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Home My WebLink About193-061MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1B-12 KUPARUK RIV UNIT 1B-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 1B-12 50-029-22365-00-00 193-061-0 W SPT 6094 1930610 1524 1636 1641 1646 1647 60 60 60 60 4YRTST P Guy Cook 6/13/2025 Testing completed with a Little Red Services pump truck and calibrated gauges 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1B-12 Inspection Date: Tubing OA Packer Depth 230 2410 2330 2310IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612102159 BBL Pumped:1.2 BBL Returned:1.1 Tuesday, July 22, 2025 Page 1 of 1            ORIGINATED TRANSMITTAL DATE: ALASKA E-LINE SERVICES TRANSMITTAL #: 5361 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5361 1B-12 50029223650000 Injection Profile (IPROF) 23-Mar-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 lorna.c.collins@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 193-061 T40250 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.01 13:16:33 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2024-03-14_22153_KRU_1B-12_CaliperSurveLogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22153 KRU 1B-12 50-029-22365-00 Caliper Survey w/ Log Data 14-Mar-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 193-061 T38644 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.20 15:14:01 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1B-12 KUPARUK RIV UNIT 113-12 Src: Inspector Well Name KUPARUK RIV UNIT 1B-12 API Well Number 50-029-22365-00-00 Inspector Name: Jeff Jones Permit Number: 193-061-0 Inspection Date: 6/30/2021 Insp Num: mitJJ210701132007 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IB -12 Type Inj I w- TVD 6094 - Tubing 2530 - 2530 2520 - 2520 - PTD 1930610 Type Test SPT Test psi 1524 -! IA 330 1900 - 1850 - 1830 BBL Pumped: 1 BBL Returned: 1 ! OA 220 390 iso I iso Interval Four Year Cycle P/F Pass Notes: I well inspected, no exceptions noted. Previous MIT early (Apr 2017) due to water header modifications in May 2017. ✓ Wednesday, August 11, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg q DATE: Wednesday,May 03,2017 P.I.Supervisor r l 5 111C17 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-12 FROM: Lou Laubenstein KUPARUK RIV UNIT 1B-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1B-12 API Well Number 50-029-22365-00-00 Inspector Name: Lou Laubenstein Permit Number: 193-061-0 Inspection Date: 4/22/2017 Insp Num: mitLOL170423072353 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1B-12 • Type Inj W- TVD 6094 _ Tubing 2396 2397 2396 - 2397 PTD 1930610 Type Test SPT Test psi 1524 IA 730 1800 , 1770 - 1770 BBL Pumped: L 0.7 BBL Returned: 0.6 - OA 350 470 470 - 470 • Interval 4YRTST P/F P Notes: SCANNED AUG 2 42017, Wednesday,May 03,2017 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. l (~ 3 "' (~::~/ File Number of Well History File PAGES TO DELETE Complete RESCAN D Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED · [] ' Logs 'of various kinds [] Other Scanned by: Dianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 17, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1B -12 Run Date: 6/4/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1B -12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 22365 -00 114141° Injection Profile Log 1 Color Log 50- 029 - 22365 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 y Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: C'_� Le 1 / Signed: e iLl 173 -o • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 27, 2011 r .. N' JUL 0 8 Z Q I'` p 1 P CO Commissioner Dan Seamount ; Alaska Oil and Gas Commission ' `x- 333 West 7 Avenue, Suite 100 1 i '. 11,11iuSSion ,,cad. Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 3/21, 5/9, 5/23 and 5/24, 2011. The corrosion inhibitor /sealant was pumped 6/18, 6/19, 6/20 and 6/21, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ L veland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 06/27/2011 1A,1B,1E,1L,1Q,1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date _ ft bbls ft gal 1A -03 50029206150000 _ 1810880 _ 16" _ N/A 23" N/A 1.7 6/20/2011 1A-04A 50029206210100 2001940 18" N/A 23" N/A 2.5 6/20/2011 1A -16RD 50029207130100 1820310 SF N/A 22" N/A 5 6/18/2011 1B -03 50029205880000 1810560 - SF N/A 23" N/A 5 6/21/2011 1B-04 50029205950000 1810650 18" N/A 18" N/A 2.5 6/21 /2011 1B -05 50029202370000 1770010 _ 31" _ 6.40 2'9" 5/24/2011 6 6/21/2011 1B-07 50029206160000 I 1810890 72" 1.00 22" 5/9/2011 2.5 6/21/2011 1B -08A 50029206350100 1971120 18'8" N/A 29" N/A 4.5 6/21/2011 1B-09 50029206550000 1811340 SF N/A 23" r N/A 5 6/20/2011 1B -10 50029206560000 18f1350 SF N/A 23" N/A 6 6/21/2011 1B-12 50029223650000 1930610 13'4" 2.00 _ 24" _ 5/9/2011 _ 6 6/21/2011 18-101 50029231730000 2031330 3" N/A 22" N/A 1.7 6/21/2011 1B-102 50029231670000 2031220 112" 0.60 36" - 5/9/2011 1.7 6/21/2011 1E-05 50029204790000 1800580 _ 19" N/A 19" N/A 1.7 6/19/2011 1E -22 50029208840000 1 1822140 14" 1.75 17" - 3/21/2011 1.7 6/19/2011 1E-23 50029208580000 1821840 58' 10.75 2'5" _ 5/23/2011 3.4 6/19/2011 1E-30 50029208140000 1821390 155" 1.75 16" _ 3/21/2011 _ 2.5 6/19/2011 1E -105 50029232430000 2050060 20" N/A 20" N/A 6 6/19/2011 1L-16 50029212020000 _ 1841810 1 4'9" 2.00 35" - 5/23/2011 _ 6 6/20/2011 1L-18 50029221450000 1910350 SF N/A 18" N/A 2.5 6/19/2011 1Q-24 50029225840000 1951210 7'8" 1.00 12" - 5/9/2011 5 6/18/2011 1Y-02 50029209410000 1830590 40'10" 5.00 41" 519/2011 8.5 6/18/2011 ~ MEMORANDUM To: Jim Regg 1 P.I. Supervisor ~~~ ~~2z ~~~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 06, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1B-12 KUPARiJKRIV LTNIT 1B-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV iJNIT iB-12 Insp Num: miUJ090706095148 Rel Insp Num: API Well Number: 50-029-22365-00-00 Permit Number: 193-061-0 f Inspector Name: JeffJones Inspection Date: 6/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1B'12 Type Inj. G TVD 6094 Ip soo »is •% i6so i6~s P.T.D 1930610 TypeTest SPT Test psi 1523.5 QA 60 80 90 90 Interval 4~TST P~ P .i Tubing 2215 2215 2215 2210 NOtes: 1.4 BBLS diesel pumped. 1 well inspected, 1 exception noted: the ROV actuator is leaking oil. Mr. Colee will address this item. i , fr '7~~E, .,, ~. ~. #'~~in r`': ~.' . +-~ f_ ~' , Monday, July O6, 2009 Page 1 of 1 12120107 Schlumberger -DCS ' - ;'~ k 2525 Gambell Street, Suite 400 ' Anchorage, AK 99503-2838 ~ ,af„~.. ATTN: Beth A.,.+i..'~ `~ ~ ~s;_~' ~ ~ ~~~, NO. 4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk • Well Job # Log Description Date BL Color CD 1J-105 11837540 INJECTION PROFILE c'~'1'~-('~'-~ 11/20/07 1 1 A-06 11837542 RST WFL ~'~ ~- ~ J L + 11/22/07 1 1 Q-05 11837537 _ LDL G - ( 11/17107 1 1B-12 11970607 INJECTION PROFILE vT 12104/07 1 2N-327 11996582 OILPHASE SAMPLER Q~- (p 12/15/07 1 1D-132 11994588 SBHP SURVEY t~'(_ - ~ 12/17/07 1 3H-106 11996580 PATCH EVALUATION 12/13/07 1 3N-02A 11970609 LDL - 12105/07 1 1C-125 11964553 INJECTION PROFILE 12101107 1 2M-15 NIA PRODUCTION PROFILE ( (" 12110107 1 2M-11 N/A PRODUCTION PROFILE ~q -- ( 12/08/07 1 3A-03B 11970604 SCMT J 12/01/07 1 2T-217A 11978431 SCMT 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11/27/07 1 2L-330 11837544 SONIC SCANNER 11/27/07 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ""L~ STATE OF ALASKA ~ A ,.,~Z-,A OIL AND GAS CQNSERVATION COMMIS .,I REPORT OF SUNDRY WELL OPERATIONS l:O'~erations:Performed: Abandon. r'-] suspend r'-] · ope'ration Shutdown. [] Perforate r-1 . · .. Varianc~ .. "r-l"AnnularDisp. . ... .. . ...' . . .'.' '.. . . .' .. .... .... · . :: "'.." :': .." .':" ':'Alter Ca~ing'",.. "E~." '"Repair Well. .... .r---~ · Plag"perf~a~ion~.., . . :[--]:.' :~ 'stimulate [] .. "" ..Ti~n~ E~nSi;3n ':,[-'] '. :' :.:::':~)t~er:..'r~ .i, '. Change/~pp?0ved program. ".. [-'1 "' Puil Tubing ['-1 '" .. Perforate "6~'.P0ol':' .r~'l........i..:.~... ,~. i' .'.....Re~nier SUspeh~led'Wbll :'. ~" . ......... :. · . . . 2. Operator Name: '" i.4¥'Curteht:.W~ll.:Statu's::~: "!":'.'.~".:' ;':'..:' · :...=" "' :..i' · .::' 5. Permit to Ddll Number: ...: ...... :..:.. :., .....;. , . ·. . .. , . · ConocoPhillips Alaska, Inc. ."....'. D;ybi~)m~ni '...'.:.r-] .. Exploato~y..r-]'... ....' '.': ':'. 193-061 / · . : . 3. Address: : . ..::"..~t~J~ir~p'hi~ ,'i r-] '" . ServiCe · r~ . 6. APl Number: P. O. Box 100360 .: · '='. 50-029-22365-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 102' 1B-12 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8780' feet true vertical 6964' feet Plugs (measured) Effective Depth measured 8682 feet Junk (measured) true vertical 6875 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 4979' 9-5/8" 5081' 4190' PRODUCTION 7856' 7" 7958' 6343' LINER 1106' 5" 8772' 6958' COIL TUBING 7473' 3-1/2" 7575' Perforation depth: Measured depth: 8146-8340 true vertical depth: 6483 - 6628 iTubing (size, grade, and measured depth) 3-1/2" J-55, 7686' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FB-I' PERM. pkr= 7633' SSSV= NIP SSSV= 1764' :..'.i2.:.stimulation.orcerfient'sque~z6'summary:.." · · ....'... .'. :. ;' .'.' .. ..: '.....: . ... . ....... :........ :;.... =. .... . '.. ;.... .... · 'i' :. i.. ' .: .'.. ...':' .'.' "'.': .' : "' :.'..'i ... .. '" . ..'".:i"'.'... . · · ' ':."." ...... '.:i.'.. . , .;........ ,, ;... . ,'. .. :..... , ':. , · . .: · . , .. .. . · . ·, ~... Intervalstreated'(m'basumd) · .....' · . N/A" ' · · ..! " .... · ...... · ..: · · · ...'=".' :.' .... .::. i. '".'i ..... :i'~: '.. · '..: .! '.'" :~...... i;.'"'. .... " · ":.' ".,.. :' ' .... .' · · .... '.:' '. ....... . '=. ': ':";.:..' =:'. Treatmeht::desc~ipti0nsincludi~ig:~/01~mes.u'sed:and final p~;~Ssai'e: .'":" :'" ''''!'''' '.':'i' '.i..= '? .....:.: ..i.: ' "" : '. · . · ..... "' =. -,,,='., .." '.' .":' "; ' · · :.'.' ': .... '.::"=' '.' ".." '. :'. ...... ' · .: ................. := "='..' ". ...... ';.. · . .... .:;..'.. · :'.: . ii.'= .' ..: · ' ' · .... =..'.'" ..... · ' =.":. i'=' 'i:: ";13~.... '.: ....: '...'..:~ :. ';...' i'ii...":.:.' :'~ :~"~'. :..' ' .:. ' '. '"Rept~sei~tati~e..DbJily.'A~/~'r~.ge 'Pj-iJdui~t on.0r Inj~ctibn Data ...:..~... ': ...:.~'.'.. ::..'. · : '"." ..... . .' :...,. , · . · . ......:. .. : · . ..... · ... ;.. ~.., :.. :. ....: ... .... .... · . · ;.. .'. . . ::: .;...... ::.:... :.:...:. ~ .' :..... ; :;'::"~ ::~ .... ...:'.:DiI.Bbl...' .;;;:,:'1,. .... :.. ~:...;.~.G~MCf.:: ..::...: :..:.'::. ::......::.Wate. r:Bb~...~; :......,. :~asinR'Pre~sum · TuSin~ pr~sur~: · ' · Prior.tO'~W.~l!..pperati0n':'.:' .. '. :. ":. ~.. · · ..:.' ..'..:~ ...: '..~;' .. "'~. :."..;.:':'::' ':;'~" :..~.~: ':.'~: ." ~'..'.': :".384~.: ; ..:..:":....: .: :'. !.~5~."~:'...." . ' '.." 'i 5~8: ..;.." · ,, · ........ :".;:'14~=Aff~hmbnts':"; '.:'"~ ..... : ;":'..: .' .[ ' ': ;'"'..': ·: '.;" "::' :" '..: :. '. "!" !5.:.Well Cia~s'.affer. p~0pbsed'~oyk:; · · ............. . . · ' "Dally ~epo~ oI.W~ll:'0porhtion~':. :".X .... ' ....' '" ' ':a0~'~O,~:Si~t~: ~*~'~0p'~ea~'r~: .. ' ";'::.~ :".:...' :'. ..... '.:".' "': · ·" .... '..'.. : ' '" :"':" .'." ': '":' "'::'""': .... ". · .": '.':: 'o,D ': '.: . . · . . .' . :. ... .'.... '~ .... . . · ... . . · ....... ~ . . . . · . . . .. · ... .. : . :. . .... . .. ~ 7. I horoby Codify lhat tho foro~oin~ is truo and corroct to tho host of my knowlod~o. I 8und~ ~umber or ~/~ ii C.O. fixempt: Contact doff'Sponeor ~65~-722~ " '." ' " · . Prinlod Uam~ ~~a~.~hrisI0nSen ~it~e .' . ~roductionEnOineerin~ iechBician Form. 10-404 Revised 2/2003 · 1B-12 ~)ESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/12/031(~.0mm~ce~!.:.wAG'EOR:lr)je~tion' '.' "...';:. .' ' "" .'" :."".::' ' ' I 03/19/03 Schlumberger N0.2705 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2T-27 cf 01/01/03 1 / 5- 3.~' [,~ TEMPERATURE LOG 1B-12 I~ ~'~-OG [ INJECTION PROFILE 03~04~03 1 lC-135 ~! '--.c~:':~O . INJECTION PROFILE 02/26/03 1 1D-12~l~ ~" O ~ PRODUCTION PROFILE 03~05~03 1 IF-19 ,~.[).~. LEAK DETECTION LOG 02,08,03 1 1 H-07]~-~. LEAK DETECTION LOG 02/~ 5/03 J .... 7F_D SIGN L DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~(;ANN~:!, SE? 1 $ 2003 ,~AR 2 5 200~, ~a~ka ~.a & G~ Cons. ~mm~n MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylor(-~'~ Chairman DATE: June 16, 2002 THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips 1 B Pad KRU Kuparuk WellI P.T.D.I Notes: Well] P.T.D.I Notes: WellI P.T.D.I Notes: WellI , P.T-D.I Notes: P.T.D.I Notes: P.T.D.I Notes: , WellI P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. 1B-02 J TyPelnj. J F I T.V.D. 16109 I Tubing 11450 11450 11450 11450 I Intervall 4 181-133 ITypetestl P ITestpsil 1527 I Casingl 150 I 1980 I 1930 I 1920 I P/F I __P ,s~-os5ITypetestl P I Testpsil 1545 ICasingI 550 I 2°5°1 2050 I. 2°5°1 P/F I P 1B-05 I Type,nJ.I F I ~.V.O. I~, I TUbingl~00 I~00 I~00 I~00 I,ntervall 4 177-001ITypetestl P I Testpsil 1585 ICasingI 250 I 2000 I 1950 I 1925I P/F I P 181-089ITypetestl P ITestpSil 1557 I Casingl 1000 I 1950 I 1920 I 1920I P/F I _P 1B-08 I Typeinj.I Fi I TUbingl 00 I,nte va,I4 197-112 ITypetestl P ITestpsil 1209 ICasingI 0 I 20501 20001 20001 P/F I P 181-134 ITypetestl P ITestpsiI 1527 I Casingl 550 I 2025 I 2000 I 2000 I P/F I --P 193-061 TypetestI P ITestpsil 1524 I CasingI 0 I 21001 20501 20501 P/F I P Type INJ. Fluid Codes F = FRESH WATER INJ. (3 = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips lB Pad in the Kuparuk River Field and witnessed the routine 4 year MITs on the above 7 wells. The pretest tubing and casing pressures on all wells was observed and found to be stable. The standard annulus pressure tests were then performed with all 7 wells demonstrating good mechanical integrity. t~.l.T.'s performed: 7 Number of Failures: 0 Total Time during tests: 4 Hours Attachments: cc: MIT report form 5112/00 L.G. MIT KRU lB Pad 6-16-02 CS.xls 6/20/2002 ~GANNED JUL 1 0 2002 PEf<HIT DATA T DATA .... PLIJ3 07/26/" 1993 J 0,,/05/1993 '10/' 05 ,/' "i 993 I .