposure of gas blowing back onto an ignition source. It is our opinion that with proper placement of the diverter line with respect to prevailing winds in conjunction with the short duration of time while drilling under the diverter, a bifurcated line is not necessary. RECEIVi::u DEC 2 8-1995 Alaska Oil & Gas Cons, Commission Anchorage PROPOSED CASING AND CEMENTING PROGRAM ARCO Neve #1 (Per 20 AAC 25.005(c)(4)) RECEIV L) DEC 2 8 't995 0il & Gas Cons, ~mmission A~chorage WELLBORE SCHEMATIC AND CEMENT PLAN NEVE #1 16" Conductor @ 120' RKB 12-1/4" Hole 9-5/8" Surface Casing @ 1,800' RKB 8-1/2" Hole Top of Cement at approx. 6,600' RKB 7" Production Casing @ 8,180' RKB, Cemented to 500' above Jurassic Sands Casing Size: ...... 16" Hole Size: 20" Depth: 120' RKB Top of Cement: Surface Excess Calculated: 100% Volume Calc: (120')(0.7855 cuft/ft)(2) = (189 cuft)/(0.93 cuft/sk) = 203 sks 203 sacks ARCTICSET I Slurry Volume 189 cuff Slurry Weight 15.7 ppg Slurry Yield 0.93 cu. ft./sk Mix water 3.59 gps Thickening time 2+ hours Casing Size: 9 5/8" Hole Size: 12 1/4" Depth: 1,800' RKB Top of Cement: Surface Excess Calculated: 100% BHT (Static): 60°F BHT (Circ): 60°F Volume Calc: Lead (900')(0.3132 cuft/ft)(2) = (564 cuft)/(1.94 cuft/sk)= 291 sks Volume Calc: Tail (900')(0.3132 cuft/ft)(2) = (564 cult)/(0.93 cuft/sk): 607 sks Lead: 291 sacks ARCTICSET III + 1/4 #/sk D29 (celloflake) Slurry Volume 564 cuft Slurry Weight 12.1 ppg Slurry Yield 1.94 cu. ft./sk Mix Water 11.11 gps Thickening time 6.0+ hours Tail: 607 sacks ARCTICSET I + 1/4 #/sk D29 (celloflake) Slurry Volume 564 cuft Slurry Weight 15.7 ppg Slurry Yield 0.93 cu. ft./sk Mix water 3.59 gps Thickening time 3+ hours Casing Size: 7" Hole Size: 8 1/2" Depth: 8,180' RKB Top of Cement: 6,600' RKB Excess Calculated: 20% (depending on caliper) BHT (Static): 170°F BHT (Circ): 140°F Volume Calc: (8,180' - 6,600')(0.1268 cuft/ft)(1.2) = (240 cuft)/(1.19 cuft/sk) -- 202 sks 202 sacks Class G cement + 2 gps D600(latex) + 0.1 gps D135(stabilizer) + 0.1 gps D47 (defoam) + 3% D53(Gyp) + 0.7% D65(dispersant) + 0.05% D800(retarder) Slurry Volume Slurry Weight Slurry Yield RECEIVbu Mix water Thickening time DEC 2 8 1995 Alaska 0il & Gas Cons, Commission 240 cult 15.8 ppg 1.19 cu. ft./sk 5.18 gps 3.5 - 4.5 hours PROPOSED DRILLING FLUID PROGRAM and DRILLING FLUID SYSTEM DESCRIPTION ARCO NEVE #1 (Per 20 AAC 25.005(c)(6)) ARCO Alaska, Inc. Proposed Mud Program Neve #1 (Colville Exploration) November 20, 1995 General Well Plan: A standard Kuparuk type fresh water spud mud (10.0 ppg) will be used to the 9 5/8" casing point. From there to TD, a fresh water LSND system similar to that used on last winter's Alpine and Fiord tests will be used to drill the 8 1/2" hole. The plan is to treat the fresh water spud mud for cement contamination when drilling out of the 9 5/8" surface shoe and drill ahead in the 8 1/2" hole to TD treating the system as a standard fresh water LSND system. However, as dictated by the actual drilling requirements of this well, an inhibited mud (KCl) may be required to address special coring or formation damage issues. Estimated Casinq Program: Hole Size Casinq Size 20" Conductor 12 1/4" 9 5/8" 8 1/2" 7" I. Surface Hole (12 1/4" Hole to 9 5/8" Casing): 1.) The current plan is to have 800 bbls of 10.0 ppg spud mud at the Baroid Prudhoe Bay Mud Plant to spud this well. The mud will be delivered to the rig with the following target properties: Density - 10.0 ppg Viscosity - 120 sec/qt YP - 35-40 lbs/100ft(2) pH - 9.0-9.5 To drill ahead, maintain the viscosity at initial levels to the base of the permafrost (800'-1000') then reduce the viscosity as allowed based upon actual hole cleaning requirements. A funnel viscosity of 50 - 80 sec/qt may be suitable by the 12 1/4" TD. It should be noted that the actual mud viscosity requirements will vary in this area based upon the actual amount of surface gravel present at each specific location. However, generally only minimum gravel has been noted in this area allowing successful drilling with reduced viscosities. 2.) Due to concerns for gas below the permafrost and to reduce barite mixing activities during spud operations, spud the well with a 10.0 ppg mud weight and basically hold that mud weight to TD of the 12 1/4" surface hole at 1800'. While there is some mud weight latitude from spud to the base of the permafrost at 800'-1000', the mud weight should be a solid 10.0 ppg by the base of the permafrost then held at that weight to the 12 1/4" TD (or as dictated by actual hole conditions). 3.) PAC treatments can be initiated toward the 12 1/4" TD for improved well bore stabilization by reducing the API filtrate to 8-10 cc's. RECEivbu DEC 2 8 ]995 Page - 1 Alaska Oil & Gas ~,u~. · _ ! 4.) Circulate and short trip the hole prior to running the 9 5/8" casing. A light Desco-CF treatment will be useful to reduce the gel strengths of the mud prior to running the casing and cementing. Note: There should be adequate chemical treatment of the mud to insure rheological stabilization of the system prior to TOH to run the surface casing. As the cement contamination while drilling out of the surface casing on Alpine #1 created significant problems, extra focus should be made to insure this problem does not recur. Condition the mud prior to TOH to run the surface casing and then again after the surface casing has been landed and the rig is circulating the hole prior to the actual cement job itself. Target a pretreatment of 2 ppb Bicarb and 1 ppb PH6 with .5 ppb Therma-Thi~ (pilot test for specific treatments) to minimize the effects of the cement contamination when drilling out. When drilling out, continue with bicarb treatments to remove the excess calcium, add PH6 (citric acid) as required to neutralize the pH and treat with thinners as needed for rheological stabilization. 5.) Maximum utilization of solids control equipment is recommended throughout surface hole drilling operations to keep the sand content less than 1% by volume and improve overall drilling conditions. II. 8 1/2" Hole (From 9 5/8" Shoe to Top Zone of Interest): Again, assuming normal spud operations and a salvageable spud mud, the plax is to clean-up the spud mud as required while NU on surface casing and drill ahead with the conditioned spud mud into the 8 1/2" hole. The syste~ will be maintained as a standard fresh water gel/PAC LSND system (as done on the Alpine #iA and #lB sidetracks) for this interval of the well. Mud treatments should be based on an as needed basis for the 8 1/2" hole. 1.) The important initial properties for the initial 8 1/2" hole would include a neutral pH in the 8.5 to 9.0 range, YP in the 10-15 lbs/100 SF range and an API filtrate in the 6-8 cc range. The initial funnel viscosity should be in the 40 to 50 sec/qt range or as dictated by actual well bore conditions. For drill-out, the initial mud weight requirement is for a 9.8-10.0 ppg mu¢ weight. As drilling continues in the 8 1/2" hole, the mud weight should be increased on an as needed basis with barite. The maximum mud weight for the 8 1/2" hole should be in the 10.2 - 11.0 ppg range. To reduce or control the mud weight while drilling ahead, maximize the solids control equipment efficiency and dilute with fresh water as required. Some rig site solids analysis will be required to identify the best mechanism for overall solids control. 2.) The viscosity of the mud in the 8 1/2" hole can be sustained with additions of Aquagel and extender and/or PAC treatments. Xanvis or Biozan can also be used to provide good LSRV support on an as needed basis. These viscosity treatments should be based upon actual hole cleaning requirements. ~5~5~V~-U Page - 2 DEC 2 8- '1995 Alask~ Oil & Gas Con~. Commi~.qm An~hnr~ POOL ARCTIC ALASKA RIG #6 DRILLING FLUID SYSTEM RECEIV u DEC 2 8 ~995 .Aiaska Oil & Gas L;ons. Anchorage REGEI¥~u DEC 2 8. ~995 AJaska Oil & Gas Cons. Commission ,A. nchor~e DRILl FR'S DOGHOUSE I I rLOO. I 150 BBL MUD/I/t/ATER SI'ORA~E TANK 225 BBL ~JUD/WATER STORAGE TANK 225 BBL CENTRIFUGE PIT II1111 sc~ MOTOR CONTROL CENTER , JHIJ · 150 BBL /'J~~-'~- 1't0 BBL PILL Pi'T VOLUME PIT J ................. ~ 140 BBL SUCTIO~ PI7 .......... PRESSURE ANALYSIS ARCO NEVE #1 (Per 20 AAC 25.005(c)(7), as required in 20 AAC 25.033(e)) RECEIV L Anchorage -1000 SURFACE CASING 1800' -2000 -3000 -4000 -r -5000 I,-- I,LI ~ -60OO I--, -7000 -8000 -9000 -10000 ARCO NEVE #1 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT ...... ' ....... ~' '1 ...... l ............... iii i .................. i ...... ? ......... i'"'"'?'"'i i i i !!!ill iii !I .... I ~ ...... MI..!_,.!! ......... ,, .._[!1 ,...!....! !_._~.!_!____~.._..~......~ '- ........... ~ .............. ' ............. '"'""'""' ~"~'"'~ .... ' ..... ...... i -' i" ~ i .......................... · ................. i--"~ ...... I-'-T-"-'?'"'~""T'-"?'~ f'"'"'"'-~ ..... r ~ ....... -.._F_i_ i -- [1i ! F-I""]I I '.]1 .... , ....... ~ ..... ~li ,-i~ .......... ~ ....... r----i~ ............. ~ ~-"-"i'-'"'il i~ ............... ~ I ..... ~~ ~ i ' i i' ~ ~ Ix I , iI I ~ ~ ' 1 K-5 ~ ~ ' ......... ~ "i i ...... i~ ..... i:~--~ .... ..1 ~[, ~ ~'/.. ~1 .... [, i ,, "'"' '. ~ ' ' .... ..... ! ~ ~ ....... ~ ~ : ~ ~'i .... ~ ~" ..... ....... - 8 9 10 11 12 13 14 15 16 17 18 EQUIVALENT MUD WEIGHT (LB/GAL) -1000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 -10000 ARCO ALPINE #1, lB MUD WEIGHT CURVE JANUARY 1995 ' :. =~ .... :- .~ .~. ~. .1 I 'L......i . i ..~ ,' -, _ ; .......... ........... ~ ~ ~ ~ : ~ ................... I...L.....L.f i ~ ~ ' ..~ ..... ~ ...... t_..L...L..~ ~ ..... ~ ...... : ~"~:-: :: ....... AZ?,~,~lff~ :[ i_] i !:~ ..i.._..~::i:~ iL.i!! ..... 'Li !.!.....i3.....L..[ J I :i:_: .... ..... i~ili '.~ i._.LJ. ~i! .... ',:i-~ ~.i...:!: !fl.} i/i! Ii!..... i .......... A~PINE¢IBMW %; [ I I ..... , ...... ..... : . ....... ......... f , ..... 1' I...~-'7: ~I~ ......... ~, i17 ...... ....... ~ ~i 1 ":' .~_.. ,..! .. I ...... t i C~=r~~,,~:~"'., '"" :: ' ' ii ..... i , i" "P~~~i~i~'~ie~i~ I~ ' .......... ~"'". I" ~"-'. ..... i..~.i [ i .... L I , .. ....... 8 9 10 11 12 13 14 15 16 17 18 MUD WEIGHT (LB/GAL) -1000 -2000 -3000 -4000 -5000 -6000 -7OOO -8000 ARCO BERGSCHRUND MUD WEIGHT CURVE MARCH 1994 8 9 10 11 12 13 14 15 16 17 18 Bt.lB WEIGHT LB/6AL Pore Pressure Prediction for the Neve #1 Well (WKE92-02) correlated to the Alpine #1 Well. The following summarizes the pore pressure work done in the Colville area using the above data. The wireline sonic data was used to predict the pressure in the Alpine #1 well; and the seismic velocity was used for the seismic line. There are no large pressure anomalies at this well or seismic line. Seismic Processing: The accuracy of Geopressure prediction is highly dependent upon the accuracy of the seismic stacking velocity field that is used as input. This velocity field is generated by picking velocities at every 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 every CDP location. The RMS velocities that are output have been smoothed over 300 ms vertically and 150 CDPs horizontally to normalize any instabilities in the velocity field that might result from noise, lack of signal, or variations in CDP fold. Pressure Prediction Procedure: ARCO's PPFG software was used to calculate the pore pressures. These were the steps taken to calculate the pressures: 1) The Gamma Ray log from the Alpine #1 well was used to distinguish the sand intervals from the shales. 2) 3) 4) A Normal Compaction Trend Line (NCTL) was determined in the shales from the wireline sonic data for the Alpine #1. This line indicates the predicted sonic value if these shales were normally compacted (no pressure). If the sonic delta T increases past the compaction line, (this change is AAT), then there is an indication of an increase in pressure. Using the mud weight data from the Alpine #1 and Bergschrund #1 wells, a Translational Trend model was developed to convert the AAT to equivalent mud weight (PP). This equation is · PP = C2 * AAT 2 d-C1 * AAT + Co where C2 = -1.34 e-05; C1-' .0062; Co = .465 This NCTL and Translational Trend was used for the seismic line. RECEIV u DEC 2 8- 1995 .Alaska Oil & Gas Cons. Commission ~chorage Alpine #1 Figure #1 is the pore pressure plot from the wireline sonic data. The curves from left to right are: 1) The black curve is the sonic log. The green dots are the shale 2) 3) 4) 5) 6) 7) intervals. The red line is the Normal Compaction Trend Line. The blue curve is the pore pressure. The green curve is the actual drilling mud weights. The red curve is the fracture gradient. The points labeled "pressure" are RFT measured pressures in equivalent mud weight. "LOT" is the leak off test in equivalent mud weight. There are no major pressure intervals in this well. There are some minor ones at 2000' and 3800' where the mud weights may need to be increased to 10 ppg. At 6800', there is an increase in the sonic AT which is attributed to the kerogen in the shales. This can be seen on the Gamma Ray increase on the logs. Since there was only one leak off test, it was difficult to create a fracture gradient curve. A Gulf of Mexico trend curve was used in this model and appears to be pessimistic. WKE92-02 (Neve #1) Figure #2 is a plot of the change in velocity verses depth for each CDP. The curves to the right shows the tie-in of the wireline sonic (black curve) of the Alpine #1 well (CDP 2730) to the seismic Travel Time (red curve, ITT). The green line is the NCTL. The ITT is higher than the sonic (EDT). This will make the pore pressure at CDP 2730 too high by 1.0 ppg when compared to wireline. Figure #3 shows at CDP 2480 the ITT overlays the NCTL very well at 2000'. Figure #4 shows the same good overlay at CDP 2530. Figures #5 and #6 show there is no pressure above 7500' for CDPs 2480 and 2530. The pressure deeper than 7500' may be due to the kerogen in the shales or lithology changes. The color plot is pore pressure verses depth for each CDP. Figure #7 is the pore pressure plots over the seismic interval verses depth and Figure #8 is verses time. RECEIVi::u DEC 2 8- 1995 Anchorage ~000 2000 3000 400C $00{ ?000 8000 846240 60 80 ~TL ~ ~ ~L = ~ ~g ~8 39 20 5000 6000 ?000 8000 8462 2/05/95 Ray WydFmski Scale: Verlical I m= 1679fl, Horizx}nlal I in= 184 cdp CDP 0000 ~ ~ ~ 22223 83 3 SPI24DPI265 2 2 2 2 4 4 4 5 2 5 8 3 5 0 0 0 ALPINE1 2222222 2222222223 5666677 7888899990 7(125703 70257(12570 5050500 5050505050 usec/ft Prclject Name: COLVILLE_AA~ Cross Section: WKE92-02 ITl' DataSel: VELF_DT CDP 2730 Well: ALPINE] Tm~d line "" -' Sonic EDT Feet (Datum sel to MSL) MSL40 60 80 [00120 160 D E P T H 1250.0 25{×}.0- 3750.0- 5000.0- 6250.0' 180.0 170.0 2500 160.0 150.0 130.0 3750 1200 90.0 5000 80.0 70.0 60,0 50.0 40.0 625(I 75(×).0 8750.0 100000 ~,AR¢O Explomti©~ mhd Production Technology ~ Pore Pressure and Fracture Gradient System ] ~2/05/95 P. ay Wydrinski Scale: Verlical I in = 1679 ft, Horiz~)nlal I itl = 184 cdp TF.S'[x)202 SP1243~P~ 265 ALPINEt ~¢ 2 2 22 2 22222222222 2 2 222222 2 2222222223 CDP[~iOOl 1 1 222233334444 5 566667 7 7888899990 025702 6 02570257025 8 3 702570 3 7025702570 35 0 5 0 5 0 0 5 0 5 0 5 0 5 05 0 0 0 5 0 5 0 5 0 Q ~ 0 ~ O 5 0 5 0 5 0 MSL 0.0' Projecl Name: COLV)LLE_AA~ Cross S~lion: WKE92-02 ITl' DataSet: VELF_DT usec/fl CDP 2480 Well: SP1240 Trend L~e ---- ITF Feet (Datum set to MSI0 MSL40 60 80 ~00 120 160 1250.0' 2500/) D 3750,0- E P T H (fl) 50~).0- 6250.0~ 250 3750 5000 75(X).0 8750.0 Pore Pressure and Fmct m Gradient System 2/05/95 Ray Wydr nsk S~le: Vertical I in: ~679 ft. JJoFJzDt/i3} ~ ~I} = ]84 cdp TI:~ST9202 SP124~' 1265 ALPINE1 99 9 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 3 CDP55~o~ i t 222233334444 q 5666677 7888899990 025702 6 02570257025 8 3 702570 3 7025702570 0 5 0 q 0 0 5 0 5 0 5 0 s 0 5 0 0 0 5 0 5 0 5 (1 0 5 0 5 0 5 0 5 0 5 0 usec/ft Plx)jecl Name: COLV[LLE_AA[ Cross S~nm~: WKE92-02 FIT DalaSet: VELF_DT CDP 2530 Well: SP1265 I've ~d Lb~e &/ F~t (Datum set to MSL} MSL40 60 80 10012/) 160 1250.0 D 3750.0- P T H (f0 62511.0- 1250 3750 5000 7500.0 8750.0 00[)00 t(~)001 ARCO Exp~omtion ~nd Production Technology p,-oj~,, N~,.