~ ..) ,,; 06 .,; ,:. ~.. ,,, I 9 !i) 91} 061 c ~ ~'.:',T ~ 7650-8656 9:~{: .... 06I C. ET ~7650 .... 8681 ,. ,(3!}~"06"1 GR .~i. 2' ~ 121 .... 8780 . 9 ':~, .... 061 HLDT c"~.,;',~RRECTED ~9~,, 0 .... 868~ ~ 06~OLd~ 'i 993 06/04/ i 993 06/' 28/'" '199 ~r{l 07/08.,,/ '1993 93 ..... 06 "i I.'-I L D T .-~ C 0 R R E C T E D /....,3,~/80130 .... 8682 () 6 ,/"' 07 / 'J 99 ii~ ? - ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 5, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ff'~- ~,/" B-1 2 Other (SSSV) B-1 2 Perforate B-12 Stimulate ~.~.~.~t~,. 1F-02 Stimulate ~--tcb 1 L-24 Perforate c/.~_ ~ i 1Y-23 Stimulate c/~_~/j 1Y-34 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ALA~i,v~ OIL AND GAS CONSERVATION COMMISb,,..N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate Plugging ~ Perforate X Repair well Other 5. Type of Well: Development ~ Exploratory _ Stratigraphic _ Service X 6. Datum elevation (DF or KB) RKB 1 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 501' FNL, 170' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1261' FSL, 1190' FEL, Sec. 3, T11N, R10E, UM At effective depth 1391' FSL, 862' FEL, Sec. 3, T11N, R10E, UM At total depth 1409' FSL, 814' FEL, Sec. 3, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8. Well number 1B-12 9. Permit number/approval number 9,,t-61 10. APl number 5 q-029-22~65 11. Field/Pool Kuparuk River Oil Field/Pool 8 7 8 0 feet Plugs (measured) None 6954 feet Effective depth: measured 8682 feet Junk (measured) None true vertical 6875 feet Casing Length Size Cemented Measured depth Structural Conductor 1 21 ' 1 6" 300 Sx AS II 1 21' Surface 5041' 9 5/8" 1010 Sx Perm. E & 5081' True vertical depth 121' 4170' 13. Intermediate 450 Sx Prom. G Production 7 93 0' 7" 750 Sx Prem. G 7 9 5 8' Liner 1 1 0 7' 5" 170 Sx Prem. G 8 7 7 2' Perforation depth: measured 8146'-8286', 8310'-8340' true vertical 6461 '-6566', 6584'-6607' Tubing (size, grade, and measured depth) 3.5", 7.15#/ft., QT-800 @ 7576', 3.5", 9.3 #/ft., J-55 @ 7576'-7686' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 7633'; SSSV: Otis MCX Ini. Valve @ 1764" Stimulation or cement squeeze summary Perforate °'C" Sands on 9/27/93. Intervals treated (measured) 8146'-8286', 8310'-8340' Treatment description including volumes used and final pressure N/A 6320' 6946' RECE!V D ,JAN -$ 1994 .-..,,,.~k~ uu & Gas Cons. c01.~,.. Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 1250 50 2275 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . X 16. Status of well classification as: Oil Gas Suspended __ Service H20 Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'F~'~,'.~ Title Senior Erlgirleer Form 10-404 Rev 06/15/88 Date / '"'- ,~' ""~:~ ~/' SUBMIT IN DUPLICATE ARCO Alaska, Inc. _~ Substdl~y of Atllnllc Rt;hfletd O~pltty CONTRACTOFJ REM.~RK$ ~' ~ I'Fi'£[.D - DISTRICT- STATE IOPi~ffATION AT REFK)RT TIME ! ~,,.~/~./"~. il" WELL SERVICE REPORT 0030 ! [-] CHECK THIS BLOCK IF SUMMARY CO NUED Weather Refit Temp.*F 1 ChlllFaet~r [vlilblllly.F , .... 5~~.'.c7, : _ .-.., P. .¢ 'd el : _ ~'$ / o '- ~ s ¢ o ' Anchqracm ON BACK mlle~] Wind Vel. STATE OF ALASKA ALA3rv-~ OIL AND GAS CONSERVATION COMMISU,,.,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 501' FNL, 170' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1261' FSL, 1190' FEL, Sec. 3, T11N, R10E, UM At effective depth 1391' FSL, 862' FEL, Sec. 3, T11N, R10E, UM At total depth 1409' FSL, 814' FEL, Sec. 3, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 102~ 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-12 feet 9. Permit number/approval number 93-61/9~-166 10. APl number 50-029-22305 11. Field/Pool Kuparuk River Oil Field/Pool 8780 feet Plugs (measured) None 6954 feet Effective depth' measured 8 6 8 2 feet Junk (measured) None true vertical 6875 feet Casing Length Size Cemented Measured depth Structural Conductor 1 21' 1 6" 300 Sx AS II 1 21' Surface 5041' 9 5/8" 1010 Sx Perm. E & 5081' True vertical depth 121' 4170' Intermediate 450 Sx Prem. G Production 7 9 3 0' 7" 750 Sx Prem. G 7 9 5 8' Liner 1 1 0 7' 5" 170 Sx Prem. G 8 7 7 2' Perforation depth: measured 8146'-8286', 8310'-8340' true vertical 6461 '-6566', 6584'-6607' Tubing (size, grade, and measured depth) 3.5", 7.15#/ft., QT-800 @ 7576', 3.5", 9.3 #~ft., J-55 @ 7576'-7686' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 7633'; SSSV: Otis MCX Inj. Valve @ 1764" 13. Stimulation or cement squeeze summary Installed spring controlled safety valve on 1/3/94. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 6320' 6946' RECEIVED JAN -,5 i994 u~i & Gas Cons. Commission ~nch0rage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 1250 50 2275 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended __ Service .H2O Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed -- ,, Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ALASKA ; ..L=., 4-cj4 ; ,.'3: 4~PM ; KPS/WELLS/CNST/PROJ~'KUPARUK OPERAT IONS ; # 1 / 2 ARCO Alaska, Inc. SubsR:llary of Atlant}c Rlcl~fleld Company WELL WELL SERVICE REPOI~ ,.cc,qr_ 40 IFIELD- D'ISTRICT- STATE c.c.; _~o CONTRACTOR _ H£X...- I;IEMARKS g. ~,tr Hr_.~! t# 2,' .~ z t/£ - _. c .T~ c o .JS!Y "~r , :i ' ' * ' - ' PSt -~.~EA~9' o[ To~ ~ ~0~7/~ ~ ~lg ~Jr~ ~,~.~/H. _ T~Z.~ ~ ~F. ~,/7oo P~/ /. lZ= ~_.~/6 ~.. /~ ~/~ ~ ~ ~ . i JAN --,5 i994- Aiaska Oil & Gas Cons. Commission [2 CHECK ?HI8 BLOCK IF SUMMAFI¥ ¢ONIINUED O!~i' BACK 'i ..,,,. ~ .~ -~,, ,.I /;. _,;LIw'%v:'' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,,.~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing ~ Alter casing Repair well Perforate Other '2. Name of Operator ARCO Alaska, In~;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 501' FNL, 170' FEL, Sec. 9, TllN, R10E, UM At top of productive interval 1261' FSL, 1190' FEL, Sec. 3, TllN, R10E, UM At effective depth 6. Datum elevation (DF or KB) RKB 10~ 7. unit or Property name Kuparuk River Unit 8. Well number 1B-12 9. Permit number/approval number 93-61 10. APl number feet 1391' FSL, 862' FEL, Sec. 3, T11N, R10E, UM At total depth 1409' FSL, 814' FEL, Sec. 3, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 878O 6954 feet feet 5 0-029-2236~ 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 8 6 8 2 true vertical 6875 feet Junk (measured) None feet Casing Length Size Structural Conductor 1 2 1' 1 6" Surface 5041' 9 5/8" Cemented Measured depth True vertical depth 300 SxAS II 121' 121' 1010 Sx Perm. E & 5081' 41 70' Intermediate Production Liner Perforation depth: 7930' 7" 1107' 5" measured 8146'-8286', true vertical 6461 '-6566', 450 Sx Prem. G 750 Sx Prem. G 7958' 170 Sx Prem. G 8772' 8310'-8340' 6584'-6607' Tubing (size, grade, and measured depth) 3.5", 7.15#/ft., QT-800 @ 7576', 3.5", 9.3 #/ft., J-55 @ 7576'-7686' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 7633'; SSSV: Otis MCX Inj. Valve @ 1764" 13. Stimulation or cement squeeze summary Acid Stimulation of "C" Sands on 10/31/93. Intervals treated (measured) 8146'-8286', 8310'-8340' Treatment description including volumes used and final pressure 14. 6320' 6946' RECEIVED ,,~ ;;~ u,~ & 6as Cons. C0mmis~ Anchorage Pumped 83 bbls DAD acid system (12% HCL) and 105 bbls pw flush, final pressure was 1854 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .X 0 0 1250 50 2275 16. Status of well classification as: Oil Gas Suspended__ Service H2Q Injector 17. I hereb~certify that the foregoing is true and correct to the best of my knowledge. S,,ne Title Senior En~lineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE . ARCO Alaska, Inc. Subsidiary of Athmtie Ricl~dd Corn. party WELL lB-12 DATE 10-31-93 DAY 1 DF, SCRIFrION OF WORK "C" SAND ACID STIMULATION CONTRACTOR / I~Y PERSON DS-VANCE YOKUM, PBTD (RKB) 8682' S1TP 2508~-CP 568~ LAST TAG (RKB) / DATE 8476'/9-27-93 KUPARUK RIVER UNIT 1 WELL SERVICE REPORT I AFC/CC# - SCA # 998001/80528 FIELD COST EST. ACCUMULATED COST $14,949.00 ] $14,949.00 SSSV TYPE / STATUS OTIS SLN-MCX [NJ VALVE NOT INSTALLED TIME LOG ENTRY "C" SAND ACID STIMULATION 1000 MIRU DS-WAITING ON TRANSPORT 1115 KL,,--/.~,~,~.,;.4 PETROLEUM ENGiNEERi;'4G HELD SAFETY MEETING! 1130 PT PUMP LINES TO 4700g-OK! 1132 START PUMPING ACID @ 1.5 BPM WHTP 3225#-CUT RATE TO 1.0 BPM WHTP 3300g 1150 1215 1216 1221 1241 1251 WHTP 2980~ (CP 957#) W/15.3 BBLS IN WELL @ 1.0 BPM WHTP 3396~ (CP 1310~) W/41.6 BBLS IN WELL @ 1.0 BPM PUMP 7 BBL DIVERTER SLUG @ 1.0 BPM-TOTAL OF 50 BBLS IN START PUMPING 2ND STAGE OF ACID @ 1.0 BPM WHTP 3775# (CP 1375#) WHTP 37264¢ W/64.7 BBLS IN @ .5 BPM WHTP 3425# (CP 1300~) Wf/0 BBLS IN @ .5 BPM WHTP 2900~ W/75 BBLS IN @ .5 BPM-ACID @ TOP PERFS 1301 1305 WHTP 2720~ (CP 1218#)W/77 BBLS IN @ .5 BPM 1326 WHTP 2797# W/92 BBLS IN @ .70 BPM 1327 START FLUSH W/10S DEGRgE PW-PUMP LOST PRIME WHEN SWITCHING TO FLUSH WHTP 1748~ .. 1353 1405 1422 WHTP 2682# (CP 1374#) WI117 BBLS IN @ 1.75 BPM 1427: 1431 WHTP 2463# @ .5 BPM-PW @ PERFS WHTP 2700~ (CP 1690~) W/137 BBLS IN @ 1.4 BPM ALL ACID PUMPED AWAY-WHTP 2700g (CP 1975#) @ 2.75 BPM RATE 1.0 BPM WHTP 2730~-CUT RATE TO .5 BPM WHTP 24(X~ 1434 WHTP 2545~ (CP 1990#) PUMPED TOTAL 89 BBLS PW @ .5 BPM (14 BBLS OVERFLUSI-I) Vel. I Slgn.~! Weather [ Temp., / / RECEIVEr JAN - 5 19~'' ",. 0il & 6as 6ol'is. f g~.chora~r~ P~MARKS C(~NTINUI~: 1435 SD PUMPING 1445 WHTP 1625# 1446 1452 1457 1502 1510 1545 1700 RESUME PUMPING PW @ .5 BPM WHTP 2400~ WHTP 2(:ff)0~ @ .5 BPM-INCREASE RATE TO 1.0 BPM WHTP 3030~ @ 1.0 BPM-INCREASE RATE TO 1.5 BPM WHTP 3245# @ 1.5 BPM-SD PUMPING-TOTAL PW PUMPED 104 BBLS WHTP 1510~ (CP 185440 RDMO DS FREE:ZI~_, PROTECTE_D WELL W/30,BBLS 60/40 MEOH & 20 BBLS DIESEL ~., ~-~. SUlVlMAR¥ PUMPED DAD ACID PER PROCEDURE-APPEARED ACID OPENED PERFS (2700~ @ 2.75 BPM ) BUT WHEN PW HIT PERFS INJECTION PRESSURE STARTED BUILDING UP- PUMPED A TOTAL OF 104 BBLS PW (29 BBLS OVERFLUSI-1) RECOMMEND WELL BE FLOWED TO SYSTEM TO CLEAN UP PERFORATIONS! SERVICE COMPANY III I DAILY $13025.00 ACCUM. TOTAL $13,025.00 PEAK 1200.00 $1200.00 LIL RED SERVICES 640.00 640.00 84.00 84.00 DmSEL TOTAL FI~.I.D le~TIMATE $14,949.00 $14,949.00 RECEIVED ~, c.::~r: Cr~,s. CoBmJssior ,'~. ;~; ARCO Alaska, Inc. Date: July 23, 1993 Transmittal#: 8812 RETURN TO: ARCO Alaska, Inc. At"tn: Sarah Bowen ~ ~!~ Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items, and return one signed copy of this transmittal. 9 ILlS Tape and Listing: 10-18-92 L,,~_,<~.. '7Bit Runs of CDR. Corrected HLDT ~u.~~-07 .LIS and 9-18-93 Tape Listing: ~"'~L'21'~H'J- :3 Bit Runs of CDR. Corrected HLDT 'LIS Tape and Listing: '3-27-93 :.L~,td~ CDR/CDN & QRO Enhanced Resistivity '~~Vl-32 ~LIS Tape and listing: 1.1-17-92 ' ..... ;CDR Runs '1 & 2, Averaged Cased Hole HLDT LIS Tape and Listing: 6-26-93- · DTE/SDN & CNTH · ~ LIS Tape and Listing' ' 6-9-93 0 CDR/CDN & GR CBT in LDWG Format' Please acknowledge receipt 92622 92563 93132 .92686 93292 93263 ., ~,' ,1R'~-22 · LIS Tape and Usting: ' 5-29-93 93244 ~ . CDR/CDN in 1 Bit Run, GR from CBT · . _ .~'~'~'/tR~--17 '". ,LIS=Tape and. Listing: .... -...' .5-23-93- 93241 ".' -.~-'.~~ . ~ - - , ~~ · , CDR Runs.1 &2, CDN Run 2, QRO Preened . "' 4')' ~12 -., ' LIS Tape and ~ing: . 5-18-93 93239' '~ C../ ' .~/ ..... CN'TG/HLD~.& Arithmetic Average: :._ ~ Receipt Ackn~d DISTRIBU~N: . Bob ~nas State ofAlas~ ~' INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT 10/08/1993 PAGE: 1 PERMIT DATA DETAIL 93-061 CBT CH,7650-8656 93-061 CET CH,7650-8681 93-06~ GR 2",121-8780 93-061 HLDT CORRECTED 7970-8682 93-061 HLDT-CORRECTED 8030-8682 93-061 407 93-061 DAILY WELL OP 93-061 SURVEY COMP DATE:09/27/93 05/02/93-09/27/93 SS DIRECTIONAL 93-061 5715 CNTG/HLDT &ARITH AVE SUMMARY Are well tests required? Was well cored? Yes No Yes No If yes, was the core analysis & description received? Are dry ditch samples required? Yes No Yes No WELL IS IN COMPLIANCE. INITIAL COMMENTS: STATE OF ALASKA ~ ALASr~ OIL AND GAS CONSERVATION COMMisSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG " I Status of Well Classification of Service Well ' OIL r'--'l GAS r--] SUSPENDED E~ ABANDONED r~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska' IncORIGINAL 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22365 4 Location of well at surface ~' ~ ;i~, ~ ;~ ~ -: 9 Unit or Lease Name At Top Producing Interval ?,~Z-~ ¢-~"" "~ i ....... ~' 1239' FSL, 1220' FEL SEC 3, T11 N, R10E, UM 1396' FSL, 831' FEL, SEC 3, Zl 1N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER RKB 102', PAD 61' GLI ADL 25648 ALK 466 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 02-May-93 12-May-93 09/27/93.(Perfed) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 8780' MD, 6964' TVD 8684' MD, 6890' TVD YES X~J NO L._JI SLN @ 1764' feet MDI 1600' APPROX 22 Type Electric or Other Logs Run G R/ONTG/HLDT/CET/CBT/GCT 23 CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD :CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT'RECORD 16. 