~: COLVlLLE_AA~ ~Pore Pressure and Fracture Gradient System pp DataSct: PLE~$18045_PPG _12/05/95 R~ay Wydrinski s~de: Vertical [ in = 1679 ti, HoriTx>lllal I i~l = [84 cdp TEST9202 SP124,%)P1265 ALPINEI ~,.... 22 2 2 2 2 2 2 2 2 2 2 2 2 Z 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 3 00 I I I 2 2 22 3 3 3 3 4~ 4 4 5 5 6 66 6 7 7 7888899990 02 5 7 0 2 6 0 2 5 7 0 2 5 7 0 2 5 8 3 7 0 2 5 7 0 3 7 0 2 5 7 0 2 5 7 0 350505 0 05050505050 0 0 505050 0 5050505050 MSL 0,0 1250.0 2500.0 3750~0 50(Yd.0' 6250.0' D E P T H (fi) PPg 8.(~1 8.50 9.00 9.50 I 0.5(} [ 1.50 8750.0- Melhod: Trend Curve NCTL: $89202 ~80 45 MoOch PUESTOCENE 1250---- 25(KI 3750 PPG curve S CDP~,,8( ~' ~' ' (Datum set to MSL) 16 18 20 Pore Pressure and Fracture Gradient System Pro. Nci Name: COLVILLE_AA[ Cross Section: WKE92-02 PP mtaSet: PLEIS18045_PPG D E P T H 12/05/95 Ray Wvdrinski 22 2 2 22 2 2 2 22 2 22 2 22 2 2 2 2 2 2 CDP00001 i I 22223333444 4 5 566 025 7 02 6 0 2 57 0 25 7 02 5 8 3 702 35 0 5 05 0 0 5 05 0 50 5 05 0 0 0 505 MSL0.0 ALPtNEI 222 2222222223 677 7888899990 703 7(125702570 500 5050505050 PPg 8.00 Method: Trend Curve NCTL: SS9202 180 45 Modal: PLIESTOCENE Feet (Datum set to MSL) MSL8 I0 12 [4 16 18 20 9.00 250,0 i 9.50 1250 0.50 25FY).0 - 12.00 12.50 1 13.50 37500- 14.00 3750 15.50 5000 16.50 17.50 6250.0- 18.50 6250 75(K},0 87502) E×p omt om end Production Technology Prqiect N~me: COLV~LLE_AA{ Pore Pressure and Fracture Gradient System Cro~s section: WKE92-02 I 2/05/9~5 Ray Wydrinski PP DataSeI: PLEIS18045_PPG Seismic Dataset: WKE92-02_Z TES'F)202 SP[240 SPf265 ~ ~ 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 CDP b ~ 0 0 0 i i i ~ ~ 2 2 2 2 2 3 3 3 3 3 4 4 4 4 4 5 5 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 2 4 6 8 0 3 ~ o o o o o o o o o o o o o o o o o o o o o o o o o MSL 0.0 I250.0 Me[hod: Trend Curve NC~: SS9202 180 45 Modeh PLIESTOCENE D 3750~0 E P T H fit) 50fK).0 6250.0 ALPINEI 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 3 5 5 6 6 6 6 6 7 7 7 7 8 8 8 8 8 9 9 9 9 9 {) 6 8 0 2 4 6 8 0 3 6 8 0 2 4 6 8 0 2 4 6 8 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 PPg 8,(X) 8.50 9.00 9.50 8750.0- 100()0.0 T I M E ARCO xp omtio and Productio COLV~LLE_AAI Sectkm: WKE92-02 Pore Pressure and Fracture Gradient System PP DataSeh PLEIS18045_PPG_T Seismic Dataset: WKE92-02 2/05/95 Ray Wydri nski TEST9202 SPI240 SP1265 ALP[NEI '~ 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 CDP 80000 ~ i i ~ i 22222 3 333 3444445 q 55666667 7 77 88 02 .468024680246802468024680 !~ 6802 ,i 680 3 *o 99oo oo 09000000000oo00 o o o o o oo oo o Method: NCTL: $89202 180 45 Modeh PL[ESTOCENE 250.0 500.0 750.0 100%0 250.0 222222223 888999990 6802468024680 0 00000000000 PPg 8.50 9.50 ~0.00 10.50 12.50 13.50 14.50 f51X).0 1750.0 ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 27, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Neve #1 Dear Commissioner Johnston, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the ARCO Neve #1, on State lands near the mouth of the Colville River. ARCO will act as operator for itself, Union Texas Petroleum and Anadarko Petroleum Corporation in evaluating acreage previously leased by ARCO in Lease Sale 75 in December, 1992 from the State of Alaska and the Arctic Slope Regional Corporation. The proposed well location is approximately 2 miles southwest of the ARCO Alpine #1 drilled last winter. The wellsite will be accessed via ice road originating at KRU 2M Pad. ARCO plans to use Pool Arctic's Rig No. 6 to drill this well from an ice pad during the winter of 1995-96. Attached find the information required by 20 AAC 25.005(c) and 20 AAC 25.061. All waste drilling mud and cuttings generated during the drilling of Neve #1 will be hauled to either the Kuparuk River Field or Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be at the base of the Nuiqsut Formation which directly underlies the Kuparuk Formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. ARCO also requests an exception to the shale density requirement in 20 AAC 25.033(e,2,D). The shale density technique does not work well in Alaska due to the variable composition of the shales and the chemical used in the shale density column is listed as an exceptional health hazard. The Commission is requested to keep confidential the following attachments to this permit application which are drawn from research and data proprietary to ARCO Alaska, Inc.: Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program RECEIVEu DEC 2 8 995 Naska Oil & Gas Cons. Commission Anchorage ARSB-6003-93 242-2603 Finally, the following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Weekly Status Report Fred Johnson, Drilling Engineer 265-1492 2) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 265-1492 3) Geologic Data and Logs (20 AAC 25.071) Mark McDermott, Explorationist 265-6394 If you have questions or require additional information, please contact Fred Johnson at 265-1492 or myself at 265-6206 in our Anchorage office. Sincerely' I e Development RECEIV!:::u DEC 2 8 1995 AJaska Oil & (.~ ~,~..,.~,,,'~ission Anchorage COMPANY dev [] redrll [] serv [] ON/OFF SHORE wellbore seg O ttached .................. ~ N appropriate ............... ~ N name and number .............. ~ N in a defined pool .............. Y proper distance from drlg unit boundary. . .Y proper distance from other wells ..... ~ N creage available in drilling unit ..... ~ N is wellbore plat included ......... Y~ N /%~,~ , y affected party .............. ~ N appropriate bond in force ......... e issued without conservation order ..... Y e issued without administrative approval.. e approved before 15-day wait ........ Y REMARKS / -',3 ' /' /I" ' .,' I --' / ;ring provided ............... .ng protects all known USDWs ........ 'uate to circulate on conductor & surf csg. .'uate to tie-in long string to surf csg . . 'er all known productive horizons ...... ,ns adequate for C, T, B & permafrost .... lkage or reserve pit ............. .1, has a 10-403 for abndnmnt been approved. .lbore separation proposed ......... required, is it adequate .......... lid program schematic & equip list adequate Ite ..................... :ating adequate; test to ~d~ psig. ~ld complies w/API RP-53 (May 84) ....... ~cur without operation shutdown ....... of H2S gas probable ............. 3e issued w/o hydrogen sulfide measures... ~j N ;ed on potential overpressure zones .... ~ N £ysis of shallow gas zones ......... N ition survey (if off-shore)for reports ........./~/Y NN ~/~/'~~ /~. ~/;~' /' ~/phone weekly progress ..... f~f [exploratory only] COMMISSION: ........... JDN Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . * . ............................ * ....... SCHLUMBERGER * ............................ * COMPANY NAME : ARCO ALASKA INC. WELL NAME : NEVE #1 FIELD NA~4E : WILDCAT BOROUGH ' NORTH SLOPE STATE : ALASKA API ~ER : 501032023100 REFERENCE NO : 96097 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/14 ORIGIN . FLIC REEL NAME : 96097 CONTINUATION # : PREVIOUS REEL COb~IENT . ARCO ALASKA INC. , WILDCAT, NEVE #1, API# 50-103-20231-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/14 ORIGIN · FLIC TAPE NAME : 96097 CONTINUATION # : 1 PREVIOUS TAPE : C03~ENT : ARCO ALASKA INC., WILDCAT, NEVE #1, API# 50-103-20231-00 TAPE HEADER WILDCAT MWD CDR AND CASED HOLE WIRELINE LOGS WELL NAME: NEVE #1 API NUMBER: 501032023100 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 14 -APR- 96 JOB NUMBER: 96097 LOGGING ENGINEER: SCHWARTZ OPERATOR WITNESS: SCARBROUGH SURFACE LOCATION SECTION: 14 TOWNSHIP '. 1 iN RANGE: 4E FNL : 465 FSL: FEL : FWL: 2440 ELEVATION (FT FROM MSL O) KELLY BUSHING: 44.30 DERRICK FLOOR: 42.80 GROUND LEVEL: 12. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 7679.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: 1 PASS NUMBER: 1 DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH $ RE~ARKS: .......... EQUIVALENT UNSHIFTEDDEPTH .......... THE DATA ON THIS TAPE WAS ACQUIRED ON ARCO'S NEVE #1. THE DATA IS A MODIFIED LDWG FORMAT AS PER INSTRUCTIONS FROM WAYNE CAMPAIGN. THE DATA SET CONSISTS OF ANADRILL'S CDR (OPENHOLE) AND SCHLUMBERGER WIRELINE CASED HOLE CNTG/CBL/CET/CCL BEFORE AND AFTER SQUEEZE. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCRE~fENT: 0.5000 FILE SU~IARY LDWG TOOL CODE START DEPTH STOP DEPTH CNTG 7538.0 6850.0 CDR 141.0 7249.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NURiBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH CNTG CDR LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: REMARKS: THE DATA IN THIS FILE IS OF ANADRILL'S MEASO-REMENT WHILE DRILLING CDR RESISTIVITY AND PASS #1 OF SCHLUMBERGER WIRELINE CASED HOLE CNTG BEFORE SQUEEZE. THE CDR IS THE DEPTH STANDARD AND THE FIRST PASS CNTG BEFORE SQUEEZE WAS TIED TO IT ON LOCATION AND DOES NOT REQUIRE DEPTH SHIFTING. ALL OTHER CASED HOLE CNTG PASSES WILL BE DEPTH CORRECTED TO THE 1ST PASS CNTG BEFORE SQUEEZE. $ LIS FORMAT DATA TABLE TYPE : CONS TONI VALU DEFI CN ARCO ALASKA INC. Company Name FN WILDCAT Field Name WN NEVE #1 Well Name APIN 501032023100 API Serial Number FL 2440 FWL 0465 FNL Field Location SECT 14 Section TOWN 1 iN Township RANG 4 E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN SCARBROUGH Wi tness Name SON 50033 Service Order Number PDAT MSL Permanent da turn EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 44.3 Above Permanent Datum EKB FT 44.3 Elevation of Kelly Bushing EDF FT 42.8 Elevation of Derrick Floor EGL FT 12. Elevation of Ground Level TDD FT 7591. Total Depth - Driller TDL FT 7585. Total Depth - Logger BLI FT 7538. Bottom Log Interval TLI FT 6596. Top Log Interval DFD G/C3 10.3 Drilling Fluid Density RMS OH~4~ 2.21 Resistivity of Mud Sample MST DEGF 71. Mud Sample Temperature RMFS OHT~4 2.08 Resistivity of Mud Filtrate S MFST DEGF 75. Mud Filtrate Sample Temperatu BHT DEGF 135. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: TABLE TYPE : CURV DEFI Depth Neutron Porosity Epithermal Neutron Porosity COMPENSATED NEUTORN POROSITY (TOOL, CAL, AND ENV CORR) Neutron Ratio (ND/FD) Cementing Rate Epi thermal Neutron Ratio Calibrated DEPT NPHI ENPH CPHI NRAT CRA T ENRA NCNT FCNT CNTC CFTC CNEC CFEC GRCH TENS CCL GR FET ROP RP DER VRP Corrected Near Thermal Counts Corrected Far Thermal Counts Corrected Near Epi thermal Counts Corrected Far Epithermal Counts GA~A RAY IN CASING Tension CCL Ampli rude Gamma Ray TIME AFTER BIT RATE OF PENETRATION CDR ATTN RESISTIVITY CDR PHSF RESISTIVITY DIELECTRIC RESISITIVTY QRO VERY ENHANCED AMPLITUDE RESISTIVITY QRO VERY ENHANCED PHASE RESISITIVTY ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 50033 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 50033 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 50033 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 50033 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 50033 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 50033 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 50033 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG CAPI 50033 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 50033 O0 000 O0 0 1 1 1 4 68 0000000000 CR MWD GAPI 50033 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 50033 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 50033 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H1~150033 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0tt~50033 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 0H~450033 O0 000 O0 0 1 1 1 4 68 0000000000 V-RA MWD 0tt~M50033 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD 0H~50033 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. NRAT. CNTG FCNT. CNTG CFEC. CNTG GR.MWD RP.MWD 7538 000 2 805 510 354 550 002 -999 250 -999 250 DEPT. 89.000 NRAT. CNTG -999.250 FCNT. CNTG -999.250 CFEC. CNTG -999.250 GR.MWD 16.290 RP.MWD -999.250 NPHI.CNTG 26.147 ENPH. CNTG 30.363 CPHI.CNTG 26.716 CR~T. CNTG 2.837 ENRA.CNTG 4.698 NCNT. CNTG 1523.900 CNTC. CNTG 1459.287 CFTC. CNTG 527.059 CNEC. CNTG 2584.048 GRCH. CNTG -999.250 TENS. CNTG 2895.000 CCL.CNTG -0.002 FET.MWD -999.250 ROP.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG GRCH. CNTG -999.250 TENS.CNTG -999.250 CCL.CNTG FET.MWD -999.250 ROP.MWD -999.250 RA.MWD DER.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE . 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENO~IBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 7533.0 6834.0 CNTG 7538.0 6834.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88888.0 88887.0 7257.5 7256.5 7256.5 7256.5 7253.5 7253.0 7248.5 7249.0 7245.5 7245.5 7244.5 7244.0 7242.5 7241.5 7240.5 7240.0 7237.5 7237.0 7233.5 7233.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 7232.5 7232.0 7230.0 7230.0 7228.5 7227.5 7228.0 7228.5 7225.5 7226.0 7224.5 7224.0 7221.5 7221.5 7220.5 7221.0 7217.5 7216.5 7216.5 7216.0 7213.5 7213.5 7212.5 7212.5 7209.5 7209.0 7206.5 7205.5 7205.5 7204.5 7204.5 7204.5 7201 . 5 7200.5 7200.5 7200.0 7197.5 7197.0 7195.0 7195.0 7188.0 7188.0 7186.5 7186.5 7184.5 7184.0 7180.5 7180.5 7179.5 7178.5 7177.5 7176.5 7173.5 7172.5 7164.5 7164.5 7162.5 7163.0 7159.5 7159.5 7156.5 7156.5 7153.5 7153.0 7150.5 7149.5 7145.0 7145.0 7141 . 5 7140.0 7140.5 7140.0 7137.0 7136.0 7136.5 7136.5 7135.0 7134 . 5 7132.5 7132.5 7131.0 7129.5 7128.5 7128.0 7125.5 7124.0 7124.5 7124.0 7121.5 7121.5 7120.5 7119.0 7119.5 7118.5 7116.5 7116.0 7115.5 7115.5 7111.5 7113.0 7109.5 7110.5 7108.5 7108.0 7106.0 7105.0 7104.5 7103.0 7103.5 71 O1.5 71 O1.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 7100.5 7096.0 7095.0 7092.5 7092.0 7088.5 7087.5 7084.0 7082.0 7078.5 7077.0 7074.5 7073.0 7070.5 7069.0 7068.5 7066.0 7064.5 7064.0 7060.5 7056.5 7054 5 7053 5 7051 0 7050 0 7044 0 7041 0 7034 5 7033.5 7032.5 7029.5 7028.5 7026.0 7024.5 7024.0 7021.5 7020.0 7019.0 7016.5 7013.5 7005.5 7001.5 6998.0 6996.5 6993.5 6992.5 6989.5 6988.5 6985.5 6981.5 6968.5 6964.5 6961.5 6957.5 6953.5 7100.0 7092.0 7087.5 7084.5 7068.5 7063.5 7059.5 7056.0 7054.0 7052.5 7033.5 7028.0 6996.0 6992.5 6988.0 6968.0 6964.5 7095.5 7094.0 7089.5 7084.5 7081.5 7077.0 7076.0 7075.0 7073.0 7071.0 7068.0 7065.0 7063.0 7053 0 7051 0 7049 0 7043 5 7041 0 7035 5 7034 0 7029.5 7026.0 7025.5 7024. 0 7022.0 7021.5 7019.0 7016.5 7013.0 7007.5 7002.5 6996.0 6991.0 6987.5 6983.5 6979.5 6960.5 6956.5 6952.