62.5# H-40 121' 121' 24" 200 SX (Approx) 9.625 47#/36# L-80/J-55 SURF 5081' 12.25" 1010 SX PERM E CMT, 450 SX CLASS G 7. 26# J-55 SURF 7958' 8.5" 200 SX CLASS G CMT 5. 18# L-80 7666' 8772' 6.125" 170 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8146'-8286' MD 6483'-6588' TVD 3-1/2' (7.148# QT-800/9.3# J-55) 7686' 7633' 8310'-8340' MD 6606'-6628' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED OCT - ,5 t993 klask.~ 0il & Gas Cons. ~,ummissto~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONT1NUEDON REVERSE SIDE GE(%OGIC MARKER FORMATION TESTS ~ .¢ '. ¢ NAME Include interval tested, pressure data, all fluids recovered and gravity, .-: : ... MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. '~' TOP KUPARUK C 8135' 6475' :. 31. LIST OF A'f-I'ACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed ~ ,~ ,,~/*¢/~,1¢~ Title ~ ~,/,,~ ~:/~'~ . DATE ~'~/~/~ 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 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: lB-12 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25648 ALK 466 50-029-22365 93-61 ACCEPT: 05/02/93 05:00 SPUD: 05/02/93 03:30 RELEASE: 09/27/93 12:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: SWS 05/02/93 ( 1) PARKER 245 TD: 121'( 121) NU DIVERTER 16"@ 121' MW: 0.0 VIS: 0 MOVE RIG F/1H-22 TO lB-12 & RU. NU 20" DIVERTER. 05/03/93 ( 2) PARKER 245 TD: 1575'(1454) 05/04/93 ( 3) PARKER 245 TD: 4640'(3065) 05/05/93 ( 4) PARKER 245 TD: 5105'( 465) DRILLING 16"@ 121' MW:10.5 VIS: 52 NU DIVERTER SYSTEM. FUNCITON TEST DIVERTER. TEST WITNESSED BY JERRY HERRING OF AOGCC. PU DP AND HWDP APPLYING CATS PAW DOPE. TORQUE 10% HIGHER FOR MU. PU 3 MONELS AND 3 STEEL DC'S. CLEAN THREADS AND APPLY CATS PAW. FILL STACK. CHECK FOR LEAKS-OK. PU BHA. ORIENT TOOLS. C/O F/95'-121' SPUD WELL @ 1530 HRS 05/02/93. DRLG 12.25" HOLE F/i21'-1575' DRILLING 16"@ 121' MW:10.5 VIS: 51 DRLG 12.25 " HOLE F/1575'-1600' CBU. SLUG DP. POOH. PU NEW BIT, 9-1/2" NAVIDRILL. C/O BTM STAB SLEEVE F/12-1/4" TO 12-1/8" TIH. DRLG 12.25" HOLE F/1600'-4640' CEMENTING 9-5/8" CSG 9-5/8"@ 5081' MW:10.9 VIS: 60 DRILL & MWD SURVEY TO 5105'_ CBU. ATTEMPT SHORT TRIP, HOLE TIGHT & SWABBING F/2788'-1800', UNABLE TO RIH. POH. LD MWD, MONEL & NAVI-DRIL. PU HOLE OPENER. RIH. REAM TIGHT HOLE F/1871'-1955' & F/2012'-2052' RIH TO 5105', NO FILL. FILL PIPE & CIRC, COND FOR 9-5/8" CSG. POH. LD ALL BHA & CLEAR FLOOR OF 8" TOOLS. RU TO RUN 9-5/8" CSG. HOLD SAFETY MEETING. RUN 52 JTS 9-5/8" 36# J-55 BTC CSG & 69 JTS 9-5/8" 47# L-80 BTC CSG W/SHOE @ 5081' CIRC & COND CSG, COND MUD/HOLE FOR CEMENTING. CEMENTING 9-5/8" CSG PER WELL PLAN @ REPORT TIME. RECEIVED OCT - 5 1995 .&laska Oil & LmS Gons. GurnmissiO¢ Anchorage WELL: lB-12 API: 50-029-22365 PERMIT: 93-61 PAGE: 2 05/06/93 ( 5) PARKER 245 TD: 6277'(1172) 05/07/93 ( 6) PARKER 245 TD: 7958'(1681) 05/08/93 ( 7) PARKER 245 TD: 7958'( o) POH TO 9-5/8" SHOE 9-5/8"@ 5081' MW: 8.7 VIS: 30 BOP TEST WAIVED BY BOBBY FOSTER OF AOGCC. CMT 9-5/8" CSG W/1010 SX PF E, 390 BBLS MIXED ~ 12 PPG, FOLLOWED BY 450 SX PREM G W/ADDITIVES, MIXED @ 15.7 PPG. DISPLACE W/377.5 BBLS. BMP PLUG W/2000 PSI, BLED OFF, FLOATS HELD, 12 PPG CMT RETURNS TO SURF. CIP 0830 HRS 05/05/93. LD LANDING JT, WASH OUT DIVERTER & DIVERTER VALVES, ND DIVERTER. INSTALL 11 3/4 BTC X 11" 3M MC EVOY SPEED HEAD & TORQUE TO 20K FT/LBS. NU BOP. SET TEST PLUG, TEST BOP TO 300 PSI LOW & 3000 PSI HIGH. PULL TEST PLUG, RUN WEAR BUSHING. SERVICE RIG & TOP DRIVE. CUT DRLG LINE 94' PU BHA, ORIENT MWD, SURF TEST MWD. RIH, TAG WIPER PLUGS @ 4993' CIRC, TEST 9-5/8" CSG TO 2000 PSI FOR 1/2 HR, LOST 50 PSI. DRILL PLUGS, FC, CMT, FS & 10' NEW FORMATION TO 5115'. CBU. TEST FORMATION @ 5115' MD, 4196' TVD, 8.6 PPG MW, 850 PSI SURF PRESS. 12.5 PPG EMW. DRILL & MWD SURV TO 6277'. PMP SLUG & POH TO SHOE FOR LOWER IBOP REPAIRS. POOH, LD 5" DP 9-5/8"@ 5081' MW: 9.2 VIS: 33 REPAIR IBOP & AIR MOTOR FOR GRABS ON TOP DRIVE. RIH WASHING DOWN LAST 90' TO BTM-NO FILL. DRILL & SURVEY 8.5" HOLE F/6278'-6928'_ SERVICE RIG & TOP DRIVE. DRILL & SURVEY F/6928'-7958' CBU. MONITOR FOR FLOW. MIX & PMP DRY JOB. MAKE 31 STD SHORT TRIP TO 9-5/8" SHOE. CIRC & COND MUD F/TRIP OUT OF HOLE, MIX & PMP DRY JOB. POOH LAYING DOWN 5" DP. CHANGING RAMS IN BOP 7"~ 7957' MW:12.1 VIS: 47 FIN POH, LD DP & BHA. PULL WEAR RING, RIG TO RUN 7" CSG. HOLD PRE-JOB SAFETY MEETING. RUN 7" 26# J-55 CSG. INSTALL CENTRALIZERS & CENTERING GUIDES. CIRC & RECIP 7" CSG, CIRC PACKING OFF. WITH SHOE ~ 7958' & FC @ 7865', RECIP & CMT 7" IN PLACE. ND & PU STACK, SET SLIPS ON CSG W/240K GROSS. MAKE ROUGH CUT ON 7", LD LANDING JT, MOVE STACK & RISER, MAKE FINAL CUT & DRESS STUB, SET PACKOFF & NU ll"-3M X 7-1/16" 5M TBG SPOOL. TEST PACKOFF TO 3000 PSI FOR 1/4 HR-GOOD. RU LINES & FREEZE PROTECT 7" X 9-5/8" ANN W/100 BBLS WATER FOLLOWED BY 75 BBLS DIESEL. NU SHORT RISER & BOP. CHANGING BOTH SETS OF RAMS TO 3-1/2" RECEIVED OCT Alaska 0il & C~as Anchorage WELL: lB-12 API: 50-029-22365 PERMIT: 93-61 PAGE: 3 05/09/93 ( 8) PARKER 245 TD: 7968'( 10) 05/10/93 ( 9) PARKER 245 TD: 8135'( 167) 05/11/93 (10) PARKER 245 TD: 8412'( 277) 05/12/93 (11) PARKER 245 TD: 8767'( 355) 05/13/93 (12) PARKER 245 TD: 8780'( 13) CHANGE MUD TO 12.5 PPG 7"@ 7957' MW:12.1 VIS: 46 FIN INSTALLING 3-1/2" RAMS IN TOP & BTM RAMS. RU TEST EQUIP & TEST TOP & BTM RAMS & ALL BREAKS TO 300 PSI & 3000 PSI. RD TEST EQUIP. INSTALL WEAR BUSHING. RU TOP DRIVE F/3-1/2 " DP. CHANGE OUT GRAB LOCKS. PU BHA-ORIENT TOOLS. RIH & TEST MWD TOOLS. TOOL FAILED TO WORK, POOH & LD MWD TOOLS. REPLACE TOOLS W/BACKUP. RIH & TEST-OK. RIH W/3-1/2" DP FILLING PIPE @ 4300' CIRC & TEST 7" CSG TO 3500 PSI FOR 30 MIN W/100 PSI LOSS. VALVE ON KILL LINE BROKE. CHANGE OUT INSIDE KILL LINE VALVE. TEST VALVE & BREAKS TO 3000 PSI. DRILL PLUGS, FC, CMT, SHOE, & 10' NEW FORMATION TO 7968' PERFORM FIT TO 13.5 PPG EMW. DISPLACE OLD MUD W/NEW 12.5 PPG MUD IN PREP FOR DRILLING KUPARUK C SANDS. DRILL, LOG & SURVEY 7"~ 7957' MW:12.5 VIS: 47 DRILL, LOG, & MWD SURVEY TO 8113' MONITOR HOLE, SLUG PIPE, POH. CHECK ANADRIL TOOLS, BREAK BIT. MU NEW BIT. RIH, TEST MWD ~ 620'. FILL PIPE @ 4000' & @ 7" SHOE. REAM F/7" SHOE TO 8113', BRIDGE @ 8061' PACKING OFF. MUD WT CUT TO 11.7 PPG ON BTMS UP. DRILL, LOG, & MWD SURVEY. DRILL & SURVEY 6.125" HOLE 7"@ 7957' MW:12.5 VIS: 48 DRILL, LOG, & MWD SURVEY 6.125" HOLE F/8135'-8330'. MONITOR FLOW & PMP DRY JOB. TRIP OUT OF HOLE LAYING DOWN ANADRILL TOOLS, NAVIDRILL, & DOT SUB. PU NEW BHA & RIH FILLING PIPE @ 3500' & 7000'_ WASH 65' TO BTM-O' FILL. DRILL F/8330'-8389' AT 8389, GAS CUT RETURNS TO 8.4 PPG @ SURF. CIRC OUT GAS CUT RETURNS & MONITOR FLOW. DRILL F/8389'-8412' DRILLING 7"~ 7957' MW:12.5 VIS: 43 DRLG 6.125" HOLE F/8380'-8500' SERVICE RIG. DRLG 6.125" HOLE F/8500'-8767' NO MUD LOSS. STARTED SHAKING OUT LCM @ 8700' CIRC & COND MUD 5"~ 8772' MW:12.5 VIS: 44 DRLG 6.125" HOLE F/8767'-8780' CBU-SLUG DP. MADE 9 STD SHORT TRIP. HOLE TIGHT, PULLING OUT @ 8150' & 8185' RIH OK-NO FILL. CIRC & COND MUD & HOLE FOR 5" LINER. DROP SURV, SLUG DP, DROPPED 2-3/8" OD RABBIT. POH. LD BHA. SLM-NO CORR. PULLED WEAR BUSHING. RU CASERS, HOLD SAFETY MEETING. RAN 25 JTS 5" 18# L-80 LT & C 8RD CSG & BAKER HYDRAULIC SET LINER HGR AND ISOLATION PKR. TOTAL LENGTH 1106.64' RIH W/LINER ON 3-1/2" DP TO 7900' FILL PIPE EVERY 5 STANDS. CBU ~ 7900' CONT RIH TO 8780'-SHOE DEPTH. 5' FILL ON BTM. CIRC & RECIP PIPE FOR CMT JOB. RECEIVED Alaska Oil & uas ~ons, uu~.nissl°'~ Anchorage WELL: lB-12 API: 50-029-22365 PERMIT: 93-61 PAGE: 4 05/14/93 (13) PARKER 245 TD: 8780'( 05/15/93 (14) PARKER 245 TD: 8780'( o) 08/22/93 (17) TD: 8780 PB: 8682 o) RIH W/4" MILL 5"0 8772' MW:12.5 VIS: 44 CIRC & COND MUD AND HOLE, RECIPICATE LINER, CIRC 0 3 BPM - 1000 PSI, HOWCO CMTD 5" LINER, PUMPED 5 BBLS 13.5 PPG SPACER, TESTED LINES TO 4500 PSI, PUMPED 25 BBLS SPACER, 170 SX CLASS "G" PREM W/ ADDITIVES (37 BBLS SLURRY), WASHED UP AND DISPLACED W/69.5 BBLS MUD, FULL RETURNS THRU JOB. PLUG DOWN AT 09:00, BUMPED PLUG, PRESS TO 3100 PSI AND SET LINER HGR, TOL 0 7666', LC AT 8683' AND SHOE AT 8772' PRESS TO 4000 PSI TO SET ISOLATION PKR. RELEASED PRESS, FLOATS HELD, RELEASED SETTING TOOL, PRESS UP TO 1500 PSI TO TEST PKR AND 7" CSG, LEAKED OFF TO 1050 PSI, PRESS DP TO 500 PSI, PULLED SETTING TOOL OUT OF LINER, PULLED 3 STDS DP, CBU 0 7380', REC 20 BBLS SPACER, NO CMT, SLUG DP, POH AND LD SETTING TOOL. INSTALLED WEAR BUSHING, PU 6 1/8" BIT, 7" CSG SCRAPER, BS, RIH W/ 4-3/4" DC'S AND DP, LD 21 JTS 3-1/2" DP, RIH TO 7020', CUT DRLG LINE, GREASE UP, RIH TAG CMT 0 7637', CO CMT F/7637' TO 5" TOL 0 7666', CBU, TEST 5" LINER TOP TO 1500 PSI FOR 30 MIN, HELD, SLUG DP, POH, LD 12 4-3/4" DC'S, CSG SCRAPER & BIT, PU 4" MILL, 5" CSG SCRAPPER, BS, & 37 JTS 2-7/8" DP, PUMP THRU 2-7/8" DP, RIH W/3-1/2" DP. RELEASE RIG, MOVE TO 1Y-17 5"0 8772' MW:12.5 VIS: 0 FRIH W/4" MILL. TAGGED PBTD AT 8682', CBU, PUMPED 40 BBL HI-VIS SWEEP, 5 BPM 0 3500 PSI, TEST CSG TO 1500 PSI , HELD, TEST HOWCO LINES TO 2500 PSI, PUMPED 100 BBLS FRESH WATER HOLDING BACK PRESURE W/CHOKE, BRINE WEIGHT QUESTIONABLE, 12.~5 PPG 0 60 DEG F. DISPLACE HOLE W/289 BBLS 12.5 PPG BRINE POOH LD 3-1/2" DP, 2-7/8" DP & SCRAPER, ARCTIC PACKED 9-5/8"X7" ANNULUS W/ 300 BBL WATER AHEAD, 250 SX PERMAFROST "C" CMT AND & 55 BBL ARCTIC PACK DIESEL. CO TOP DRIVE BACK TO 5", CHANGE TOP RAMS F/3-1/2" TO VARIABLE. CO BTTM RAMS F/3-1/2" TO 5". ND BOP, FILL 7" CSG TO 32' BELOW GROUND LEVEL, NU TREE, RIG RELEASED 0400 ON 5/15/93 BOP TESTING 5"0 8772' MW: 0.0 RU DOWELL CTU OVER WELL. SPOT 3-1/2" COILED TBG TRAILER IN FRONT OF CTU. INSTALL TWO SPOOLS & BLIND RAM IN BOP STACK. RU LINES TO 3-1/2" CT REEL. RECEIVED ALL GLM'S & RELATED TOOLS. PREP TO TEST BOP STACK. REMOVE LOWER 7-1/16 SPOOL INSTALL TEST PLUG. NU BOP STACK. BEGIN TESTING BOP STACK 0 1900 HRS. TEST ON LOWER BLIND RAMS FAILED. FOUND LEAKING VALVE ON HOT PMP TRUCK. RETEST-OK. TEST BLINDS, PACKOFF, ANN TO 300/3000 PSI-OK. TEST WITNESSED BY JOHN SPAULDING(AOGCC). SDFN. RECEIVED Oil & (Jas Cons. bun~misslo~ Anohoraoe WELL: lB-12 API: 50-029-22365 PERMIT: 93-61 PAGE: 5 08/23/93 (18) TD: 8780 PB: 8682 08/24/93 (19) TD: 8780 PB: 8682 08/25/93 (20) TD: 8780 PB: 8682 CLOSED UPPER BLIND RAMS 5"~ 8772' MW: 0.0 WAIT ON FLUID TO BE DELIVERED FROM CPF-1 TO FIN TESTING PIPE RAMS. TEST UPPER & LOWER PIPE RAMS TO 300/3000 PSI-OK. ND FLANGE @ TOP OF 7-1/16" BOP. RETRIEVE TEST PLUG. RU CSG CREW. PU SEAL ASSY, 1 JT 3-1/2" 9.3 PPF TBG & CAMCO GLM W/DUMMY VALVE. MU W/CSG CREW & RIH. INSTALL COILED TBG CONNECTOR. NU FLANGE. RIH W/5800' 3-1/2" QT 800 COILED TBG. SET SLIPS. BREAK FLANGE ~ TOP OF 7-1/16" BOP. RAISE INJ & 5-1/8" BOP UP. MAKE CUT W/TBG CUTTER. BRINE WATER IN COILED TBG SPRAYED WHEN CUT MADE. BRINE GOT ON GRAVEL AROUND WELL HEAD. HALTED OPERATIONS WHILE PEAK ROUSTABOUTS CLEANED UP CONTAMINATED GRAVEL. ESTIMATE <1 BBL BRINE WATER GOT ONTO GRAVEL. MOST OF THE BRINE WENT INTO CELLAR & WAS IMMEDIATELY REMOVED BY VAC TRUCK ON LOC. FIN CUT ON COILED TBG. LOWERED 5-1/8" BOP & INJ BACK DN. REMOVED INJ & SET IT BACK ON CTU. UNTHREADED 3-1/2" COILED TBG F/INJ. CLOSED UPPER BLIND RAMS. SDFN. RIGGING DOWN 5"@ 8772' MW: 0.0 FIN CHANGING REELS OF 3-1/2" TBG ON TBG T-RAILER. INSTALL CT CONNECTOR. MU PUP JT, LANDING NIPPLE, FLOW COUPLING, & PUP JT. MU CT CONNECTOR. CONT IN HOLE W/ADDITIONAL 1750' OF 3-1/2" CT. STING IN PKR SEAL BORE & PRESS UP ANN TO CHECK IF SEALS STABBED IN-OK. SPACE OUT 1' ABOVE PKR. INSTALL CT CONNECTOR. MU 3' PUP JT, & WKM TBG HGR. LAND STRING IN TBG HEAD. RILDS. 42K UP, 12K DOWN. TEST ANN TO 2500 PSI FOR 15 MIN-0K. ND BOP STACK. SET CHECK VALVE IN TBG HGR. NU WKM TREE. TEST TREE & PACKOFF TO 5000 PSI-OK. PULL TEST PLUG. SECURE CTU. CLEAN UP LOCATION. CLEAN LOCATION/RELEASE RIG 5"~ 8772' MW: 0.0 RD DOWELL 3-1/2" CTU. CLEAN LOCATION. RELEASE DOWELL CTU @ 1200 HRS 08/24/93. 09/27/93 (21) TD: 8780 PB: 8682 SECURE WELL 5"~ 8772' MW: 0.0 WOW. RU SWS E-LINE UNIT. PRESS TEST LUB TO 3000 PSI. BLEED _+ .5 BBLS OFF OF TBGING & WHP=0 PSI. RIH W/GUN #1. TAG ~ 8476'. RKB. TIE IN 2-1/8" PHASED ENERJET GUNS & SHOOT C1 SAND F/8310'-8340' @ 6 SPF, 90 DEG PHASING W/EJIII, RDX DEEP PENETRATING CHARGES. POOH. ASF. MU & RIH W/GUN #2 & PERF F/8256'-8286' POOH. ASF. MU & RIH W/GUN #3. PERF F/8226'-8256' POOH. ASF. MU & RIH W/GUN #4. PERF F/8196'-8226' ASF. MU & RIH W/GUN #5. PERF F/8166'-8196' POOH. ASF. MU & RIH W/GUN #6. PERF F/8146'-8166' POOH. ASF. RD SWS. SECURE WELL. FINAL SITP=400 PSI. SIGNATURE: DATE: RECEIVED OCT- 5 199; alaska 0il & 6as 0OHS. c,u~.misslu" Anchorace SUB - SURFA CE DIRECTIONAL SURVEY r~l UIDANCE ~'J ONTINUOUS ~ OOL Aiaska Uil & Gas Cons. Commission' Anchorage Company ARCO ALASKA, INC Well Name 16-12 Field/Location 501' FNL & 170' ! FEL S9 TllN RIOE Job Reference No. Schwartz Date. Date 5-JUN-1993 Computed By: R. Sines DIRECTIONAL SURVEY COMPANY FIELD ARCO ALASKA INC. KUPARUK RIVER WELL 1B-12 COUNTRY USA RUN ONE DATE LOGGED -18 - MAY - 93 DEPTH UNIT FEET REFERENCE 93240 OCT - 199:. Alaska Oil & Gas Cons. GommisSioo Anchorage All Interpretations are c~lnlons ba~ed on Inferences from electrical or other measurement~ and we canno~, and do not guarantee the accuracy or correctness of any Interl3retaflons. and we shall not. except In the case of gross or wlffull r'~gllgence or,, our part. be liable or responslb~ for any loss. coe~. damages or exr)ensls Incurred or sustained by anyone resulting fi'om any Interpretation made by any of our officem, agent~ or employees. These Interr)retatlons are also subject to our General Terms and Conditions as se~t out In our current f~flce Schedule. 