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 6950.0 6950.0 6948.5 6948.5 6948.0 6948.0 6947.0 6947.0 6946.5 6946.0 6944.5 6944.0 6942.5 6942.0 6937.5 6937.5 6932.5 6932.0 6929.5 6930.0 6928.5 6928.5 6928.0 6928.0 6927.0 6926.5 6924.5 6923.5 6924.5 6920.5 6920.5 6916.5 6916.5 6913.5 6913.5 6912.5 6912.0 6909.5 6908.0 6906.0 6905.0 6903.0 6902.0 6903.0 6901.5 6901.5 6900.5 6900.0 6897.5 6897.0 6890.0 6889.5 6884.5 6884.0 6884.0 6883.5 6881.5 6881.5 6880.5 6880.5 6877.5 6877.5 6876.5 6876.0 6868.5 6868.0 6867.0 6866.5 6856.0 6855.0 6855.0 6854.0 100.0 99.0 99.0 $ REMARKS: THE DATA IN THIS FILE IS OF SCHLUMBERGER WIRELINE CASED HOLE PASS #2 CNTG BEFORE SQUEEZE. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT ARCO ALASKA INC. WILDCAT NEVE #1 501032023100 2440 FWL 0465 FNL 14 Company Name Field Name Well Name API Serial Number Field Location Section LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 10 TUNI VALU DEFI TOWN liN Township RANG 4E Range COON NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN SCARBROUGH Wi tness Name SON 50033 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RK~ Log Measured From APD FT 44.3 Above Permanent Datum EKB FT 44.3 Elevation of Kelly Bushing EDF FT 42.8 Elevation of Derrick Floor EGL FT 12. Elevation of Ground Level TDD FT 7591. Total Depth - Driller TDL FT 7585. Total Depth - Logger BLI FT 7538. Bottom Log Interval TLI FT 6596. Top Log Interval DFD G/C3 10.3 Drilling Fluid Density RMS OH~M 2.21 Resistivity of Mud Sample MST DEGF 71. Mud Sample Temperature RMFS OH~ 2.08 Resistivity of Mud Filtrate S MFST DEGF 75. Mud Filtrate Sample Temperatu BHT DEGF 135. Bottom Hole Temperature TABLE TYPE : CURV DEFI Depth Neutron Porosity Epithermal Neutron Porosity COMPENSATED NEUTORN POROSITY (TOOL, CAL, AND ENV CORR) Neutron Ratio (ND/FD) Cementing Rate Epithermal Neutron Ratio Calibrated DEPT NPHI ENPH CPHI NRAT CRA T ENRA NCNT FCNT CNTC CFTC CNEC CFEC GRCH TENS CCL Corrected Near Thermal Counts Corrected Far Thermal Counts Corrected Near Epi thermal Counts Corrected Far Epithermal Counts GARff~A RAY IN CASING Tension CCL Ampl i tude LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 50033 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 50033 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 50033 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 50033 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 50033 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 50033 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 50033 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 50033 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 50033 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 50033 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 50033 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 50033 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 50033 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 50033 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 50033 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 50033 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7537.000 NPHI.CNTG 27.355 ENPH. CNTG 28.704 CPHI.CNTG NRAT. CNTG 2.984 CRAT. CNTG 2.903 ENRA.CNTG 4.526 NCNT. CNTG FCNT. CNTG 480.183 CNTC. CNTG 1426.629 CFTC. CNTG 514.628 CNEC. CNTG CFEC. CNTG 569.460 GRCH. CNTG -999.250 TENS. CNTG 2850.000 CCL. CNTG 26.767 1401.591 2577.415 -0.003 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 12 DEPT. 6833 . 000 NPHI. CNTG NRAT. CNTG 3. 680 CRAT. CNTG FCNT. CNTG 177.107 CNTC. CNTG CFEC. CNTG 313. 897 GRCH. CNTG 46.037 ENPH. CNTG 3.928 ENRA.CNTG 730.055 CFTC. CNTG 98.375 TENS.CNTG 51.047 6.528 194.317 2750.000 CPHI.CNTG NCNT. CNTG CNEC. CNTG CCL.CNTG 42.347 787.143 2049.210 0.008 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE · 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENOI~BER: 3 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREmENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2 CNTG $ REMARKS: THE DATA IN THIS FILE IS THE ARITH~ETIC AVERAGE OF WIRELINE CASED HOLE CNTG (PRE SQUEEZE) PASSES 1 AND 2. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-!996 10:55 PAGE: 13 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN WILDCAT Field Name WN NEVE #1 Well Name APIN 501032023100 API Serial Number FL 2440 FWL 0465 FNL Field Location SECT 14 Section TOWN 1 IN Township ~G 4E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN SCARBROUGH Wi tness Name SON 50033 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 44.3 Above Permanent Datum EKB FT 44.3 Elevation of Kelly Bushing EDF FT 42.8 Elevation of Derrick Floor EGL FT 12. Elevation of Ground Level TDD FT 7591. Total Depth - Driller TDL FT 7585. Total Depth - Logger BLI FT 7538. Bottom Log Interval TLI FT 6596. Top Log Interval DFD G/C3 10.3 Drilling Fluid Density RMS Otff4~ 2.21 Resistivity of Mud Sample MST DEGF 71. Mud Sample Temperature RMFS 05k4M 2.08 Resistivity of Mud Filtrate S MFST DEGF 75. Mud Filtrate Sample Temperatu BHT DEGF 135. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT NPHI NRAT CPHI CRA T ENPH ENRA NCNT FCNT CNTC CFTC CNEC CFEC GRCH Depth Neutron Porosity Neutron Ratio (ND/FD) COMPENSATED NEUTORN POROSITY (TOOL, CAL, AND ENV CORR) Cementing Rate Epi thermal Neutron Porosity Epithermal Neutron Ratio Calibrated Corrected Near Thermal Counts Corrected Far Thermal Counts Corrected Near Epithermal Counts Corrected Far Epithermal Counts GA~k4ARAY IN CASING LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 50033 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNAV PU-S 50033 O0 000 O0 0 3 1 1 4 68 0000000000 1VRAT CNAV 50033 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNAV PU-S 50033 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNAV 50033 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNAV PU-S 50033 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNAV 50033 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNAV CPS 50033 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNAV CPS 50033 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNAV CPS 50033 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNAV CPS 50033 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNAV CPS 50033 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNAV CPS 50033 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 50033 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 DEPT. 7537.000 NPHI.CNAV 27.325 lv-RAT. CNAV CRAT. CNAV 2.902 ENPH. CNAV 28.068 ENRA.CNAV FCNT. CNAV 479.210 CNTC. CNAV 1429.751 CFTC. CNAV CFEC. CNAV 576.455 GRCH. CNTG -999.250 DEPT. 6850. 000 NPHI. CNAV CRAT. CNAV 3. 989 ENPH. CNAV FCNT. CNAV 193. 749 CNTC. CNAV CFEC. CNAV 326. 266 GRCH. CNTG 47.154 NRAT. CNAV 49.035 ~.CNAV 742.433 CFTC. CNAV 81.688 2.992 CPHI.CNAV 4.459 NCNT. CNAV 519.135 CNEC. CNAV 4 . 167 CPHI. CNAV 6.373 NCNT. CNAV 187. 639 CNEC. CNAV PAGE: 15 26.500 1469. 938 2569. 739 45.710 784.250 2079.135 ** END OF DATA ** **** FILE T~AILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE1VTuT~BER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCRE~fENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 7520.0 6598.0 CNTG 7534.0 6598.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS--ER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APRil996 10:55 PAGE: 16 BASELINE DEPTH 88888 0 7257 5 7256 0 7254 0 7253 5 7252 5 7250 0 7248 5 7248.0 7245.5 7244.5 7238.0 7236.5 7233.5 7232.5 7230.5 7228.5 7225.5 7224.5 7221.5 7220.5 7217.5 7216.5 7213.5 7212.5 7208.5 7205.5 7204.5 7201.5 7200.5 7197.5 7196.5 7193.5 7191.0 7189.5 7188.0 7185.5 7182.5 7180.5 7177.5 7176.5 7173.5 7172.5 7169.5 7168.0 7164.5 7157.5 7156.5 7154.0 7145.5 7141.