248.00 -2000 -1000 0 0 1000 2000 3000 4000 5000 6000 ( __ ::: : i; Ri: :!~i i:i:ii! ! iil ::: ! :i : : i i : : i"i'i'i ,-i'i'i'i i'"!'i ! 'h:i i i' i'ii i" 'i ! ! i"i"!'! !' i'"~"i ! ;'i ' ;' '! f i ~ ; : ; ~ : ' : ; ........... . -i i ~ ! ! !-!---i--.i-i--i i-i ..... i-!--!---! .... !--:~,:i-! ..... i---i---i-!-~--!---i--i-.! 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[:..~ . ................................... :!!: :.:ii .... ~...[.Li_i:!~ !.:!.:. iii!..[!:: :iii i.::i~::.: .:. .: ... :,ii [.i;i.i..i.i::i..ii..}. i}~} i:ii.;;~i :i : i:;;:,;~ : ,,: ..:: : :: .::. :::. ::. ::: .:.: .. : .......... ::' :':: :.:: ::: :::: :: · .:'' :: : '' i i;:i ,',~ ,i~; ::,- ,.i, :::: :'~' i~i, :~i i. : .. il ....... ~ili ..i.i i.i...iii.i ...i. ii.-i, i--.i.i-i, i;.i.i .i.;;i i~ii i.i.i.-.i, ilii .~ i. i i..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.; : . . : .... : : ..... :: . :: .:. : :. ::.. :::. -::. :: ...... 66.00 -. PROJECTION ON VERTICAL PLANE 24.8.00 68.00 ~CALED IN VERTICAL DEPTHS HORIZ SCALE ~ I / 10OO IN/FT REC.EtVED OOT --$ t99~ Alaska Oil & Gas Cons. L;ommiss~o" Anchorage NORTH 5000 4000 3OOO 1000 -1000__ -2OOO SOUTH -3000 -2OO0 WEST REF 93240 SCALE = I / 1 OOO IN/FT !-! ...... !-!-~--!-~::::,..:; ;~;; .... 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 . ~ : i : . . i}i~. ~ii-i.i~ ~.;i.~ ~iii i-~i.i'i[~ i;-i[ ~;;; ;.;;; ;, ; i;.i; ;.. ...... ~: --:: : .- .::: :... :.: :;~. :-:. ;..: .... :: ~ : ~ !'~! !!'~"!'i"!'!!!' ~:~ '!!!! !! ! !!'~ !!~'! ':'!!! !!!! ~'!~!~ .... ~ ..... .. · :: ::: :. · : - . . : 21i: ~ii! :i~ , :: :: !:! : : ::: ::i: : . : ~ ;..!.!-.!...ill! ..... i--i~i i.-;-i.i, i-ii- i ..... ~...':{~:~oiii.~i;.i ~i :..i:., ; ;;I ~";I"!"'!;';'; '?";"ii'ii"!~!'i ;'III .... I'!'.I '..'.." ! .! ::. ! :: ~ ! :'' ' ! !' .......... . :::. ::::!.:.: :::: :::: .::: I;~: :.i :. ,' s : s ~ ; :-"i'"; .... ;..;.; !.- ;...; ;-i .... i...;-..!--.!..l ;..i-;.; .... i...i..i i i ;--~.;-..:-:-~ ~ .... :..:..~.s .... :..; .... s ..... :.~ · : i . : . . .i ~ . i...i i i.i ..... L..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'T'i"i .... !'i"!"i 'i !'i ; i ! !'~!' i'!"[ '"':"i }~ : : ! ; ~ : ! : : ~ ! · : .......... : . _ . : ................ -1000 0 1000 2000 3000 4000 5000 6000 RECEIVED OCT - 5 199 f .Alaska Oil & Gas Cons. (Jommission Anchorage SCHLUMBERGER GCT DIRECTIDNAL SURVEY CUSTOMER LISTING FOR ARCO A~SKA INC. lB-12 RECEIVED 0 CT -- 5 ~99~ .,'-Ilaska OJJ & Gas Cons. OommissioF' Anchorage KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 18-MAY-1993 ENGINEER' SCHWARTZ METHODS OF COMPLFFATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONrFO A TARGET AZIMLFFH OF NORTH 67 DEG 35 MIN EAST COMPUTATION DATE' 4-JUN-93 PAGE I ARCO ALASKA INC. 1B-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 18-MAY-1993 KELLY BUSHING ELEVATION' 102.00 ET ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 1OO FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG DIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -102 O0 100 200 299 399 499 599 699 798 896 0 0 O0 -2 O0 0 12 O0 98 O0 0 21 99 197 99 0 32 99 297 99 0 25 99 397 99 0 12 95 497 95 3 23 60 597 60 6 2 80 696 80 8 33 794 93 13 37 93 N 0 0 E S 56 9 W S 77 2 W S 59 47 W S 58 32 W S 56 33 W N 64 46 E N 69 58 E N 75 16 E N 76 4O E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -0 27 -0 76 -1 48 -2 28 -2 88 -0 82 '7 52 2O O0 38 83 O. O0 O. 73 O. 90 1.12 1.11 1.44 5.97 2,50 4.46 4.73 0 O0 N 0 28 S 0 64 S 1 O0 S 1 42 S 1 66 S 0 74 S 2 46 N 6 20 N 10 50 N 0 O0 E 0 18 W 0 55 W 1 18 W 1 89 W 243W 0 58W 7 12 E 19 08 E 37 67 E 2 2 0 7 20 39 0 O0 N 0 0 E 0 33 S 33 30 W 0 85 S 40 46 W 1 55 S 49 45 W 36 S 53 8 W 94 S 55 35 W 94 S 37 49 W 53 N 70 56 E O6 N 72 0 E 11 N 74 25 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 993 35 O0 1088 O0 1183 O0 1276 O0 1368 O0 1458 O0 1546 O0 1634 O0 1720 O0 1802 891.35 16 34 73 986.73 18 22 06 1081.06 20 25 26 1174.26 22 1 08 1266.08 24 32 24 1356.24 26 42 93 1444.93 28 8 58 1532.58 29 35 35 1618.35 32 42 44 1700.44 36 53 N 75 48 E N 75 38 E N 75 5 E N 74 37 E N 73 44 E N 72 16 E N 71 55 E N 70 59 E N 70 3 E N 69 28 E 64 99 94 73 127 59 163 54 202 85 245 91 291 95 339 98 391 30 448 32 2.02 1 67 1 82 2 09 2 18 2 22 1 22 2 27 4 69 4 76 16 83 N 24 32 42 52 65 79 94 112 131 63 36 E 23 N 92 59 N 124 07 N 159 81N 197 50 N 238 74 N 282 99 N 328 23 N 376 89 N 43O 65 56 N 75 8 E 47 E 95 57 E 128 55 E 165 64 E 204 98 E 247 92 E 293 59 E 342 98 E 393 55 E 450 60 N 75 19 E 76 N 75 20 E O0 N 75 14 E 58 N 75 2 E 80 N 74 40 E 94 N 74 16 E O4 N 73 53 E 33 N 73 25 E 3O N 72 58 E 2000 O0 1880 32 1778 32 40 44 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1955 O0 2030 O0 2105 O0 2181 O0 2255 O0 2330 O0 2406 O0 2482 O0 2555 14 1853 06 1928 47 2003 20 2079 68 2153 64 2228 97 2304 36 2380 47 2453 14 41 44 06 41 15 47 40 49 20 41 21 68 41 52 64 40 43 97 40 9 36 42 33 47 43 14 N 68 30 E N 68 11E N 68 13 E N 68 24 E N 67 35 E N 66 43 E N 66 54 E N 67 9 E N 66 55 E 1037 N 67 1E 1105 511 O0 577 33 643 56 709 24 774 54 841 26 907 44 972 04 73 95 4 07 0 39 0 54 0 78 2 90 0 45 2 52 0 37 2 18 0 42 154 37 N 489 08 E 512 87 N 72 29 E 178 203 227 252 278 304 329 355 381 99 N 550 59 N 612 87 N 673 18 N 733 28 N 795 38 N 856 59 N 915 15 N 976 91N 1038 68 E 579 18 E 645 21E 710 81E 775 23 E 842 05 E 908 54 E 973 05 E 1038 80 E 1106 04 N 72 0 E 15 N 71 36 E 72 N 71 18 E 94 N 71 2 E 52 N 70 43 E 55 N 70 26 E 05 N 70 12 E 65 N 70 0 E 78 N 69 49 E 3000 O0 2628 38 2526 38 43 5 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2701 O0 2774 O0 2848 O0 2921 O0 2994 O0 3069 O0 3145 O0 3221 O0 3297 51 2599 81 2672 03 2746 11 2819 74 2892 77 2967 59 3043 66 3119 61 3195 51 42 55 81 42 49 03 43 1 11 43 2 74 41 57 77 40 56 59 40 36 66 40 23 61 40 48 N 67 12 E 1174 38 N 67 20 E 1242 58 N 67 27 E 1310 61 N 67 37 E 1378 72 N 67 53 E 1446 N 68 15 E 1514 N 68 41E 1580 N 69 8 E 1645 N 68 56 E 1710 N 66 53 E 1775 97 63 74 91 80 85 0 15 0 06 0 17 0 29 0 55 1 64 1 09 0 O0 0 69 0 60 408 54 N 1101 85 E 1175 15 N 69 39 E 434 461 487 512 538 562 585 609 633 88 N 1164 04 N 1227 08 N 1290 90 N 1353 19 N 1416 46 N 1477 85 N 1538 O0 N 1599 44 N 1659 76 E 1243 55 E 1311 48 E 1379 67 E 1447 43 E 1515 92 E 1581 78 E 1646 42 E 1711 70 E 1776 29 N 69 32 E 28 N 69 25 E 35 N 69 19 E 58 N 69 15 E 23 N 69 12 E 53 N 69 9 E "~ . , 44 N 69 9 E 48 N 69 7 E ua$ ,..,u;l$. L,(JITIITliSSiO Anchorage arco ALASKA INC. 18-12 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 4-JUN-93 PAGE 2 DATE OF SURVEY: 18-MAY-1993 KELLY BUSHING ELEVATION: 102.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000 O0 3373 31 3271 31 40 45 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3449 O0 3525 O0 3601 O0 3678 O0 3755 O0 3832 O0 3907 O0 3981 O0 4055 20 3347 47 3423 99 3499 77 3576 78 3653 76 3730 53 3805 62 3879 84 3953 20 40 29 47 40 10 99 39 59 77 39 44 78 39 29 76 40 28 53 42 13 62 42 9 84 42 6 5000.00 4129.99 4027 99 42 6 5100.00 4204.42 4102 5200.00 4279.49 4177 5300 O0 4354.86 4252 5400 O0 4430.18 4328 5500 O0 4505.48 4403 5600 O0 4580.75 4478 5700 O0 4655.99 4553 5800 O0 4731.35 4629 5900 O0 4806.82 4704 42 41 34 49 41 11 86 41 6 18 41 11 48 41 10 75 41 12 99 41 9 35 41 3 82 40 58 6000 O0 4882 34 4780.34 41 4 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4956 O0 5030 O0 5104 O0 5177 O0 5251 O0 5325 O0 5399 O0 5474 O0 5547 77 4854.77 42 37 37 4928 37 42 37 O1 5002 O1 42 37 62 5075 62 42 36 30 5149 30 42 29 21 5223 21 42 7 66 5297 66 41 41 24 5372 24 42 9 89 5445 89 42 33 7000 O0 5621 78 5519 78 42 17 7100 7200 7300 7400 7500 7600 7700 7800 79O0 O0 5695 O0 5769 O0 5843 O0 5918 O0 5993 O0 6069 O0 6145 O0 6221 O0 6298 72 5593 60 5667 99 5741 54 5816 54 5891 28 5967 31 6043 73 6119 45 6196 72 42 26 60 42 5 99 41 50 54 41 50 54 40 53 28 40 28 31 40 33 73 40 1 45 39 46 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG MIN FEET N 66 42 E 1841 19 N 66 50 E 1906 N 67 2 E 1970 N 67 7 E 2035 N 67 6 E 2099 N 67 12 E 2163 N 67 0 E 2227 N 66 17 E 2293 N 65 54 E 2360 N 65 33 E 2427 29 97 34 41 2O O2 41 55 54 N 65 28 E 2494 59 N 65 4 E 2561 N 65 29 E 2627 N 67 35 E 2693 N 67 38 E 2758 N 67 47 E 2824 N 67 54 E 2890 N 67 55 E 2956 N 67 59 E 3022 N 67 56 E 3087 32 32 O2 8O 61 44 31 O4 65 N 67 29 E 3153 20 N 66 53 E 3219 N 66 27 E 3287 N 65 58 E 3355 N 65 49 E 3422 N 65 38 E 3490 N 65 25 E 3557 N 64 58 E 3624 N 65 51E 3691 N 67 1E 3758 97 66 30 96 53 84 54 11 74 N 66 38 E 3826 11 N 66 22 E 3893 N 69 1E 396O N 69 21E 4027 N 69 12 E 4094 N 66 43 E 4160 N 66 18 E 4225 N 66 4 E 4290 N 66 2 E 4355 N 66 17 E 4419 43 81 61 23 36 64 58 06 17 DEG/ZO0 0 26 0 33 0 15 0 O0 0 10 0 40 3 31 0 34 0 34 0 27 0 25 0 90 2 30 0 06 0 16 0 27 0 O9 0 12 0 20 0 22 0 96 0 56 0 50 0 15 0 22 0 19 0 57 0 52 3 13 0 75 0 10 0 53 1 69 0 25 0 62 1 O0 1 72 2 19 0 34 0 75 FEET FEET FEET DEG MIN 659.25 N 1719 74 E 1841.77 N 69 2 684.93 N 1779 710 26 N 1839 735 34 N 1898 760 26 N 1957 785 04 N 2016 809 79 N 2075 836 20 N 2135 863 40 N 2197 89O 57 E 1906 83 N 68 57 08 E 1971 38 E 2035 40 E 2099 18 E 2163 O1E 2227 94 E 2293 34 E 2360 93 N 2258.44 E 2427 47 N 68 53 82 N 68 50 86 N 68 46 63 N 68 44 43 N 68 41 78 N 68 37 88 N 68 33 82 N 68 28 918 72 N 2319 51E 2494 83 N 68 24 E 946 974 1000 1025 1050 1075 1100 1124 1149 63 N 2380 58 N 2440 40 N 2500 49 N 2561 45 N 2622 27 N 2683 03 N 2744 69 N 2805 30 N 2865 19 E 2561 05 E 2627 47 E 2693 28 E 2758 17 E 2824 15 E 289O 19 E 2956 12 E 3022 94 E 3087 52 N 68 19 E 48 N 68 14 E 17 N 68 12 E 95 N 68 11E 75 N 68 10 E 59 N 68 10 E 45 N 68 9 E 19 N 68 9 E 80 N 68 9 E 1174.13 N 2926 61 E 3153 35 N 68 8 E 1200.02 N 2988 1226.84 N 3050 1254'.17 N 3112 1281.81N 3173 1309.60 N 3235 1337.49 N 3296 1365.49 N 3357 1393.54 N 3417 1420.16 N 3480 15 E 3220 31E 3287 20 E 3355 99 E 3423 62 E 3490 94 E 3557 54 E 3624 97 E 3691 15 E 3758 11 N 68 7 E 79 N 68 5 E 41 N 68 3 E 05 N 68 1E 60 N 67 58 E 90 N 67 55 E 59 N 67 52 E 14 N 67 49 E 76 N 67 48 E 1499.57 N 3665 1523.13 N 3728 1546.68 N 3790 1571.44 N 3852 1597.49 N 3912 1623.77 N 3971 1649.95 N 4030 1675.92 N 4089 1446.74 N 3542.07 E 3826.14 N 67 47 E 1473.57 N 3603 82 E 3893.44 N 67 46 E 98 E 3960.82 N 67 45 E 52 E 4027 63 N 67 47 E 87 E 4094 26 N 67 48 E 20 E 4160 39 N 67 48 E 07 E 4225 67 N 67 47 E ~} ~ ~,_...___ 48 E 4290 60 N 67 46 E ~ LklVED 42 E 4355 07 N 67 44 E 06 E 4419 18 N 67 43 E ,r ~.j T -- 5 1993 (~as Cons. C0mmissio Anchorage ARCO ALASKA INC. 18-12 KUPaRUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 4-JUN-93 PAGE 3 DATE OF SURVEY: 18-MAY-1993 KELLY BUSHING ELEVATION: 102.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH ]-RUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FEET FEET DEG MIN 8000 O0 6375 25 6273 25 40 19 N 66 20 E 4483.20 8100 8200 8300 8400 8500 8600 8700 8780 O0 6449 O0 6523 O0 6598 O0 6673 O0 6748 O0 6825 O0 6902 O0 6964 51 6347 08 6421 46 6496 31 6571 62 6646 09 6723 37 6800 23 6862 3 27 1701 62 n 4147 73 E 4483 21 N 67 42 E 51 43 31 N 64 2 E 4550.09 3 08 40 52 N 63 41 E 4617.62 1 46 41 30 N 66 0 E 4683.25 1 31 41 31 N 67 12 E 4749.'56 0 62 40 37 N 68 38 E 4815.34 1 09 39 37 N 70 41E 4879.73 1 37 39 22 N 71 48 E 4942.49 0 23 39 22 N 71 48 E 4993.09 0 64 1729 62 1759 34 1787 48 1814 84 1838 89 1861 O0 1880 O0 1896 60 N 4208 93 N 4269 78 N 4328 05 N 4389 96 N 4450 24 N 4510 79 N 4570 64 N 4618 54 E 4550 08 E 4617 60 E 4683 48 E 4749 36 E 4815 82 E 4879 65 E 4942 85 E 4993 09 N 67 40 E 62 N 67 36 E 25 N 67 34 E 56 N 67 33 E 34 N 67 33 E 73 N 67 35 E 49 N 67 38 E 09 N 67 41E E,CE · Af'ask~ OiJ & Gas Cons. C;ommiss~o" Anchorage COMPUTATION DATE: 4-JUN-93 PAGE 4 ARCO ALASKA INC. 18-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 18-MAY-1993 KELLY BUSHING ELEVATION: 102.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 GO 1000 2000 3000 4000 5000 6000 7000 8000 8780 O0 993 O0 1880 O0 2628 O0 3373 O0 4129 O0 4882 O0 5621 O0 6375 O0 6964 0 O0 -102 O0 0 0 N 0 0 E 0 O0 35 891 99 32 1778 O0 38 2526 38 31 3271 19 99 4027 59 34 4780 20 78 5519 11 25 6273 20 23 6862 09 35 16 34 N 75 48 E 64 32 40 44 N 68 30 E 511 38 43 5 N 67 12 E 1174 31 40 45 N 66 42 E 1841 99 42 6 N 65 28 E 2494 34 41 4 N 67 29 E 3153 78 42 17 N 66 38 E 3826 25 40 19 N 66 20 E 4483 23' 39 22 N 71 48 E 4993 0.00 2.02 16 4.07 154 0.15 4O8 0.26 659 0.25 918 0.96 1174 0.10 1446 3.27 1701 0.00 1896 0 O0 N 83 N 63 37 N 489 54 N 1101 25 N 1719 72 N 2319 13 N 2926 74 N 3542 62 N 4147 64 N 4618 0 O0 E 0.00 N 0 0 E 36 E 65.56 N 75 8 E 08 E 512.87 N 72 29 E 85 E 1175.15 N 69 39 E 74 E 1841.77 N 69 2 E 51 E 2494.83 N 68 24 E 61 E 3153.35 N 68 8 E 07 E 3826.14 N 67 47 E 73 E 4483.21 N 67 42 E 85 E 4993.09 N 67 41E 51995 .Alaska Oil & Gas Cons. Commission" Anchorage COMPUTATION DATE' 4-JUN-93 PAGE $ ARCO ALASKA INC. 18-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 18-MAY-1993 KELLY BUSHING ELEVATION' 102.00 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 102 O0 202 O0 302 O1 402 O1 502 O1 602 05 702 42 803 24 905 23 0 O0 -102 O0 102 202 302 402 5O2 602 702 8O2 902 0 0 O0 0 O0 0 12 O0 100 O0 0 21 O0 20O O0 0 32 O0 3OO O0 0 25 O0 400 O0 0 12 O0 50O O0 3 28 O0 600 O0 6 5 O0 700 O0 8 41 800 O0 13 52 O0 N 0 0 E S 58 35 W S 78 27 W S 57 53 W S 60 50 W S 48 59 W N 6449 E N 70 6 E N 75 32 E N 76 38 E VERTICAL DOGLEG RECTANGULAR COORDINATES hORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEC/lO0 FEET FEET FEET DEC MIN 0 O0 -0 28 -0 77 -1 49 -2 30 -2 88 -0 68 7 77 20 47 40 07 0 O0 0 71 0 89 1 08 1 12 1 61 5 55 2 25 4 69 4 60 0 O0 N 0 28 S 0 65 S 1 O1 S 1 42 S 1 66 S 0 69 S 2 55 N 6 32 N 10 79 N 0 O0 E 0 19 W 0 56W 120 W 1 90 W 2 43 W 0 46 W 7 36 E 19 53 E 38 89 E 0 O0 N 0 0 E 0 0 1 2 2 0 7 2O 4O 34 S 33 50 W 86 S 41 10 W 57 S 49 48 W 37 S 53 11W 95 S 55 37 W 82 S 33 36 W 79 N 70 54 E 53 N 72 4 E 36 N 74 29 E 1009.03 1002 O0 1114.00 1102 1220.24 1202 1327.84 1302 1437.40 1402 1549.19 1502 1662.67 1602 1778.34 1702 1899.45 1802 2028.79 1902 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 16 44 O0 18 37 O0 20 48 O0 22 43 O0 25 23 O0 27 32 O0 28 55 O0 31 48 O0 36 52 O0 41 32 N 75 46 E N 75 35 E N 74 59 E N 74 29 E N 73 7 E N 72 2 E N 71 28 E N 7O 6 E N 69 28 E N 68 13 E 67 56 99 13 134 67 174 05 218 52 268 30 321 80 379 80 447 98 529 93 1 86 1 90 1 85 2 95 2 58 1 24 1 52 3 91 4 78 1 75 17 46 N 25 34 44 57 72 89 108 131 161 34 N 96.78 E 100 44 N 131.47 E 135 89 N 169 76 E 175 30 N 212 74 E 220 40 N 260 36 E 270 12 N 311 33 E 323 31 N 366 16 E 381 78 N 430 24 E 449 36 N 506 68 E 531 65.88 E 68 15 N 75 9 E 04 N 75 20 E 91 N 75 19 E 59 N 75 11E 32 N 74 56 E 24 N 74 28 E 84 N 74 2 E 84 N 73 31E 97 N 72 58 E 75 N 72 20 E 2162 63 2002 O0 1900.00 41 25 2295 2427 2562 2693 2826 2963 3100 3237 3373 41 2102 82 2202 O0 2302 50 2402 75 25O2 86 2602 67 2702 09 2802 84 2902 O0 2000.00 40 50 O0 2100.00 41 54 O0 2200.00 41 22 O0 2300.00 40 7 O0 2400.00 42 57 O0 2500.00 43 10 O0 2600.00 42 55 O0 2700.00 42 55 O0 2800.00 43 5 N 68 12 E N 68 24 E 7O6 N 67 6 E 793 N 66 47 E 882 N 67 9 E 967 N 66 51E 1055 N 67 8 E 1149 N 67 20 E 1243 N 67 29 E 1335 N 67 5O E 1429 618 89 23 O1 47 85 89 68 04 84 11 0.26 0 74 1 7O 1 23 0 26 0 83 0 32 0 O6 0 33 0 25 194.43 N 589 26 E 620 51 N 71 44 E 226.76 N 670 259.29 N 75O 294 56 N 833 327 96 N 911 362 28 N 992 398 95 N 1079 435 06 N 1165 470 70 N 1250 506 17 N 1337 41E 707 86 E 794 09 E 883 67 E 968 75 E 1056 08 E 1150 18 E 1243 86 E 1336 12 E 1429 72 N 71 19 E 37 N 70 57 E 63 N 70 32 E 87 N 70 13 E 78 N 69 57 E 47 N 69 43 E 75 N 69 32 E 49 N 69 23 E 72 N 69 16 E 3509 74 3002 O0 2900 O0 41 49 3642 56 3102 3774 18 3202 3905 80 3302 4O37 85 3402 4169 27 3502 4300 O1 3602 4430 20 3702 4559.86 3802 4692.54 3902 O0 3000 O0 4O 39 O0 3100 O0 40 24 O0 3200 O0 40 49 O0 3300 O0 40 40 O0 3400 O0 40 12 O0 3500 O0 39 59 O0 3600.00 39 42 O0 3700.00 39 34 O0 3800.00 42 12 N 68 18 E 1521 13 N 69 0 E 1608 53 N 69 6 E 1694 O8 N 66 49 E 1779 64 N 66 45 E 1865 N 66 59 E 1951 N 67 7 E 2035 N 67 7 E 2118 N 67 13 E 2201 N 66 18 E 2288 87 14 35 71 25 41 1 53 0 37 0 26 0 42 0 26 0 28 0 O0 0 21 1 13 0 51 540 59 N 1422.46 E 1521 72 N 69 11 E 572 13 N 69 10 E 603 71 N 69 9 E 634 26 N 69 6 E 669 43 N 69 0 E 702 65 N 68 54 E 735 82 N 68 50 E 799 66 N 68 42 834 78 N 68 38 E OCT - 5 199 Alaska Oil & Gas Cons. Commission Anchorage 50 N 1503 85 E 1609 O1N 1583 80 E 1694 92 N 1663 19 E 1780 O0 N 1742 42 E 1866 52 N 1820 82 E 1951 34 N 1898 38 E 2035 77 N 1975 18 E 2119 77 N 2051.26 E 2201 18 N 2131.35 E 2288 COMPUTATION DATE' 4-JUN-93 PAGE 6 arco ALASKA INC. 1B-12 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- 18-MAY-1993 KELLY BUSHING ELEVATION- 102.00 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4827 48 4002 O0 3900 O0 42 6 4962 5096 5229 5362 5495 5628 5761 5893 6026 26 4102 77 42O2 89 4302 57 4402 38 4502 25 4602 07 4702 62 4802 14 4902 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 42 9 O0 41 35 O0 41 4 O0 41 9 O0 41 10 O0 41 13 O0 41 5 O0 40 59 O0 41 24 N 65 49 E 2378 97 N 65 34 E 2469 n 65 5 E 2559 N 66 32 E 2646 N 67 35 E 2734 N 67 47 E 2821 N 67 55 E 2909 N 67 59 E 2~96 N 67 57 E 3083 N 67 20 E 3170 28 18 97 16 57 O6 47 47 43 0 32 0 49 0 91 2 34 0 14 0 27 0 O0 0 02 0 21 2 O8 870 94 N 2214 16 E 2379 29 N 68 32 E 908 945 982 1016 1049 1082 1115 1147 1180 22 N 2296 72 N 2378 57 N 2458 10 N 2538 30 N 2619 27 N 2700 10 N 2781 73 N 2862 74 N 2942 47 E 2469 24 E 2559 01E 2647 50 E 2734 35 E 2821 40 E 29O9 41E 2996 07 E 3083 51E 3170 54 N 68 25 E 38 N 68 19 E 12 N 68 13 E 31 N 68 11E 71 N 68 10 E 20 N 68 10 E 62 N 68 9 E 62 N 68 9 E 57 N 68 8 E 6161 45 5002 O0 4900 O0 42 36 6297 6433 6568 6703 6837 6973 7108 7243 7377 27 5102 12 5202 66 5302 13 5402 61 5502 26 5602 51 5702 60 5802 81 5902 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 550O O0 5600 O0 5700 O0 5800 O0 42 36 O0 42 35 O0 42 17 O0 41 41 O0 42 39 O0 42 17 O0 42 28 O0 41 56 O0 41 49 N 66 37 E 3261 57 N 65 58 E 3353 N 65 46 E 3445 N 65 31E 3536 N 64 57 E 3626 N 66 55 E 3716 N 66 40 E 3808 N 66 21E 3899 N 69 28 E 3989 N 69 18 E 4079 45 36 81 62 47 13 16 97 44 0 32 0 19 0 44 0 49 0 49 I 52 0 13 0 59 0 27 0 24 1216 45 N 3026 38 E 3261 70 N 68 6 E 1253 1291 1328 1366 1403 1439 1475 1509 1541 42 N 3110 O0 N 3194 75 N 3277 38 N 3359 68 N 3441 61N 3525 87 N 3609 89 N 3693 44 N 3777 52 E 3353 43 E 3445 78 E 3536 42 E 3626 23 E 3716 56 E 3808 07 E 3899 27 E 3989 56 N 68 3 E 44 N 68 0 E 87 N 67 56 E 66 N 67 52 E 5O N 67 49 E 15 N 67 47 E 18 N 67 46 E 99 N 67 46 E 04 E 4079.47 N 67 48 E 7511.19 6002 O0 5900 O0 40 50 7643.02 6102 7774.24 6202 79O4.62 6302 8035.42 64O2 8171.90 6502 8304.73 6602 8438.27 6702 8569.95 6802 8699.52 6902 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 40 29 O0 40 2 O0 39 45 O0 41 40 O0 41 52 O0 41 32 O0 41 18 O0 39 57 O0 39 22 N 66 35 E 4167 69 N 66 7 E 4253 57 N 66 2 E 4338 50 N 66 17 E 4422 12 N 65 43 E 4506 41 N 63 12 E 4599 08 N 66 4 E 4686 39 N 67 29 E 4774 88 N 70 12 E 4860,52 N 71 48 E 4942.18 0 48 0 48 0 32 0 63 4 31 5 80 1 23 1 31 1 13 0 O0 1574 33 N 3858 93 E 4167 71 N 67 48 E 1608 1643 1677 1711 1751 1789 1823 1854 1880 77 N 3937 22 N 4015 11N 4091 O5 N 4168 62 N 4252 05 N 4331 81N 4412 80 N 4492 70 N 4570 63 E 4253 28 E 4338 77 E 4422 94 E 45O6 46 E 4599 46 E 4686 84 E 4774 7O E 4860 36 E 4942 59 N 67 47 E 51 N 67 45 E 13 N 67 43 E 42 N 67 41E 08 N 67 37 E 39 N 67 33 E 88 N 67 33 E 52 N 67 34 E 19 N 67 38 E 8780.00 6964.23 6862.23 39 22 N 71 48 E 4993.09 0.00 1896.64 N 4618.85 E 4993.09 N 67 41 E RECEIVED 5 t995 Alaska (ill (~ (SaS gOllS, t, ulld'flicJ~tO'' Aliei']orage COMPUTATION DATE: 4-JUN-93 PAGE 7 ARCO ALASKA INC. lB-12 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING 5" LINER TOP 7" CAS'lNG TOP KUPARUK C GCT LAST READING PBTD 5" LINER BOTTOM DATE OF SURVEY' 18-MAY-1993 KELLY BUSHING ELEVATION' 102.00 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 501' FNL A 170' FEL, SEC9 TllN RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NOR'TH/SOUTH EAST/WEST 5081 O0 7666 O0 7958 O0 8135 O0 8642 O0 8684 O0 8772 O0 8780 O0 4190 23 6119 47 6343 06 6474 87 6857 55 6890 O0 6958 04 '6964.23 4088 23 6017 47 6241 06 6372 87 6755 55 6788 O0 6856 04 6862 23 941 32 N 1614 81N 1690 81N 1740 32 N 1869 83 N 1877 62 N 1895 05 N 1896 64 N 2368 72 E 3951 27 E 4123 O1E 4230 15 E 4536 06 E 4561 O1E 4614 03 E 4618 85 E r'U0T-- ,5 199, AJask~ Oil & Gas Cons. Commission, Anchorage ARCO ALASKA INC. 18-12 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C PBTD TD COMPUTATION DATE: 4-JUN-93 PAGE 8 DATE OF SURVEY: 18-MAY-1993 KELLY BUSHING ELEVATION: 102.00 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 501' FNL & 170' FEL, SEC9 TllN RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 8135.00 6474.87 6372.87 1740.32 N 4230.15 E 8684.00 6890.00 6788.00 1877.62 N 4S61.01E 8780.00 6964.23 6862.23 1896.64 N 4618.85 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8780.00 6964.23 6862.23 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4993.09 N 67 41 E qtaska Oil & Gas Cons. Anchorage, ARCO Alaska, Inc. Date: July 23, 1993 Transmittal #: 8812 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this transmittal. ~i'O,,~29 ~'I 3"~bls Tape and Listing: · 10-18-92 92622 ~1"/'; LIS Tape and Listing: .9-18-93 92563 -07 ~' n/'TBit Runs of CDR. Corrected HLDT '.-1'R-"4'L'21 F~,t,,\f__ 3 Bit Runs of CDR. Corrected HLDT ~ ~ LIS Tape and Listing: 3-27-93 93132 U~.~o~ ./fl .~.O CDR/CDN & QRO Enhanced Resistivity ~''~i~'/EM-32 ~,, LiS Tape and Listing: 11-17-92 - 92686 \'\CDR Runs 1 & 2, Averaged Cased Hole HLDT LIS Tape and Listing' 6-26-93 93292 ~,'l~ DTE/SDN & CNTH , /30 ~ ' LIS Tape and Listing: 6-9-93 93263 /~..,~\~ CDR/CDN & GR CBT in LDWG Format .~.~.-22 "'~' ,LIS Tape and Listing: 5-29-93 93244 ~'~.. ~,,~ ~L~CDR/CDN in 1 Bit Run, GR from CBT - ~ ).,..1.'Y--'17 ¢'''~, t /LiS:Tape and Listing: 5-23-93 ,,~,/-.,CDR Runs 1 & 2, CDN Run 2, QRO Processed ~:~'~' ~;I.8<12 "1 LIS Tape and List, ng: 5-18-93 ~'"'.-- CNTG/HLDT & Arithmetic Average _ /~chdrage , DISTRIBUTION: Please acknowledge receipt 93241 93239 Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: July 02, 1993 Transmittal #: 8786 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 1 B-12 HLDT-Corrected Casedhole 5-18-93 Density Bulk Density, Neutron Porosity, Gamma Ray 2" & 5" TVD Dual Propagation Resistivity, Gamma Ray 2"& 5" TMD Bulk Density, Neutron Porosity Gamma Ray 2" & 5" TMD Dual Propagation Resistivity, Gamma Ray 2" & 5" TVD i3W-07 v" 3W-O7x/~ Please acknowledge 7970-8682 4-07-93 1 710-10350 4-07-93 1710-10350 4-07-93 1710-10350 4-07-93 1710-10350 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Date' '~laska 011 &Anchorage~a~ Con& Co~m/~ion VendorPackage(Johnston) NSK State of Alaska(+Sepia) Catherine Worley(Geology) ARCO Alaska, Inc. Date: June 25, 1993 Transmittal #: 8779 RETURN TO: ARCO Alaska, Inc. At'tn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 1 B-12 2" Slim 1 Gamma Ray 5-2-93 Acknowledged: Please acknowledge 121-8780 Date: DISTRIBUTION: D&M Drilling VendorPackage(Johnston) NSK State of Alaska(+Sepia) Kathy Worley(Geology) ARCO Alaska, Inc. Post Office B~)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 21, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Application for Sundry Approvals on the following Kuparuk well. Well Action Anticipated Start Date 1 B- 1 2 Waiver July 1 993 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering Attachments RECEIVED JUI',,', 199 5 Alaska Oil & Gas Gens. Gom~'nission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ALASKA OIL AND C.¢.S ~SERVATION COMMIS,~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon w Suspend__ Operation Shutdown __ Re-enter suspended well Alter casing ..... Repair well Plugging Time extension Stimulate Change approved program __ Pull tubing __ Variance _.X. Perforate __ Other 2. Name of Operator 5. Type of Well: 16. Datum elevation (DF or KB) Development m I Exploratory _ I RKB 102 feet ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service 4. Location of well at surface 501' FNL, 170' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 1261' FSL, 1190' FEL, Sec. 3, T11N, R10E, UM At effective depth 1391' FSL, 862' FEL, Sec. 3, T11N, R10E, UM At total depth 1409' FSL, 814' FEL, Sec. 3, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7. Unit or Property name Kuparuk River Unit 8. Well number 1B-12 9. Permit number 93-61 10. APl number so-029-22365 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 8 7 8 0 feet Plugs (measured) None 6 9 5 4 feet Effective depth: measured 8 6 8 2 feet Junk (measured) None true vertical 6875 feet Casing Length Size Cemented Structural Conductor 1 21' 1 6" 300 Sx AS II Surface 5 04 1 ' 9 - 5 / 8" 1010 Sx Perm E & Intermediate 450 Sx Prem G Production 7930' 7" 750 Sx Prem G Liner 1 1 07' 5" 170 Sx Prem G Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Measured depth True vertical depth 121' 121' 5081' 4170' 7958' 6320' 8772' 6946' EEE VED I Alaska 0il & Gas Cons. Commission Anchorago 13. Attachments Description summary of proposal ~ Install sub-surface, spring controlled safety valve in water 14. Estimated date for commencing operation 15. July 1993 16. If proposal was verbally approved Name of approver Date approved Detailed operation program_ injection well. BOP sketch Status of well classification as: Oil __ Gas Suspended Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C-~J. ~ Title FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form require 10- /¢~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W.