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.5 88887.0 7257.0 7256.5 7255.5 7253.0 7251.0 7248.0 7243.5 723 6.0 7231.0 7226.5 7223.5 7219.5 7216.0 7211.5 7208.0 7204.0 7200.5 7196.0 7180.0 7175.5 7172.0 7168.0 7164.0 7158.5 7155.0 7253.0 7250.0 7248.5 7245.0 7237.0 7233.5 7230. 5 7225.0 7221.5 7217.0 7214.0 7209.5 7205.0 7202.0 7197.0 7193.0 7190.5 7188.0 7186.5 7185.0 7180.5 7177.5 7176.0 7172.0 7168.5 7156.0 7155.0 7144 ~ 0 7139.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 17 7140.5 7140.0 7138.5 7137.0 7134.5 7134.5 7132.5 7133.0 7132.5 7128.5 7129.0 7125.5 7125.0 7124.5 7124.5 7114.5 7116.5 7106.0 7106.5 7101.0 7103.0 7098.5 7098.0 7097.5 7096.5 7096.5 7095.5 7093.5 7093.0 7092.5 7092.0 7089.5 7089.5 7088.5 7088.5 7084.5 7084.0 7084.0 7084.5 7083.0 7081.5 7080.5 7080.5 7077.5 7076.0 7075.5 7075.0 7074.0 7073.0 7071.5 7071.5 7069.5 7069.0 7069.0 7068.5 '7067.0 7068.0 7065.5 7064.0 7065.0 7066.0 7062.5 7063.5 7055.0 7054.0 7054.0 7053.5 7048.5 7048.0 7046.5 7045.0 7045.0 7043.5 7044.0 7043.5 7043.5 7042.5 7041.5 7040.5 7040.5 7040.5 7037.5 7036.0 7034.5 7032.0 7030.5 7029.5 7027.5 7028.5 7026.5 7024.5 7027.0 7024.5 7023.5 7024.0 7020.5 7020.0 7021.5 7018.0 7019.5 7016.5 7015.5 7015.5 7015.0 7013.5 7012.5 7012.5 7011.5 7012.0 7011.5 7009.5 7008.5 7008.5 7006.5 LIS Tape Verification Listing Schlumberger Alaska Compu ting Cent er 14-APR-1996 10:55 PAGE: 18 7007.5 7006.0 7005.0 7003.5 7004.5 7003.5 7003.0 7002.0 7000.5 7000.5 6997.5 6996.5 6996.5 6995.5 6994.0 6992.5 6983.5 6982.5 6982.0 6981.5 6981.5 6980.5 6980.5 6979.5 6979.5 6979.5 6976.5 6976.0 6975.0 6975.5 6973.0 6970.5 6969.5 6967.0 6969.0 6968.5 6965.5 6965.5 6964.5 6963.0 6959.5 6960.0 6959.0 6960.0 6958.5 6958.0 6958.0 6959.0 6957.0 6955.5 6952.0 6951.5 6949.5 6948.5 6947.5 6947.0 6944.0 6943.5 6943.0 6942.0 6941.5 6940.5 6940.5 6940.0 6939.5 6939.0 6936.5 6936.5 6933.5 6932.0 6932.5 6932.0 6931.0 6930.0 6928.5 6928.0 6926.5 6926.5 6924.5 6923.5 6924.0 6920.5 6919.5 6916.5 6916.0 6916.0 6916.0 6913.5 6913.5 6912.5 6912.0 6908.5 6907.5 6908.0 6906.5 6896.5 6895.5 6893.5 6892.5 6892.5 6892.0 6889.5 6889.0 6885.5 6885.0 6884.5 6884.0 6880.5 6879.5 6876.5 6876.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 19 6874 0 6870 0 6868 5 6859 0 6854 5 6852 0 6846 5 6837 5 6830 0 6828 0 6809 0 6808 0 6795 0 6780 0 6774 5 6774 0 6767 0 6763 5 6756 5 6741 0 6732 0 6726.0 6724 0 6681 0 6672 0 6668 5 6665 5 6662 0 6648 5 6648 0 6627 0 6604 0 6603 5 100 0 $ 6873.5 6867.5 6858.5 6846.0 6827.5 6807.5 6794.0 6779.0 6774.0 6767.0 6740.5 6724.0 6668.5 6648.5 6604.0 100.5 6873.5 6869.0 6854.0 6852.0 6835.5 6828.5 6809.0 6779.0 6774.0 6762.5 6755.0 6732.0 6725.5 6680.0 6672.5 6668.0 6663.0 6648.0 6627.0 6603.5 99.5 REMARKS: THE DATA IN THIS FILE IS OF WIRELINE CASED HOLE CNTG (AFTER SQUEEZE) PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG ARCO ALASKA INC. WILD CA T 501032023100 2440 FWL 0465 FNL 14 liN 4E Company Name Field Name Well Name API Serial Number Field Location Section Township Range LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 20 TUNI VAL U DEFI COUN NORTH SLOPE STAT ALASKA NATI USA WITN SCARBROUGH SON 50033 PDAT MSL EPD FT O . LMF RKB APD FT 44.3 EKB FT 44.3 EDF FT 42.8 EGL FT 12. TDD FT 7591. TDL FT 7585. BLI FT 7538. TLI FT 6596. DFD G/C3 10. 3 RMS OH~4M 2.21 MST DEGF 71. RMFS OH~4M 2.08 MFST DEGF 75. BHT DEGF 135. County State or Province Nation Wi tness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Bottom Hole Temperature TABLE TYPE : CURV DEFI Depth Neutron Porosity Epithermal Neutron Porosity COMPENSATED NEUTORN POROSITY (TOOL, CAL, AND ENV CORR) Neutron Ratio (ND/FD) Cementing Rate Epithermal Neutron Ratio Calibrated DEPT NPHI ENPH CPHI NRAT CRA T ENRA NCNT FCNT CNTC CFTC CNEC CFEC GRCH TENS CCL Corrected Near Thermal Counts Corrected Far Thermal Counts Corrected Near Epi thermal Counts Corrected Far Epithermal Counts GAMMA RAY IN CASING Ten s i on CCL Amplitude LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 50033 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU-S 50033 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU-S 50033 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNTG PU-S 50033 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNTG 50033 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNTG 50033 O0 000 O0 0 4 1 1 4 68 0000000000 EAU~ CNTG 50033 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNTG CPS 50033 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNTG CPS 50033 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTG CPS 50033 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS 50033 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNTG CPS 50033 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNTG CPS 50033 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 50033 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTG LB 50033 O0 000 O0 0 4 1 1 4 68 0000000000 CCL CNTG V 50033 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 7533.000 NPHI.CNTC 45.381 ENPH. CNTC 31.075 CPHI.CNTG NRAT. CNTG 3.963 CRAT. CNTG 3.892 ENRA.CNTG 4.771 NCNT. CNTG FCNT. CNTG 231.701 CNTC. CNTG 919.704 CFTC. CNTG 239.385 CNEC. CNTG CFEC. CNTG 486.279 GRCH. CNTG -999.250 TENS.CNTG 3030.000 CCL.CNTG 43.770 925.506 2319.975 -0.002 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 22 DEPT. 6597.500 NPHI.CNTG 39.249 ENPH. CNTG NRAT. CNTG 4.172 CR~T. CNTG 3.556 ENRA.CNTG FCNT. CNTG 240.740 CNTC. CNTG 890.594 CFTC. CNTG CFEC. CNTG 378.002 GRCH. CNTG -999.250 TENS.CNTG 41.832 CPHI.CNTG 5.779 NCNT. CNTG 245.491 CNEC. CNTG 2760.000 CCL.CNTG 40.208 950. 718 2184. 471 - O. 021 ** END OF DATA ** **** FILE TRAILBR **** FILE NAME : EDIT .004 SERVICE ' FLIC VERSION · O01CO1 DATE · 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iV-JMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREmENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 7520.0 6596.0 CNTG 7534.0 6596.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 23 88888 7257 7253 7251 7249 7248 7245 5 7244 5 7240 5 7240 0 7236 5 7232 0 7230. 5 7224.0 7223.5 7218.0 7217.5 7214.0 7213.5 7210.5 7209.5 7206.5 7204.5 7198.0 7194.0 7191.5 7187.0 7179.5 7178 5 7175 0 7172 5 7171 0 7169 0 7168 5 7166.0 7164.5 7162.0 7161.5 7160.5 7159.0 7157.0 7156.5 7152.5 7152.0 7149.5 7145.5 7143.5 7142.0 7140.5 7136.5 7135.0 7133.5 7132.5 7129.5 7128.5 0 88887.5 88887.5 5 7257.0 5 7253.0 0 7251.0 5 7248.5 5 7248.0 7244.5 7240.5 7235.5 7223.5 7216.0 7213.0 721 O. 0 7197.0 7178.0 7172.0 7170. 5 7168.0 7164.0 7159.0 7154.5 7150.5 7139.5 7136.0 7132.0 7129.0 7245.5 7239.0 7232.5 723 O. 5 7223.5 7217.5 7214.0 7209.0 7205.5 7204.5 7197.0 7193.5 7192.0 7188.0 7180.0 7174. 0 7168.0 7165.0 7162.5 7161. 0 7159.5 7156.5 7150.5 7148.5 7144.0 7142.5 7139.0 7134.5 7132.0 7127.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 24 7124.5 7121 0 7113 5 7109 5 7105 5 7104 5 71 O1 5 7100 5 7097 5 7096.5 7093.5 7092.5 7089.5 7088.5 7083.0 7080.5 7076.5 7075.0 7074.0 7072.5 7069.5 7067.0 7064.5 7064.0 7061.5 7060.5 7058.5 7056.5 7054 0 7053 0 7049 5 7048 5 7046 5 7044 5 7044.0 7039.5 7038.0 7032.5 7032.0 7030.5 7029.0 7027.5 7026.5 7025.5 7021.5 7017.5 7015.5 7013.0 7012.5 7009.5 7002.0 7000.5 6998.5 6996.5 6993.0 7125.0 7104.0 7100.0 7095.5 7092.0 7089.0 7081.0 7071.5 7069.0 7064.0 7059.5 7056.0 7052.5 7048.0 7044.5 7032.5 7028.0 7025.0 7015.0 7012.0 7000.0 6996.0 7124.0 7120.0 7113.0 7109.0 7105.5 7101.0 7097.5 7093.5 7089.0 7082.0 7080.5 7076.0 7074.5 7073.0 7071.5 7066.5 7064.5 7062.0 7058.5 7053.5 7049.5 7048.0 7045.0 7043.5 7037.5 7035.5 7032.5 7029.5 7027.5 7026.0 7023.0 7020.0 7017.0 7012.0 7009.0 7004.0 7002.0 6996.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APRil996 10:55 PAGE: 25 6992 6992 6988 6988 6984 5 6983 0 6982 0 6980.5 6977.0 6968.0 6967.0 6960.5 6957.5 6956.5 6953.5 6952.5 6949.5 6945.5 6942.0 6940.5 6936.5 6932.5 6931.0 6928.5 6926.5 6921.0 6919.5 6913.5 6912.5 6907.0 6905.5 6901.0 6900.5 6897.5 6892.0 6891.5 6890.5 6885.0 6876.0 6874 0 6873 5 6871 0 6868 5 6866 5 6861 0 6856.5 6855.5 6849.5 6846.5 6846.0 6828.5 6827.5 6809.5 6799.0 6798.0 5 6993.0 0 5 6989.0 0 6984.5 6981.0 6968.5 6961.0 6956.5 6952.0 6940.0 6936.5 6932.0 6920.0 6919.5 6912.0 6906.5 6904.5 6900.5 6896.5 6891.0 6873.5 6868.0 6855.5 6849.0 6846.0 6828.0 6809.5 6798.0 6993.5 6987.5 6983.5 6982.5 6978.0 6968.5 6957.5 6953.5 6950.0 6945.5 6941.5 6931.5 6928.5 6926.5 6919.0 6912.5 6901.5 6897.0 6891.5 6889.5 6884.0 6877.0 6873.5 6871.5 6867.0 6860.5 6854.0 6846.0 6828.0 6809.5 6798.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 26 6797.0 6797.0 6794.5 6794.5 6787.0 6786.0 6776.0 6776.0 6775.0 6774.0 6772.0 6770.5 6766.5 6766.5 6762.0 6762.5 6761.5 6760.0 6745.5 6745.5 6742.0 6740.5 6740.5 6740.5 6735.5 6736.0 6727.5 6727.0 6726.0 6725.5 6724.5 6724.5 6714.5 6714.5 6683.0 6682.5 6680.0 6680.0 6679.5 6680.0 6672.5 6673.0 6668.5 6669.0 6648.0 6648.0 6641.5 6641.5 6637.0 6637.5 6628.0 6627.0 6604.0 6604.0 6603.0 6603.5 100.0 100.5 100.0 REMARKS: THE DATA IN THIS FILE IS OF WIRELINE CASED HOLE CNTG (AFTER SQUEEZ) PASS #2. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON ARCO ALASKA INC. WILDCAT NEVE #1 501032023100 2440 FWL 0465 FNL 14 liN 4E NORTH SLOPE ALASKA USA SCARBROUGH 50033 Company Name Field Name Wel 1 Name API Serial Number Field Location Section Township Range County State or Province Nation Wi tness Name Service Order Number LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 27 TUNI VALU DEFI PDA T MSL EPD FT O. LMF RKB APD FT 44.3 EKB FT 44.3 EDF FT 42.8 EGL FT 12. TDD FT 7591. TDL FT 7585. BLI FT 7538. TLI FT 6596. DFD G/C3 10. 3 RMS OPi~I 2.21 MST DEGF 71. RMFS OH~IM 2.08 MFST DEGF 75. BHT DEGF 135. Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Bottom Hole Temperature TABLE TYPE : CURV DEFI Dep th Neutron Porosity Epi thermal Neutron Porosity COMPENSATED NEUTORN POROSITY (TOOL, CAL, AND ENV CORR) Neutron Ratio (ND/FD) Cementing Rate Epithermal Neutron Ratio Calibrated DEPT NPHI ENPH CPHI NRAT CRA T ENRA NCNT FCNT CNTC CFTC CNEC CFEC GRCH TENS CCL Corrected Near Thermal Counts Corrected Far Thermal Counts Corrected Near Epithermal Counts Corrected Far Epithermal Counts GA~J~ARAY IN CASING Tension CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 28 TYPE REPR CODE VALUE 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 50033 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNTG PU-S 50033 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH CNTG PU-S 50033 O0 000 O0 0 5 1 1 4 68 0000000000 CPHI CNTG PU-S 50033 O0 000 O0 0 5 1 1 4 68 0000000000 NRAT CNTG 50033 O0 000 O0 0 5 1 1 4 68 0000000000 CRAT CNTG 50033 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA CNTG 50033 O0 000 O0 0 5 1 1 4 68 0000000000 NCNT CNTG CPS 50033 O0 000 O0 0 5 1 1 4 68 0000000000 FCNT CNTG CPS 50033 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNTG CPS 50033 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNTG CPS 50033 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC CNTG CPS 50033 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNTG CPS 50033 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH CNTG GAPI 50033 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CNTG LB 50033 O0 000 O0 0 5 1 1 4 68 0000000000 CCL CNTG V 50033 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA DEPT. 7533.500 NPHI.CNTG 37.620 ENPH. CNTG 31.065 CPHI.CNTG NRAT. CNTG 3.529 CR~T. CNTG 3.466 ENN~.CNTG 4.770 NCNT. CNTG FCNT. CNTG 314.990 CNTC. CNTG 1098.104 CFTC. CNTG 325.436 CNEC. CNTG CFEC. CNTG 541.502 GRCH. CNTG -999.250 TENS.CNTG 3090.000 CCL. CNTG DEPT. 6596.000 NPHI.CNTG 33.287 ENPH. CNTG 39.498 CPHI.CNTG NRAT. CNTG 3.077 CRAT. CNTG 3.229 ENRA.CNTG 5.573 NCNT. CNTG FCNT. CNTG 288.776 CNTC. CNTG 949.915 CFTC. CNTG 310.767 CNEC. CNTG CFEC. CNTG 430.129 GRCH. CNTG -999.250 TENS. CNTG 2810.000 CCL.CNTG 36.093 1121.925 2582.898 -0.002 31.097 986.758 2397.320 -0.013 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 29 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE · 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted a~d clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SU~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 7520.0 6596.0 CNGT 7534.0 6596.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 . .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNGT 88888.0 88888.0 88888.0 7258.0 7258.0 7257.5 7257.5 7250.5 7250.0 7248.5 7249.0 LIS Tape Verification Listing Schlumberger A1 aska Compu ting Center 14-APR-1996 10:55 PAGE: 3O 7247.5 7247.0 7245.5 7245.5 7245.0 7245.0 7241 . 5 7242.0 7239.0 7239.0 7237.5 7237.5 723 6.5 723 6.5 7235.0 7234.0 7233 . 5 7234.0 723 O. 0 723 O. 5 7227.5 7226.5 7227.0 7228.5 7222.5 7223.5 7219.0 7219.5 7218.0 7218.0 7216.5 7214 . 5 7215.5 7216.5 7213.5 7213.0 7213 . 0 7214.5 7208.0 7208.5 7206.5 7209.0 7203.5 7205.5 7200.5 7201.0 7200.0 7201.0 7198.5 7198.5 7196.5 7196.5 7196.5 7194.5 7195.0 7191.0 7192.0 7188.0 7188.0 7186.0 7185.5 7186.5 7182.5 7181.0 7181 . 0 7178.0 7178.5 7176.0 7175.5 7174.0 7174.0 7172.5 7172.5 7172.5 7170.5 7170.0 7169.0 7168.5 7168.5 7168.0 7165.0 7163 . 5 7162.5 7164.0 7161.0 7163.0 7159.0 7157.0 7159.0 7157.0 7157.0 7153.5 7152.0 7150.5 7149.5 7148.0 7148.0 7143.0 7142.5 7141.5 7142.0 7140.0 7140.5 7139.0 7138.5 7136.5 7137.0 7133.5 7133.0 7128.5 7129.5 7127.5 7127.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 31 7125.0 7124.5 7120.5 7116.5 7115.5 7113.5 7113.0 7108.5 7105.0 7103.0 7100.5 7096.5 7092 5 7092 0 7O88 5 7085 5 7084 5 7081 5 7080 5 7076.0 7071 0 7069 5 7068 5 7066 5 7064 5 7064 0 7062 0 7060 5 7056 5 7055 5 7052 5 7050 0 7048 5 7045 5 7044 0 7041 5 7041.0 7039.5 7036.5 7036.0 7034.5 7033.5 7029.5 7026.5 7025.0 7017.5 7015.0 7013.5 7012.5 7011.0 7008.5 7007.5 7005.0 7004.5 70OO.5 7125.0 7121.5 7117.5 7114.0 7108.5 7104.5 7100.0 7096.5 7093.0 7088.5 7085.0 7081.5 7071.5 7070.5 7064.5 7060.5 7057.0 7052.5 7044.0 7042.0 7036.0 7015.0 7012.0 7009.0 7004.5 7000.5 7124.5 7117.0 7114.0 7110.5 7103.5 7100.5 7093.0 7089.5 7086.0 7081.0 7080.5 7076.0 7068.0 7065.5 7063.5 7062.0 7059.5 7053.5 7052.0 7050.0 7048.0 7045.0 7041.0 7038.5 7034.0 7033.5 7033.0 7030.0 7028.0 7026.0 7019.0 7013.5 7011.5 7008.5 7006.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APRil996 10:55 PAGE: 32 7000.0 6996.5 6995.5 6992 0 6991 0 6989 5 6988 5 6986 0 6984 5 6981.5 6980.5 6978.5 6977.5 6976.5 6968.0 6967.0 6965.5 6965.0 6963.5 6963.0 6958.0 695 6.5 6953.5 6952.5 6951.0 6947.5 6940. 5 6937.5 693 6.5 6933.5 6932.5 6928.5 6927.0 6924.5 6923.5 6920.5 6920.0 6917.5 6916.5 6916.0 6913.5 6912.5 6909.5 6905.5 6905.0 6902.0 6900.5 6900.0 6896.5 6892.5 6891.5 6884.5 6881.5 6880.5 6877.5 6997.0 6992.0 6989.0 6984.5 6980.5 6978.5 6977.0 6968.5 6967.0 6963.5 6957.0 6952.5 6940.5 6937.0 6933.0 6928.5 6923.5 6920.0 6917.0 6912.5 6904.5 6900.0 6896.0 6892.5 6884.5 6880.0 7002.0 6996.0 6992.5 6991.0 6987.5 6983.0 6979.5 6968.5 6965.5 6964.0 6958.0 6953.5 6950.5 6948.0 6937.5 6932.5 6928.0 6924.0 6920.5 6918.5 6916.0 6913.5 6909.5 6905.0 6901.0 6899.0 6891.0 6881.0 6878.