~ Johnston IApprova_l No. Approved Copy Returned Commissioner Date 4,/z y//'~ ,~ SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1B-12 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to install a downhole, spring-controlled, injection valve in Injection Well 1B-12. This injection valve will act as a one-way check valve allowing downward injection of water while preventing upward flow of the injected fluid. The injection valve is capable of preventing uncontrolled upward flow by automatically closing if such an event should occur. This well's completion design, scheduled to be installed in early July, will not include a hydraulic control line from the surface to the subsurface valve, however a landing nipple will be installed at approximately 1800' to accept the spring-controlled injection valve. Installation of the valve would be performed following the original completion and prior to initial water injection. Attached is a schematic of the proposed injection valve. & Gas Coils. Commissio~'~ Anchorage Attachment 2 Injection Valve Schematic TOP SUB ORIFICE SPRING ..! ~ GUIDE SEAT SEAT INSERT Otis MC Injection Valve FLAPPER VALVE AND SPRING ASSEMBLY Oil & Gas Cons. Anchorage ARCO Alaska, inc. Date' June 18, 1993 Transmittal #' 8767 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1B-12 Sub-Surface Directional 6-5-93 93240 Survey Receipt Acknowledged: Date: DISTRIBUTION' , D&M State of Alaska (2 copies) ARCO Alaska, Inc. / Date: June 04, 1993 Transmittal #: 8¢55 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following _~.en ho~ items. receipt and return one signed copy of ~mittat. CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected CDN-LWD/Depth Corrected CDR-LWD/Depth Corrected HLDT-Corrected CH Density HLDT-Corrected CH Density HLDT-Corrected CH Density Please acknowledge Receipt Acknowledged' DISTRIBUTION: D&M NSK 3/2-5/93 4414-7561 3/2-5/93 4414-7561 3/17-20/93 5317-11034 3/!7-20/93 5317-11034 1/9/93 8000-9336 5/18/93 8030-8682 1/8/93 1 0448-1 2014 Drilling St..ate. o f_ Alaska(+Sepia) Date: VendorPackage(Joh nsto~ Kathy ARCO AlaSka, inc. Date: May 28, 1993 Transmittal #: 8753 RETURN TO: ARCO Alaska, inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the followi~e items. receipt and return one signed copy of thT~-a~"r~'al. Please acknowledge Cement Evaluation Log Cement Bond Log 5-17-93 5-17-93 7650-8681' 7650-8656 Receipt Acknowledge: Drilling Date: ~State of Alaska(+sepia) NSK ~ ¢'/~, 4"4¢) MEMORANDUM Stale of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnst..~, Chairma~ DATE: May 13, 1993 THRU: Blair Wondzell, ~.~ FILE NO' P. I. Supervisor spector jh-rep49.doc Diverter Test - Parker 245 ARCO, KRU, 1 B-12 Kuparuk River Field PTD Cf 93-61 Sunday, May 2, 1993: I traveled to Kuparuk's lB pad and witnessed the function test of Parker 245's diverter system. The rig had just moved from 1H pad. The Diverter Systems Inspection Report is attached for reference. The function test began at 9:00 a.m. and went well. I found the rig to be in excellent condition. Company man Mike Whiteley and tool pusher Darrel Gladden did a fine job during the function test. All components functioned properly and no problems were found. There were two separate 10" ball valves off of the 20" hydrill diverter. The controls were such that either the starboard 10" ball valve or the port side 10" ball valve would open (not together) when the bag closed depending on prevailing wind conditions. The 10" lines had 3 targeted tee's each and were vented sufficiently far enough away from ignition sources. I found the layout acceptable for the situation. Summary: A successful diverter test was witnessed on Parker 245, drilling well lB- 12 for ARCO, Kuparuk River Field. Attachment DMg Contractor. Operator. Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: ~o(~ ~ K ~ ' Rig No. ~(~(~0 ALA~$iL A, ~(.. O~r. Rep.: ~ ~ I~ - I ~' Rig Rep.: q T. .. Date: ._~//~/fly Development '~ Exploratopj: ,~,'~ PDT # q~-~l Rig Ph. Me~ian ~ ~ ....................................................... ~BT.D.A.T.A ..................................................................... · ....................... MISC. INSPECTIONS: ACCUMULATOR SYSTEM:- Location Gen.: (2oo~ Well Sign'~/..-/~o]) Systems Pressure: v~C~ psig HousekeePing: C~6o1') (Gen.) Drlg. Rig~ .~ [,~:)0 . psig Reserve Pit: b} [/~ Flare Pit: N/A 200 psi Attained After Closure: c:::) min. / ~ sec. Systems Pressure Attained: '~ min. ~-D sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: (.,, Diverter Size: ~ O, in. ~ Z ma, 1 ;;~0,, 2 ;~. ~,~o, ~. t :}S)D psig Divert Valve(s) Full Opening: . '~&$ ' ~SU~AL Valve(s) Auto & Simultaneous: ¥~5 MUD SYSTEM INSPECTION: ~ Alarm Vent Line(s) Size: ~ in. Trip Tank: 0/~ ~/A Vent Line(s) Length: '1~ ~' 73 ft. Mud Pits: .Line(s) B!fur~ed~~~ i~.: .~ ~ /,.~ ~f:. Flow Monitor: 'Line(s) DOwn Wind: " ,,Line(s) Anchored: ...i.''~ ~.~ GAS DE~ECTORS:, Light Alarm. Tums Targeted I Long Radius: Methane " Hydrogen Sulfide: ......... DIVERTER SCHEMATIC .. · · I0" / ~F '_~-"' . . '75 ~, Distribution orig. - Well File c - Oper/Rep AOGCC REP.: c - Database c - Trip Rpt File OPERATOR REP.: c - Inspector F1-022 Dvtrinsp2 WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 April 26, 1993 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit lB-12 ARCO Alaska, Inc. Permit No. 93-61 Sur. Loc 501'FNL, 170'FEL, Sec. 9, TllN, R10E, UM Btmhole Loc. 1417'FNL, 798'FEL, Sec. 3, TllN, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure Department of Fish & Game, Habitat Section w/o encl. D~pa~%m~n% of Environmental Conservation w/o enc1. STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry I~ Deepen [] Service X Development Gas ri single Zone X Multiple Zone [] 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 102', Pad 61' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25648, ALK 466 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 501' FNL, 170' FEL, Sec. 9, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 4,050' FNL, 1,252' FEL, Sec. 3, T11N, R10E, UM 1B-12 #UG630610 At total depth 9. Approximate spud date Amount 1,417' FNL, 798' FEL, Sec. 3, T11N, R10E, UM 4/28/93 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1B-08 8,776' MD 798' @ TD feet 16' @ 800' MD feet 2,560 6,941' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 41 o Ma)dmumsurface 2,470 psig At total depth (TVD) 4,01 6 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling] Length MD TVD MD TVD (include sta~]e data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 47.0# L-80 BTC 2,959' 41' 41' 3,000' 2,604' 630 Sx Permafrost E & 12.25" 9.625" 36.0# J-55 HF-ERW 2,090 3,000' 2,604' 5,090 4,173 450SxClassG 8.5" 7" 26.0# J-55 BTCMod 7,925' 41' 41' 7,966' 4,497' 100SxClassG HF-ERW 6.125" 5" 18.0# L-80 LT&C 1,110' 7,666' 6,312' 8,776' 6,941' 120SxClassG HF-ERW 1 9. To be completed for Reddll, 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 Oemented ~> ~CMp re~!~..,e~T~ True Structural Conductor Surface Intermediate ~,~,_.j.~3%~ '~ ~ Production Liner ,.*.'~q!,,,"~ /'~j ~' - Perforation depth: measured ~,q true vertical 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program/ X ..¢i-~e;',,' vs depth plot [] Refraction analysis [] Seabed report BI 20 AAC 25.050 requirements X 21. I hereby certify/t~t the forj~bing is true and correct to the best of my knowledge .// ,¢, /; - :. x-'-;' , Area Drilling Engineer Date ~ //' Commission Use Only Permit Number~ '' (.¢1~' IAPl number50- 0~.~ - ~1.-~,~. ~ (¢~""-- 0 0 I Appr°val dater"~ Isee c°ver letter f°r-¢-~~' ~:"~7. other requirements Conditions of approval Samples required I--I Yes [~ No Mud Icg required E] Yes [~ No Hydrogen sulfide measures [] Yes [~. No Directional survey required [~ Yes [] No Required working pressure for BOPE E] 2M aM ~ 5M FI I--I Other: Original Signed By David ~/'V. Johlqs'[oR by order of Approved by Commissioner the commission Date '/'- At, CO ALASKA, Created by · jones For: D STOLTZ Date plotted : 8-Apr-93 Plot Reference is 12 Version #4. Coordinates ore in feet reference slot #12. True Vertical Depths are reference wellhead. BAKER HUGHES : INTEQ Structure : Pad lB Well : 12 Field : Kuparuk River Unif Location : North Slope, Alaska N 67.59 DEG E 454Z' (TO TARGET) I I V - 150~_ _ 180(1_ - 2100_ _ 2400_ 27OO1 _ 3600_ _ 42~_ _ 4~_ _ _ 57~_ _ 63~~ 3~ RKB £LD/ATION: 102' Scale 1 : 175.00E Q s ~ t350 0 .350 700 1050 1400 1750 2100 [ I I I I I I i I KOP TYD=500 TMD=500 DFP=O - ~ BUILD 3 DEC; / 100' I SURFACE LOCATION: I:~.UU 501' FNL, 170' FEL ~,k21'00 [SEC. 9, TIlN, RIOE h,X 27-00 '~ 33.00 B/ P£~,FSO$'r ~ TVD=IS19 TMD:1575 DEP=295 , ----> 2450 280'0 3150 3500 3850 4200 4550 I I I I I I I I I L I I J I TARGET LOCATION: 4050' FNL. 1252' FEL SEC..3, TllN, RIOE TARGET TVD-6383 TMD=8033 OEP:4541 NORTH 1731 EAST 4198 ~_ ~750 105~ 0 ~50 X~W SAK SNDS TVD=$558 TMD=4271 DEP=2056 SEC. 5, T11N. RIOE AVERAGE ANGLE ~, B/ W SAK SNDS TVD=$973 TMD=4823 DEP=2421 41.33 DEG~ 9 5/8- CSG PT 1W0=4173 TMD=5090 OEP=2597 '~ A/B MODIFIED CSG ~=4255 TMD=5170 OEP=2650 10 ~=4575 TMD=5625 DEP=2951 K-5 WD=5147 TMD=6587 DEP=5454 7" CSGPT 'rVD=6333 TMD=T966 DEP=44-97~.~. TARGET - T/ KUP TVD=6383 TMD=8033 DEP=4541 ~% T/ ZONE C TVD=6418 TMD~8079 DEP=4572 x%% '%..%,%,. T/ ZONEA TVD=6682 TMD=843, DEP=4804 ~.X x~, X'.XX B/ KUP SNDS TVD=6791 TMD=8576 DEP=4900 TD / 5" L~NER TVD=6941 TMD=8776 DEP=5032 0 300 6OO 900 1200 1506, 1800 2100 2400 27 .3~ 530'0 5600 .39 4200 4500 4800 Scale 1 : 150.00 Vedical Section on 67,60 azimuth with reference 0,00 N, 0.00 E from slot #12 ARCO ALASKA, Ii1c 160 120 80 Structure · Pad lB Well · 12 Field · Kuparuk River Unit Location · North Slope, Alaska ~co,~,: ~o.oo E a s t - - > ~- 80 40 0 40 80 120 160 200 240 280 320 360 400 440 4.80 520 560 600 640 6.~0 720 680 [ I I r I I I i I I I I I~ I I I I { I I I I I I I I I i I I I t I I I I I I I I 680 600 i 560 t 0 1__300 280 520 8 360 .. 80 4-0 0 40 ;BO 120 160 200 240 280 320 360 400 440 480 520 560 600 64.0 6~0 720 ~o,~ ~: ~o.oo E a st - - > A I 160 [ © 120 fl6O 200 t240 L 320 © _ ~o ~ C) · . · . , o , · , 10 11 12 13 14 15 16 17 18 19 2O 21 22 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1B-12 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,090')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (7,966') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. Drill out cement and 10' of new hole. Perform leak off test to 13.0 ppg EMW. Drill 6-1/8" hole to total depth (8,776') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5" liner. Pressure test equivalent to .25 psi/ft. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 1B-12 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-9.6 15-25 15-35 45-75' Drill out to weight up 8.4-9.6 5-15 5-8 30-40 Weight up to TD See Well Plan 10-18 8-12 35-50 5-15 15-40 10-12 9.5-10 _+10% 2-4 4-8 8-10 9.5-10 4-7% 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,470 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1B-12 is 1B-08. As designed, the minimum distance between the two wells would be 16' @ 800' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. ' t:'~''~ , -i, ri Casing Design / Cement Calculations 11 -Apr-93 Well Number: Surface Csg MD: Surface Csg TVD: Intermediate Csg A MD: Intermediate Csg A TVD: Intermediate Csg B MD: Intermediate Csg B TVD: Production Liner MD: Production Liner TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Surface MW: ~lntermediate MW above Kuparuk: Estimated Mud Weight at Kuparuk: Surface Casing Choice: Intermediate Csg A Choice: Intermediate Csg B Choice: Production Liner Choice: Production Casing Frac. Pressure 1 H-22 5,O90 ft 4,173 ft 5,170 ft 4,233 ft 7,966 ft 6,333 ft 8,776 ft 6,941 ft 4,271 ft 8,033 ft 6,383 ft 10.5 ppg 9.5 ppg 12.4 ppg 6 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe = {(13.5'0.052)-0.11 }*TVDshoe =[ Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =1 4,173 ft 2,470 psiJ 12.4 ppg 6,383 ft 4,116 psi 4016 psiJ Surface lead: Top West Sak, TMD = 4,271 ft Design lead bottom 500 ft above the Top of West Sak = 3,771 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,181 cf Excess factor = 15% Cement volume required = 1,358 cf Yield for Permafrost Cmt = 2.17 cf/sk Cement volume required =[ 630 sx Surface tail' TMD shoe (surface TD - 500' above West Sak) * (Annulus area) = 5,O9O ft : 413 cf Length of cmt inside csg: 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 448 cf Excess factor = 15% Cement volume required = 515 cf Yield for Class G cmt = 1.15 cf/sk Cement volume required =L 450 sxJ Casing Design / Cement Calculations 11-Apr-93 Intermediate tail: TMD shoe= 7,966 ft Want TOC 500' above shoe = 7,466 ft Annulus area (9" Hole) - 0.1745 cf/If (TD-TOC)*Annulus area = 87 cf Length of cmt wanted in csg -- 80 ft Internal csg volume -- 0.2148 cf/If Cmt required in casing = 17 cf Total cmt = 104 cf Excess factor = 15% Cement volume required -- 120 cf Yield for Class G cmt = 1.18 cf/sk Cement volume required =1 100 sxJ Production Liner: MD at TD= 8,776 ft Liner Top (300' lap) 7,666 ft Annulus area (6.625" Hole) = 0.1032 cf/If (TD-TOC)*Annulus area = 115 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.0997 cf/If Cmt required in casing = 8 cf Total cmt = 123 cf Excess factor = 15% Cement volume required - 141 cf Yield for Class G cmt = 1.22 cf/sk Cement volume required =1 120 sxJ Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Surface (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (WEft) Casing Wt (Ib/ft) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Intermediate A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy -- Tension (Pipe Body) = Design Factor =1 564000 lb 5,O9O ft 36.0O Ib/ft 18324O.0 lb 33619.5 lb 149620.5 lb 639000 lb 5,O9O ft 36.00 Ib/ft 183240.0 lb 33619.5 lb 149620.5 lb 4.3J 415000 lb 7,966 ft 26.00 Ib/ft 207116.O lb 29675.5 lb 177440.5 lb Casing Design / Cement Calculations 11 -Apr-93 Intermediate A (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor = Intermediate B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/fi) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =l Intermediate B (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production Liner (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Production Liner (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = ns,on / oi t _, ~ ~ ~ '~' ~ Design Factor =l BURST - Minimum Design Factor =~,.. ; ~l'~q ~. 3 ~ ~'0"'~i;~.~Jo~ Surface Casing: , ,,:, ~asing Rated For: Burst = Maximum surface pre~:_~_~ ~}i~ _~ ~,~a~.