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 33 6876.5 6876.5 6873.5 6873.5 6869.5 6869.0 6856.0 6856.0 6855.5 6855.5 6846.0 6846.0 6842.0 6842.5 6842.5 6827.5 6828.0 6809.0 6809.5 6808.5 6808.5 6807.0 6806.0 6798.0 6798.5 6792.5 6794.0 6783.0 6783.5 6779.5 6779.5 6779.0 6779.5 6774.0 6774.0 6761.5 6762.0 6759.5 6760.0 6740.0 6740.5 6737.0 6740.0 6735.5 6735.5 6734.0 6735.5 6731.5 6731.5 6723.5 6724.0 6679.5 6680.0 6679.0 6680.0 6671.5 6672.5 6668.0 6669.0 6658.5 6660.5 6647.0 6648.0 6648.0 6642.5 6643.0 6637.5 6639.5 6635.0 6635.5 6634.5 6635.5 6616.0 6616.5 6603.0 6604.0 6602.5 6604.0 100.0 101.5 101.0 REMARKS: THE DATA IN THIS FILE IS OF WIRELINE CASED HOLE CNTG (AFTER SQUEEZE) PASS #3. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN ARCO ALASKA INC. WILDCAT Company Name Field Name Wel 1 Name LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 34 TONI VALU DEFI APIN 501032023100 API Serial Number FL 2440 FWL 0465 FNL Field Location SECT 14 Sec ti on TOWN 11 N Town ship RANG 4 E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nat i on WITN SCARBROUGH Wi tness Name SON 50033 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 44.3 Above Permanent Datum EKB FT 44.3 Elevation of Kelly Bushing EDF FT 42.8 Elevation of Derrick Floor EGL FT 12. Elevation of Ground Level TDD FT 7591. Total Depth - Driller TDL FT 7585. Total Depth - Logger BLI FT 7538. Bottom Log Interval TLI FT 6596. Top Log Interval DFD G/C3 10.3 Drilling Fluid Density RMS OH~4~ 2.21 Resistivity of Mud Sample MST DEGF 71. Mud Sample Temperature RMFS OH~M 2.08 Resistivity of Mud Filtrate S MFST DEGF 75. Mud Filtrate Sample Temperatu BHT DEGF 135. Bottom Hole Temperature TABLE TYPE : CURV DEFI Dep th Neutron Porosity Epithermal Neutron Porosity COMPENSATED NEUTORN POROSITY (TOOL, CAL, AND ENV CORR) Neutron Ratio (ND/FD) Cementing Rate Epithermal Neutron Ratio Calibrated DEPT NPHI ENPH CPHI NRAT CRA T ENRA NCNT FCNT CNTC CFTC CNEC CFEC GRCH TENS CCL Corrected Near Thermal Counts Corrected Far Thermal Counts Corrected Near Epi thermal Counts Corrected Far Epithermal Counts GAMMA RAY IN CASING Ten s i on CCL Ampli rude LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 35 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 50033 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI CNTG PU-S 50033 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH CNTG PU-S 50033 O0 000 O0 0 6 1 1 4 68 0000000000 CPHI CNTG PU-S 50033 O0 000 O0 0 6 1 1 4 68 0000000000 NRAT CNTG 50033 O0 000 O0 0 6 1 1 4 68 0000000000 CR~T CNTG 50033 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA CNTG 50033 O0 000 O0 0 6 1 1 4 68 0000000000 NCNT CNTG CPS 50033 O0 000 O0 0 6 1 1 4 68 0000000000 FCNT CNTG CPS 50033 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC CNTG CPS 50033 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC CNTG CPS 50033 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC CNTG CPS 50033 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC CNTG CPS 50033 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH CNTG GAPI 50033 O0 000 O0 0 6 1 1 4 68 0000000000 TENS CNTG LB 50033 O0 000 O0 0 6 1 1 4 68 0000000000 CCL CNTG V 50033 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 36 DEPT. 7534.000 NPHI.CNTG NRAT. CNTG 3.194 CRAT. CNTG FCNT. CNTG 309.906 CNTC. CNTG CFEC. CNTG 529.215 GRCH. CNTG DEPT. 6597.000 NPHI.CNTG NRAT. CNTG 3.559 CRAT. CNTG FCNT. CNTG 310.240 CNTC. CNTG CFEC. CNTG 422.875 GRCH. CNTG 31.622 ENPH. CNTG 3.137 ENRA.CNTG 994.202 CFTC. CNTG -999.250 TENS. CNTG 35.605 ENPH. CNTG 3.356 ENRA.CNTG 976.762 CFTC. CNTG -999.250 TENS.CNTG 32.546 CPHI.CNTG 4.918 NCNT. CNTG 320.183 CNEC. CNTG 3025.000 CCL.CNTG 40.019 CPHI.CNTG 5.620 NCNT. CNTG 311.740 CNEC. CNTG 2785.000 CCL.CNTG 31.848 997.675 2602.881 -0.004 32.286 997.578 2376.543 -0.012 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE ·FLIC VERSION ·O01CO1 DATE . 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION : O01CO1 DATE · 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH'INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS !, 2, 3 CNTG REMARKS: THE DATA IN THIS FILE IS THE ARITHMETIC AVERAGE OF WIRELINE CASED HOLE CNTG (AFTER SQUEEZE) PASSED 1,2,3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 37 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN WILDCAT Field Name WN NEVE #1 Well Name APIN 501032023100 API Serial Number FL 2440 FWL 0465 FNL Field Location SECT 14 Se c t i on TOWN 1 iN Township RANG 4 E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN SCARBROUGH Wi tness Name SON 50033 Service Order Number PDAT MSL Permanent da tum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 44.3 Above Permanent Datum EKB FT 44.3 Elevation of Kelly Bushing EDF FT 42.8 Elevation of Derrick Floor EGL FT 12. Elevation of Ground Level TDD FT 7591. Total Depth - Driller TDL FT 7585. Total Depth - Logger BLI FT 7538. Bottom Log Interval TLI FT 6596. Top Log Interval DFD G/C3 10.3 Drilling Fluid Density RMS OH~M 2.21 Resistivity of Mud Sample MST DEGF 71. Mud Sample Temperature RMFS OH~I~ 2.08 Resistivity of Mud Filtrate S MFST DEGF 75. Mud Filtrate Sample Temperatu BHT DEGF 135. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT NPHI ArRAT CPHI CRA T ENPH ENRA NCNT FCNT CNTC CFTC CNEC CFEC GRCH Depth Neutron Porosity Neutron Ratio (ND/FD) COMPENSATED NEUTORN POROSITY (TOOL, CAL, AND ENV CORR) Cementing Rate Epi thermal Neutron Porosity Epithermal Neutron Ratio Calibrated Corrected Near Thermal Counts Corrected Far Thermal Counts Corrected Near Epithermal Counts Corrected Far Epithermal Counts GA~k4ARAY IN CASING LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 38 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 0 66 0 73 56 66 1 66 73 65 68 0.5 65 FT 66 18 68 66 0 65 FT 66 68 66 1 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 50033 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI CNAV PU-S 50033 O0 000 O0 0 7 1 1 4 68 0000000000 NRAT CNAV 50033 O0 000 O0 0 7 1 1 4 68 0000000000 CPHI CNAV PU-S 50033 O0 000 O0 0 7 1 1 4 68 0000000000 CRAT CNAV 50033 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH CNAV PU-S 50033 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA CNAV 50033 O0 000 O0 0 7 1 1 4 68 0000000000 NCNT CNAV CPS 50033 O0 000 O0 0 7 1 1 4 68 0000000000 FCNTCNAV CPS 50033 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC CNAV CPS 50033 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC CNAV CPS 50033 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC CNAV CPS 50033 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC CNAV CPS 50033 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH CNTG GAPI 50033 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1996 10:55 PAGE: 39 DEPT. 7533.000 NPHI.CNAV 39.399 NRAT. CNAV CRAT. CNAV 3.564 ENPH. CNAV 32.571 ENRA.CNAV FCNT. CNAV 275.141 CNTC. CNAV 1015.107 CFTC. CNAV CFEC. CNAV 508.046 GRCH. CNTG -999.250 DEPT. 6597.500 NPHI.CNAV 38.073 NRAT. CNAV CRAT. CNAV 3.491 ENPH. CNAV 40.371 EIVRA.CNAV FCNT. CNAV 248.691 CNTC. CNAV 928.650 CFTC. CNAV CFEC. CNAV 407.769 GRCH. CNTG -999.250 3.562 CPHI.CNAV 4.920 NCNT. CNAV 287.098 CNEC. CNAV 3.495 CPHI.CNAV 5.650 NCNT. CNAV 274.376 CNEC. CNAV 39.139 1021.733 2501.298 36. 475 985.219 2301. 961 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE . 96/04/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 96/04/14 ORIGIN : FLIC TAPE NAME . 96097 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., WILDCAT, NEVE #1, API# 50-103-20231-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/04/14 ORIGIN : FLIC REEL NAME : 96097 CONTINUATION # : PREVIOUS REEL : CON~IENT · ARCO ALASKA INC., WILDCAT, NEVE #1, API# 50-103-20231-00