~ Oo~s, O0f~tT;t$~:Max Shut-mn Pres = ~,~0~r~¢~ Design Factor =[ Intermediate Csg A: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating/Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =1 490000 lb 7,966 ft 26.00 Ib/ft 207116.0 lb 29675.5 lb 177440.5 lb 2.8J 415000 lb 2,796 ft 26.00 lb/fi 72696.0 lb 10415.9 lb 62280.1 lb 490000 lb 2,796 ft 26.00 Ib/ft 72696.0 lb 10415.9 lb 62280.1 lb 7.9J 422000 lb 1,110 ft 18.00 lb/fi 19980.0 lb 3771.1 lb 16208.9 lb 26.01 396000 lb 1,110 ft 18.00 Ib/ft 19980.0 lb 3771.1 lb 16208.9 lb 24.4J 3520 psi 2470.4 psi 1.41 4980 psi 6229 psi 1959 psi 4270 psi 1.2J Casing Design / Cement Calculations Intermediate Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Production Liner: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Intermediate Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Intermediate Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Production Liner: 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =1 Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = 11 -Apr-93 4980 psi 7584 psi 2931 psi 4653 psi 1.11 10140 psi 7976 psi 3212 psi 4763 psi 2.1J 2020 psi 0.546 Ib/ft 1342 psi 1.5J 4320 psi 0.494 Ib/ft 2091 psi 2.11 4320 psi 0.494 Ib/ft 3129 psi 1.4J 10490 psi 0.645 Ib/ft 4116 psi Casing Design / Cement Calculations 11-Apr-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength 1161OOO lb 979000 lb 639000 lb 931000 lb Body Strength 1O86OOO lb 916000 lb 564OOO lb 715O00 lb Collapse 4750 psi 3090 psi 2020 psi 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Intermediate Casing Choices OD ID Ib/ft Grade Metal X-Section 1 7.000 6.276 26 L-80 7.5491 sq. in. 2 7.000 6.276 26 J-55 7.5491 sq. in. Jt Strength 667OOO lb 490000 lb Production Liner Choices OD ID Ib/ft Grade Metal X-Section Jt Strength 5.000 4.276 18 L-80 5.2746 sq. in. 396000 lb Body Strength 6O4OOO lb 415000 lb Body Strength 422000 lb Collapse 5410 psi 4320 psi Collapse 10490 psi Burst 7240 psi 4980 psi Burst 10140 psi 5 4 13 5/8" 5000 BOP STACK ACCUMULATO:,-~. CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLU,O. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND r%_."~OVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC' OIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11"-3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 ...~PARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 6 4 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"-2000 PSI DRILLING SPOOL WITH ~O 10" OUTL~S. 5. 10" HCR BALL VALVES ~{ITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNU~R ~REVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNU~R PREVENTER EDF 3/10/92 State: Alaska Borough: Well: 1B-12 Field: Kupa~.~k River St. Perm # 93-61 1B-12CSG.XLS Date 4/15/93 Engr: M. Minder Casing- Interval Interval Size Bott°m Top Length lA 9.625 4178 41 5049 2A 7 4497 41 7925 3A 5 6941 6312 1110 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Description Description Description Tension Lbs Grade Thread Lbs 36 J-55 BTC 0 26 J-55 TC MOD 0 18 L-80 LT&C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Collapse Maximum Minimum Weight Gradient Gradient Pressure Yield ppg psi/It p$i/ft psi psi BDF 1B 9.8 0.510 0.410 2470 8520 1.4 219 9.6 0.499 0.399 2470 4980 2.0 3B 12.4 0.645 0.545 2470 10104 4.1 413 0.0 0.000 -0.100 0 0 #DIV/0! 5B 0.0 0.000 -0.100 0 0 #DIV/0! 613 0.0 0.000 -0.100 0 0 #DIV/O! 7B 0.0 0.000 -0.100 0 0 #DIV/0! 8B 0.0 0.000 -0.100 0 0 #DIV/O! 9B 0.0 0.000 -0.100 0 0 #DIV/O! 10B 0.0 0.000 -0.100 0 0 #DIV/O! Tension Strength K/Lbs K/Lbs 1C 181.764 564 415 422 2C 206.05 3C 19.98 4C 0 5C 0 6C 0 7C 0 8C 0 10C 0 Collapse Collapse TDF Pr-Bot-Psi Resist. CDF 3.10 1709 2020 1.182 2.01 1795 4320 21.12 3781 10490 2.774 0 #DN/'O! 0 0 #DIV/O! 0 #DIVIO! 0 0 #DNiO! 0 #DIVIOI. 0 0 #DIViO! 0 #DIV/0.1 0 0 #DIV/0! 0 #DIV,/0.1 0 0 #DIV,/0.1 0 #DIV,/O.I 0 0 #DIV/O.I 0 #DiV/0~. 0 0 #DIV/O.I Page 1 1B-12Ci~IT.XLS State: Well: Fiel~ State Permit 1B-12 Kuparuk River 93--61 Engineer:. Work Sheet: Date: £efr~n! Vol~zme £a/c~ations 4/i5/$$ C~'~g T j,9:~e C~ing Size -Inche~ Casing Length -Feel Hole Diarr~er -Inches Cement-Sacks 111 Cement- Y'~,d 111 Cement- Cubic l~t111 Cement- Cubic It 111 Cement-Sacks 112 Cement- Yield 112 Cement- Cubic tl 112 Cement-Cubic It ti2 Cement-Sacks 113 Cen'~ - Y'~d 113 Cement- Cubic It 113 Cement- Cubic ft 113 Cement- Cubic t~l 1 Vol Cement- Fill F~ctor Conduclor 16.000 80.000 24.000 0.000 0.000 0.000 200.000 0.000 0.000 0.000 0.0t30 200.000 1.432 Surface 9.625 5,049.000 12.250 630.000 2.170 1,367.100 1,367.100 450.000 1.150 517.500 517,500 0,000 0.000 0.000 0.000 1,884.600 1.192 Liner 5.000 1,110.000 6.125 120.000 1.220 146.400 146.400 0.000 0.000 0.000 0.000 146.400 1.932 Casing Tj,,pe Cadng Size Casing De~h Hole Diamete~ Cement- Sacks Cement-Yield Cement- Cubic tt Cement- Cubic tt Cement- Sacks Cement- Yield - Inche~ - Feel -Inches 111 111 111 111 112 112 Cement- Cubic fl 112 Cen'~nt - Cubic ti 112 Cement-Sacks 113 Ce~- Y~ld ~3 Ce~- ~ ~ ~3 C~enl - C~ ~t~3 Ce~- ~c ~t / V~ C~-I~ava fl Top of Cement- Feet Intermediate 111 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IIDIV/~ II:DIV/0! Intermediate 112 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0! IIDIV/0! Pdnted 4/15/93 Produclion 7.000 7,gGG.000 8.500 100.00 1.18 118.00 118.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 118.00 930.55 7,035.4 Mo~sure~ Depth or. ' mo ** CHECK LIST FOR NEW WELL PERMITS ::* ITEM APPROVE DATE (1) ,F. ee ~-., (2) .,Loc [2 thru 8] (3) Admin~L'8~-- -- IffA~3 9. E9 thru 13] 10. [10 g 13] 12. (4) Casg , ~ ~-]~ 9~ 14. [14 thru 22] 15. ~/',~., ~:.,':'~ (5) BOPE '",n .... .""~, ~'-/~-. ~'~ [23 thru 28] Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ YES NO REMARKS , 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... , , I s admi n i st rat i ve approval needed .................................... Is lease ntrnber appropriate .......................................... Does well have a unique name & number ................................ I s conductor st r ing provided ......................................... Wil to Is Wil Wil Wil Is Is Is Is 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. ,, enough cement used to circulate on conductor & surface..'. ......... 1 cement tie in surface & intermediate or production strings ...... 1 cement cover all known productive horizons ..................... 1 all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed ............................. a diverter system required ........................................ Is drilling fluid program schematic $ list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~_c~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Other '~ .... ),~ I~//~c/) [29 thru 31~ (7) Contact [32] (8) Addl /~/'~..~././ geology' engineering' DWd~ MTIVl,/~ RADS2... \ RPC__ BEW JDH~ .d/~ ~> LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLOP~ATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~rnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE fl otoo Se.,,- 1 o o vt. hIERIDIAN' remarks' UM . L-.--'-'-- SM Exp/Dev., I nj ./ .TYPE' Red ri I 1" Rev o -rz 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 ~mm~mm~mmm~mmmmmmmmmm~mmm~.~ ~mmmmmmmmmmmmmmmmmmmmmmmmmmm.~ FIELD NA~E : K[!P~U~ RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NURSER : 50-029-22365-00 REFERENCE NO : 93~39 ~rlCRoFmte. .LHED Tape verification Listlnq ;chlumberger AlasKa Computing Center 993 07: 25 MERVICE ~ME : MDTT DATE : 93/U6/14 ORI~I~ : FbIC REEL NA~tE : 93~39 CONTINUATION # : PREVIOUS RE~[0 : CONtEmPT : ARCO ~LASKA !NC,,~UPARU~ RIYER,IB-12,50-029-22365-O0 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 9]/06/14 ORIGIN : FLIC TAPE NA~E CONTINUATIt~N PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.,KUPARUE RIYER,~B-12,50-029-2~365-00 TAPE HEADER KUPARUK RIVER UNIT CASED HOLE WIRELINE bOGS WELL NAME~ APl ~UMBER: OPERATOR: LOGGING CO~PAMY: TAPE CREATION DATE~ JOB,NUMBER LOGGING £N~I~EER: OPERATOR WIT~ESS: SURFACE LOCATION SECTION: TOWNSHIP: FNL: FSL: ~EL: FWL: ELEVATIO~(FT FRO~ ~S5 O) ~EbLY BUSHING: ~ERRICK FLOOR: GROUND LEVEL; WELL CASING RECORD SURFACE LOCATION lST STRING 2ND STRI~G 3RD STRING PROOUCTION STRING 5002922R6500 ARCO ALASKA INC. SCMbH~BERGER WELL SERVICES 14-JUN-93 93239 SCHWARTZ FOSTER O9 10E 501 170 102.o0 102.00 61.00 ()PEN HOL~: CASING D~IbLERS CASING 5IT SIZE (IN) SIZE (IN) DEPT~ (FT) WEIGMT (LB/FT) 12,250 9, 25 36,00 8.500 7.000 7958.0 26,00 6.125 5,O00 8772,0 18,00 PAGE: IS Tape verification Listing ~-nCT-1993 07:25 ChlUmberqer AlasKa Computlmg Center CURV~ SHIFT OATA - AL5 PASSES TO STANDARD(~EASURED DEPTH) BASELINE CURVE FOR SHIFTS PSU TOOL CODE~ PLO CURYE CODE: RUN PASS glibBER: LOGGING CO~P~Y: .......... EOUI¥~LENT ONSHIFTED DEPTH-- .... ---- BASELINE DEPTF~ $ # RE,ARKS: NO OPEN HnbE TO CASED HOLE SHIFTS WERE APPLIED TO THIS DATA, FIELD ~NGINEER'S REMARKS: TIED INTO SWS CET DATED 5-17-93. HLDT/CNTG IS RA~ DATA PRODUCT.&~CO PERFOR~.E~ BY S~$ COMPUTING CEN]!.~R,MPUTATIONS~ TO BE ALL PASSES LOGGED AT 900 FPH. $ $ PAGE: **** FILE HEADER FILE NANE : EDIT .00! SERVICE : FLIC VERSION : DATE : 93/06/~4 MAX REC SIZE : FILF TYPE : LO LAST FILE : FILE H~ADER FILE EDITED CURVES DeDt~ sniited and clipped curves for.each Pass ~n separate files, 0.5O0O P~SS ~U~BER: DEPTH INCREMENT FILE SU~RY PBU TOOL CODE HLDT GRC~ $ START DEPT}{ STOP DEPTH ~ .0 7969.0 g700.0 7969.0 g664.0 7969.0 CURVE SHIFT DATA - PASS TO PASS(i~EASURE;D DEPTH) BASELIN~ CURVE FOR SHIFTS PBij C~JRVE CODF: .......... EQUIVALENT u~SHIFTED DEPTH---- --- IS Tame verification ~chlumberger AlasKa Commuting Center 993 07: 25 BASELI~4E DEPTH $ RE~R~S: TNIS FIDE CONTAINS TME FIRST PASS OF THE CNTG/HLDT, NO PASS TO ~ASS DEPTH ADJUSTMENTS WErE APPLIED, LIS FflR~AT DATA PAGE~ DATA FORMAT SPECIFICATION RECORD ** ** SET TYPg - 64EB ** TYPE REPR CODE VALUE 1 66 0 ~ 66 0 3 73 52 4 66 5 66 6 73 7 65 9 65 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 DEPT FT 469782 00 000 00 0 1 I ! 4 68 NPHI CNTG PU-S 469782 00 000 00 0 1 1 1 4 68 NRAT CNTG 469782 O0 000 O0 0 I I 1 4 68 CRAT CNTG 469782 O0 000 00 0 1 1 1 4 68 NCNT CNTG CPS 469782 00 000 O0 0 1 1 1 4 68 FCNT CNTG CPS 469782 O0 000 00 0 1 1 1 4 68 CNTC CNTG CPS 469782 00 000 00 0 1 1 1 4 68 CFTC CNTG CPS 46978~ 00 000 O0 0 I 1 ! 4 68 GRCH CNTG GAPI 469782 00 000 00 0 1 1 I 4 68 TENS CNTG LB 469782 O0 000 O0 0 1. 1 I 4 68 PEF HLDT BN/E 469782 00 000 00 0 I 1 1 4 68 RHOB HLDT G/C3 469782 00 000 00 O 1 1 1 4 68 DRHO HLDT G/C3 469782 O0 000 00 0 1 1 ~ 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS Tape verification Listing ,chlumberger AlasKa Co.~putinq CeNter 8-0CT-1993 07:25 PAGE= mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~ DEPT. 8700.o00 NPHI.C~TG -999.250 NRAT.CNTG -999,250 NCNT,CNTG -999.250 FCNT,CNTG -99g.250 CNTC,C?~TG -999,250 G~CH.CNTG -999.25u TEN$,CNTG -999.~50 PEF.i.tLDT 40,000 DRHO,HLDT -0,354 DEPT, 7969,000 NPHI.CNTG ~5.3~1 NRAT,CNTG 5,073 NCMT.CNTG 871.533 FCNT,CNTG 176.36~ CNTC,CNTG 896,396 GRCH,CNTG 52,000 TENS,CNTG i760,000 PEF.HLDT 40,000 DRHO,~LDT -0,780 CRAT.CNTG CFTC.CNTG RHOB.HLDT CRAT.CNTG CFTC.CNTG RHOO.HLDT 999.250 :999.250 2.429 85 2.281 ** E~D OF DATA **** FILE TRAII,ER **** FILE HAME : EDIT .00! SERVICE : FLIC VERS£ON ~ O01A07 DATE : 93/06/14 MAX REC SIZE : !024 FILE TYPE : L~ LAST FILE : **** FILE HEADER **** FILE NAME : EDIT ,002 SERVICE : FLIC VERSION : O0~A07 DATE : 93/06/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CUR~ES Depth shifted a[~d clipped curves for each Pass in separate files, PASS NUMBER: 2 DEPTH INCREMENT 0,5000 FILE SI.J~MARY PBU TOOL CODE START DEPTH CNTG MLDT 8697.0 GRC}~ ~66~,0 STOP DEPTH 796 7969,0 7969,0 ,IS Ta~e verification Listing ichlUm erger AlasKa Co.;putinq Center 993 07: 25 PAGE~ # CURVE SHIFT DATA - PASS TO PASS(MEASURED BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GPCH PASS NUMBER: I RASELI 8679. 8648, 8638. 8637 8614 8603 8585 8582 857! 8567 8550 8519 8509 8479 8465 8464 8449 8409 8374 8368 8366 833,6 8334 8332 833~ 83~6, 8311. 8293 8247 8231 8189 8189 8171 8165 8154 8150 83.31 8119 8116 8114, 8087, 8087. .......... EQUIVALENT UMSNIFTED NE DEPTH C~TG HLDT GNCH 0 88888,5 88889.0 88888.0 0 8679,0 5 8649,5 5 8639,0 8639,0 0 8637.5 5 8615.5 5 8604,5 0 8585.5 0 8583,0 0 8572,0 5 ~568.0 0 8551,0 5 8520.0 5 6510,0 5 ~480.0 0 8466,0 0 8465,0 5 ~450,0 8450.5 0 8410.0 5 8374,5 0 8368,5 0 8367.0 ~366.5 0 8337.0 0 8334.5 0 8333.0 5 8332.5 0 8316 5 5 ' 8312.0 0 8294.0 5 8255,0 5 8248,0 0 8232,0 5 ~231.5 5 8190.0 0 8190,0 0 83.71,5 5 8166,5 0 8155.0 0 8151,0 0 8132.0 5 ~t20,0 5 8~.17.5 0 8115.0 5 8088,5 0 8087.5 DEPTH .... ------ ,IS Tape Verification ;chlumv-erger AlasKa ComputJ. ng Center 8-0CT-1993 07:25 8086.5 8097.0 8070,0 8070,5 8069 0 8070.0 8070.0 8031:0 8032,0 @03O 5 8031.5 7977i0 7977 5 7976 0 7977.0 ' 79'/7,o 79bl,5 7962,5 7958.5 7959.0 7956,0 7957.0 7948,5 7949.5 100.0 101.0 101.0 101.0 REMARK$~ THE DEPTH ADdUSTHENTS S~OWN ABOVE REFLECT PASS 2 GRCH TO PASS ! GRCH, PASS 2 NPHI TO PASS ! NPHI PASS 2 RHOB TO PASS ~, RHOB, ALL OTHER CURVES WERE CARRIED WITH THE SNiF.FS APPLIED TO THEIR RESPECTIVE TOOL, S # LIS FORMAT DATA PAGE: FORgAT SPECIFICATION RECO D ** SET T TYPE - 64EB ** REPR CODE YALUE 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 I5 66 16 66 0 66 0,5 FT 19 0 FT 68 ,IS Tape verification ListlnQ ,chlumber.erq Alaska ComputinQ Center 8-OCT-1993 07:25 PAGE: ** SET TYPE - CH~,{ ** V VI A I API APl AP1 FILE NUMB NOMB S Z EPR OC 88 ID ORDER ~ 50G TYPE CLASS ~OD NUMB SAMP E[_,EM CODE (HEX) DEPT FT 469782 O0 000 O0 0 2 ! I 4 68 NPHI CbiTG PU-S 4697R2 O0 GO0 O0 0 2 1 1 4 68 NRAT C,~TG 469782 O0 ~00 O0 0 2 ! ~ 4 68 CRAT CNTG 469782 O0 0o0 O0 0 2 ! 1 4 68 NCNT CNTG CPS 469782 O0 000 O0 0 2 1 I 4 68 FC~T CNTG CPS 469782 O0 O00 O0 0 2 1 ! 4 68 CNTC CNTG CPS 469782 O0 000 O0 0 2 ! 1 4 68 CFTC CNTG CPS 469782 O0 000 O0 0 2 1 I 4 68 GRC~ CNTG GAPI 469782 O0 000 O0 0 2 1 I 4 68 TENS C~TG LB 469782 O0 000 O0 0 2 1 ! 4 68 PEF HbDT 469782 O0 000 00 0 2 ! I 4 68 RHOB HLDT G/C3 469782 O0 000 O0 0 2 ! 1 4 68 DRHO HLDT G/C3 4697~2 O0 o00 O0 0 2 ~ 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmmmmmmmmmmm-mmmmmmmmmmmmmmmmmmmmm~mmm#m-mmmmmmmmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmmmm DATA ** DEPT ~.697 000 NPHI C~TG -99~ ~50 NCNT:CMTG 999:250 FCNT:CNTG -99{): 50 GRCH.C~,TG -999.250 TENS.C{~,iTG -999.250 DRHO.HLDT -0.396 ** END OF DATA NRAT.CNTG CNTC.CNTG PEF,HLDT -999 250 CRAT.CNTG -999i~50 CFTC'CNTG 40 000 RHOB.HbDT '999,290 '999,250 **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC YERSI~N : 00lA07 DATE : 93/06/14 ~AX REC SIZE : 1,024 FILE TYPE : LO LAST FILE : **** FIL~ MEADER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSIO~I : 0OIA07 DATE : 93/06/1.4 ~AX REC SIZE : 1024 FILF TYPE : LO LAST FILE : ,IS Tape Verification Llstlnq ~chlumberger AlasKa Computing Center 8-OCT-1993 07:25 PAGE: FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted and PASS NUMBERS DEPTH I~CREMEN~r FIL~ SUmmARY PBU TOOL CODE CNTG HLDT G~CH $ CURVE SHIFT DAT~ RASELINE CURVE FOR PBU CURVE CODE: PASS HUMBER: ASELINE DEPTH 8637,5 8637,0 8591.0 8582.0 8573,5 ~567.5 855t 0 8548 5 8531 0 ~25 5 8520 0 8509.0 8480.0 8435 0 ~419,5 8409.0 8400,5 8386.5 8366,0 8349.5 8342.0 834~.5 8315.5 8296.5 8231'5 8231.0 8230.0 8190.0 clipped 0.5OOO Curves START DEPTH ~67~ 8697~ $663.0 - PASS TO PASS(MEASURED SHIFTS GRCH ! for eac~ pass ~n separate STOP DEPTH 96 .0 796g.0 7969.0 DEPTH) .... -- .... EOUIVALENT UNSHIFTED CNTG MLDT GRCH 88889.0 88889 0 8889. 8649i5 8639 0 8638.5 8638.0 8583.0 8568.0 8526.0 8591.5 8526,0 8520.O 8480.5 8423.0 8410.0 83~2.0 8230.5 8420,5 8387,0 8350.5 8342,5 ~]297.0 8231,5 8574.5 8532,5 8509.5 8435,5 8401.5 8366,5 8316.0 8190.0 files. DEPTH---------- ,IS Tape Verification Listing ;chlumberger AlasKa Computing Center 8-0CT-1993 07:25 ~183.5 8183.5 8152.0 8120 5 8119:5 ~t20.O 8114.5 8070.5 8069.5 8041.5 8042.0 8030.5 8004,0 7976,5 7976,0 7977.0 7962.0 7959.0 7959.0 7956,0 7956,5 100,0 100.5 $ REMARKS: ~152.5 ~121.0 ~115.0 8071,0 8070,0 8031.0 8004.5 7977,0 7963,0 100,5 1[~1.0 THK .DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS 3 GRCH TO PASS 1GRCH, PASS 3 NPH! TO PAS~ 1 NPHI, PASS ] RHOB TO PASS I RHOB ALL OTHER CURVES~WERE CARRIED WITH THE SHIFTS APPLIED TO THEIR RESPECTIVE'TOOL, LIS FORMAT DATA PAGEJ DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ....-...........-..---.-..,,,. TYPE REPR CODE VA 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 7~ 7 65 8 68 0,5 9 65 FT !1 66 19 {2 68 1,3 66 0 14 65 FT 15 66 68 16 66 ,IS Tape Verification listing ;chlumberger Alaska Co~,puting Center 8-[:CT-~993 07:25 PAGEI 10 ** SET TYPE NAME o.RV~E uNIT SEI{¥ICEAPIAAPi PIAPIIF bE NUMB NUMB SIZE REPR PROCESS ID ORPER # LOG TYPE CLASS MUD NUMB SAMP gLEN CODE (HEX) '~''PT ............... FT 469782' ............ O0 ~00'''~; ....... 0 ';''''~'''''''''''''''''''''''''''''''''''1 4 68 0000000000 NPHI CNTG PU-S 469782 O0 000 O0 NRAT CNIG 499782 O0 000 O0 CRAT CNTG 469782 00 f~00 00 NCNT CNTG CPS 469782 00 000 00 FCNT CNTG CPS 469782 O0 000 00 C~TC CNTG CPS 469792 O0 000 O0 CFTC CNTG CPS 469782 00 0o0 00 GRCH CMTG GAPI 469782 00 000 00 TENS CNTG b~ 469782 O0 000 O0 PEF ~bDT 469782 O0 000 O0 RHOB HbDT G/C3 4697~2 O0 000 O0 DRHO HLDT G/C3 469782 O0 000 O0 0 3 1 I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 I I 4 68 0000000000 0 3 1 1 4 68 0000000000 0 3 I 1 4 68 0000000000 0 3 I 1 4 68 0000000000 0 3 i I 4 68 0000000000 mmmmmmmmmmmmmmmmm-mm-mmmmmmmmmmmmmm~mmmmmmmmm-mmmmm-#-m~-mmmmmmmmmmmmm#mmmmmmm#mmmmmm~m ** DATA ** OMPT MCNT:CNTG GRC~.CMTG DRHO.~LDT 8697 000 NPHI CNTG 999 250 NRAT C'4TG -999 250 -999.250 FCNT.C~TG -999.250 CNTC.CMTG -999:250 -999.25(i) TENS.CMTG -999.250 PEF.HLDT 40,000 -0.408 ** END OF DATA CRAT.CNTG CFTC.CNTG RHOB.HLDT -999,250 -999,250 2.340 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01A07 DATE : 93/06/I4 ~AX AEC SIZE : 1.024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAag : EDIT .004 SERVICE ~ rlL!C VERSION : OOlA07 DATE : 93/06/14 ~AX AEC SIZE ~ 1024 FILE TYPE : LO LAST ~ILg : ,IS Tape Verification [,isting ;chlumberger 41as~a Co~:puting Center ~-0CT-1993 ")7:25 PAGE: 11 FILE MEADFR FILE NUMBER: 4 AVERAGED CURVFS CompeNsated Neutron: Arithmetic average ot edited passes for all curves. Pulsed Neutron: bnaveraged edited Pass ~ ~amma ray and bac~round counts; arithmetic average of edited static oaselln~ passes for all other curves. D~PTH I~CRE~ENT 0.5000 P~SSES INCLUDED Ihi A~ERAGE PBU TOOL CODE PASS NUMBERS CNTG 12'3, , ~LDT 1, 2, ~, $ ~RKS: THIS FIbE CONTAINS THE ARITHMETIC AVERAGE OF T~E CNTG AND !{LDT DATA. $ LIS FORMAT ~TA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** E REPR CODE VAbUE I 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 9 65 11 66 19 12 68 13 66 0 ~,4 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** '';'~'':X ''',,,,',,,,,,,'',,,'',,,'',,''',',','''''''' ..... ''''~i~''''~ .... ID ORDER ~ bOG TYPE CLASS MO[) NiJ~B SANP ELEM CODE (HEX) DEPT FT 4~9782 O0 000 O0 0 ~ 1 I 4 68 0000000000 NPHI CNAV PU-S 469782 O0 000 O0 0 4 ! I 4 58 00000.00000 ,IS Tape Verification Listing ;chlumbetger AlasKa Co~putlng Center 8-OCT-I 993 07:25 PAGE: NAME V U. ER ICE API APl APl API FILE NU.,.B B $IZ E R PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SA~P gbE~ CODE (HEX) NRAT CNAV 469782 O0 000 O0 0 4 I 1 4 58 CRAT CNAV 469782 O0 000 O0 0 4 1 I 4 68 NCNT CNAV CPS 40978~ O0 000 O0 0 4 1 X 4 68 FCNT CNAV CPS 4697~2 O0 OOO O0 0 4 1 1 4 68 CNTC CNAV CPS 469782 O0 000 O0 0 4 I 1 4 68 CFTC CNAV CPS 46g782 O0 o00 O0 0 4 1 1 4 68 GRCH CNA¥ GAPI 469782 O0 000 O0 0 4 1 1 4 68 TENS CNAV bB 469782 O0 000 O0 0 4 ~ 1 4 68 PEF HLAV 469782 O0 000 O0 0 4 ! 1 4 08 RHO~ HLAV G/C3 469782 O0 00o O0 0 4 1 1 4 68 DRHO HLAV G/C3 469782 O0 000 O0 0 4 I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmmmmmmmmmmmmm~-mmmmmm#mmm~mmmmmm#mmmmm~mmmmmmmmmmmmmm~mmmmmmmmm~mmmmmmmmm~mmmmm DATA DEPT. 8697.000 CNAV -999.2~0 NRAT.CNAV -999,250 NPHI'cNAV 999.250 CNTC,CNAV -999,250 NCNT.CNAV -999°250 FCNT. GRCH.CNAV -999.250 TEM$.CNAV -999,250 PEF,HLAV -999,250 DRHO.HLAV -999,250 END OF DATA CRAT.CNAV CFTC.CNAV RMOB,HLAV '999,250 '999,250 '999,250 **** FILE TRAILER **** FILE NAME : EDIT ,004 SERVICE : FLIC VERSION ~ O0~a07 DATE ! 93106/14 ~AX REC SIZE ~ 1024 FILE TYPE : bO LAST FILE : **** FILE HEADEA **** FILE NAME : Bi}IT ,005 SERVICE : FLIC VERSION : O01A07 DATE : 93106/!4 MAX REC SIZE : !024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES ,IS Taoe Verification LlstlnO ;chlumberger AlasKa Comoutin~ Center g-OCT-~993 PAGE: 13 PASS NUMBER: 1 DEPTH INCREMENT: -.5000 # FILE SUmmARY VENDOR TOOL C(]DE S<¥ART DEPTH ¢ MLDT 8704,0 $ LOG HEADER DATA Curves and log header data for each pass in separate files; raw background pass in last file STOP [>EPTH 7936.0 DATE hOGGED: SOFTWARE VERSIO;~: TIME LOGGER ON 5OTTO,: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL BOTTO~ LOG I~TERVA~ (FT): LOGGING SPEED (FPHR): DEPTH CONTROL {!SED (YES/NO): TOUI~ STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ['''''''Nr~' ~ ....... ' ~~'' CNTG TELEgETRY CARTRIDGE CNTG GA~A RAY CNTG COMPENSATED NEUTRON CNTG HLDT C~TG TELEMETRY ~ODULE BORENOLE AND CASI[~G DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH LOGGERS CASING DEPT~ (FT): 80RENOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOL~ TE!~PERATURE (DEGF): FLUID SALINITY FLUID LEVEL ~FT) FLUID RATE A~" WELLHEAD WATER CUTS (PCT): GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EFI'C~ER~AD OR T~tER~AL): ~ATRIX: MATRIX DENSITY: }{OLE CORRECTiOi~ (IN): 18-~AY-93 CP 32.6 400 18-~AY-93 8682.0 8684.0 7950.0 90o 0 NO TOOL NUMBER CAL YA 28' TCC B 420 SGC SA 40 CNC G 65 HLDT 20 TC~ 19 12.250 5081.0 BRINE 12,50 172.0 EPITHERMAD SANDSTONE 2.65 ,IS Taoe Verificat],on f, iStin~ ,chlumberger Alaska Computin~ Center 8-UCT-1993 07:25 PAGE: X4 BLUELINE CO[~[,IT RATE NOR~AL!ZATION IN Olb ZONE TOP NORmALIZInG ~INDO~ (FT): BASE ~ORMALIZING WINDOW (FT): B[jUELINE COUNT P, AT~2 SCALES SET BY FIELD E~GINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RA'rE HIGH SCAb~ (CPS): 5500 ~ COU~T ~T~: ~OW SC~ (CPS): 0 NEAR COUNT R.~TE HIGH SCALE (CP)$: 25000 TOOL STANDOFF (IN); REMARKS: TIED INTO SWS CET DATED 5-17-93. HLDT/CNTG IS RAW DAT~ PRODUCT PERFO~i~ED BY SWS COMPUTING CENTER, ~o~$ ~u~ aT 9O0 F~'~. $ LIS FORMAT DATA COMPUTATIONS TO BE DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 168 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I TaPe veriflcat]on Listing ichlumberger AlasKa Computlnq Center 8-0CT-1993 07:25 PAGE: 15 *~ SET TYPE - CHAN *~ '~,''~''~''~¢~'~'~''XT V C ...... PI AP ~ ........ API A ;~'~''''Ib~ .......... Nt,~8 NU~ ''''''''''''''''''''''''''ZE REPR P SS ID ORDER ~ bOG ']:YPK CLASS ~[~D NUmB SA~P E[,E~ CODE (HEX) DEPT FT 4~9782 O0 000 O0 0 5 ! 1 4 68 ENpH CN1 PU 469782 O0 OOC O0 0 5 ! 1 4 68 ENRA CN1 469782 O0 {tOO O0 0 5 1 1 4 68 CFEC Cai CPS 469782 O0 000 O0 0 5 1 1 4 68 CNEC CN1 CPS 469782 O0 000 O0 0 5 1 ! 4 68 RCEF CN1 CPS 469782 O0 000 O0 0 5 1 ! 4 68 RCEN C~1 CPS 469782 O0 o00 O0 0 5 1 I 4 68 NPH! CN! PU 469782 O0 000 O0 0 5 1 i 4 68 TNpH CN! PU 4697~2 O0 000 O0 0 5 I ~ 4 68 TNRA C~I 469782 O0 000 O0 0 5 1 i 4 68 RTNR CN1 469782 O0 o00 O0 0 5 1 1 4 68 NPOR CN! PU 469782 O0 000 O0 0 5 1 ~ 4 68 RCNT CN] CPS 469782 O0 000 O0 0 5 1 ! 4 68 RCFT C~ CPS 469782 O0 000 O0 0 5 1 1 4 68 CNTC CN! CPS 469782 O0 000 O0 0 5 i i 4 68 CFTC CN! CPS 469782 O0 o00 O0 0 5 1 1 4 68 GR CHI GAPI 469782 O0 GO0 O0 0 5 1 1 4 68 CAL! CNi IN 469782 O0 000 O0 0 5 ! 1 4 68 TENS CN1 LB 469782 O0 000 O0 0 5 I i 4 68 CCL CN1 V 469782 O0 000 O0 0 5 1 I 4 68 LSRH HL! G/C3 469'782 O0 000 O0 0 5 I I 4 68 SSRH HL! G/C3 469782 O0 000 O0 0 5 X I 4 68 PEFL HS1 469782 O0 000 O0 0 5 i 1 4 68 PEFS HL1 469782 O0 000 O0 0 5 ~ 1 4 68 PEF ~L! 469782 O0 000 O0 0 5 ! i 4 68 LSWl ~L1 CPS 469782 O0 000 O0 0 5 ~ ! 4 68 LSW2 HL! CPS 469782 O0 000 O0 0 5 1 i 4 68 LSW3 HL1 CPS 469782 O0 000 O0 0 5 ! i 4 68 5SW4 HL1 CPS 469782 O0 000 O0 0 5 t ! 4 68 LSW5 HL~ CPS 469782 O0 000 O0 0 5 ! ! 4 68 SSW! HL1 CPS 469782 O0 000 O0 0 5 ! 1 4 68 SSW2 HL1 CPS 469782 O0 000 O0 0 5 1 i 4 68 SSW3 HL1 CPS 4697~2 O0 000 O0 0 5 ! ! 4 68 SSW4 HL~ CPS 469782 O0 000 O0 0 5 1 i 4 68 SSW5 Mb! CPS 469782 O0 000 O0 0 5 i I 4 68 RHOB ~L] G/C3 4697~2 O0 000 O0 0 5 ! i 4 68 DRHO HLI G/C3 469782 O0 OOO O0 0 5 I t 4 68 CS ML! F/HR 469'?~2 O0 000 O0 0 5 I I 4 68 TENS HE1 LB 469782 O0 000 O0 0 5 I I 4 68 CALI HL! IN 469782 O0 000 O0 0 5 1 'I 4 68 GR HL! GAPI 469'!82 O0 000 O0 0 5 1 ! 4 68 CCL ~LI ¥ 469782 O0 000 O0 0 5 ! ! 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA ,IS Tape Verification I, istino ichlumberger AlasKa Computing Center DEPT. 8704,{~oo ENPH.CN1 CNEC.CN{ 3308.720 RCEF.CN1 TNPH,CNI 3b.461 TNRA,C~!I RCNT.CN1 1440.751 RCFT.CN1 GR.CN1 95,000 CALl.CMl LSR..HLI 2,766 SSRH,BLi PEF.HL! 40.000 LSW1.HL1 LSW4,Hb] 379.750 LSW5,HL1 SSW3,HLi 5012.000 SSW4,HL! DRHO,HL1 -0.371 CS.HLI GR.HL1 95,000 CCL.HL! DEPT, 7936.00u ENPH.CNI o9o RCNT,CN1 10001978 RCFT.CN1 LS, gbl 204.025 LSWS.HL! DRHO~HL! -0,734 CS.~LI GR,HL1 59,906 CCL.HL1 ** END OF DATA ** 8-0CT-1993 07:25 41.875 ENRA.CNI 5,783 559,535 RCEN.CN1 3070.310 3.346 RTNR,CN1 3.477 409,543 CNTC,CNI 1421.77i 3,090 TENS,CN1 915.000 3,297 PEFL,HLI 40,000 103,688 DSW2,HL1 197.125 372.750 SSWi.ML1 641.500 2592.000 SS~5.HL1 489,250 312.000 TENS.HL1 915.000 -0,004 48,808 ENRA.C~I 6,355 488,008 RCEN.CN1 2809.647 4,683 RTNR,CN1 4,796 205.439 CNTC,CNI 986,615 4.02? TENS,CN1 1750,000 4.096 PEFb,HL! 39.813 55.750 LSW2.~L1 100.125 105.125 SSW1.HLi 322.000 1386.000 SSW5,HL1 244.500 957,500 TENS.HL1 1750.000 -0,088 CFEC.CN1 NPHI.CN1 NPOR.CN1 CFTC.CNI CCL.CN1 PEFS,HL! LSW3,HL1 SSW2.HD1 RHOB.Hbl CALI,HL! 572178 35425 36461 435599 -0 O04 40000 504,750 1802.000 2.395 3,090 CFEC,CN1 486.536 NPHI.CN1 59,801 NPOR.CN1 65,011 CFTC.CNI 213.482 CC~,CNI ;0,088 PEFS.Hbl 0,000 o :ooo RHOB.HLI 2 CALI,HL1 4:~97 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01A07 DATE : 93/06/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FIL~ NAME : EDIT ,006 SERVICE : F&IC VERSION : O0!A07 DATE : 931o6/14 MAX REC SIZE : 1024 FILE TYPE : LAST FILE FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file ~IS Tape Verification Listinq ,chlumberqer AlasKa Computln~ Center Q-OCT-19g3 07:25 PAGEI 17 PASS NtJ~BEP: 2 DEPTH INCRLMENT: -.5000 # FILE SUMMARY VEMDOR TOOL CODE START DEPTH CNTG 8702 .0 HbDT 8702.0 $ LOG HEADER DATA STOW DMPTH 7935.0 7935.0 DATE LOGGED: SOFTWARE VERSION) TIME LOGGER ON BOTTU~: TD DRILLER TD LOGGER(FT): TOP bO~ INTERVAL (FT) BOTTOM bOG INTERVAL LOGGIN~ SPEED (FPHR): DEPTH COMTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE CNT CALIPER CNTG TELEMETRY CARTRIDGE CNTG GAMMA RAY CNTG COMPENSATED NEUTRON C~TG HLDT CNTG TELEMETRY ~ODULE ~OREHOLE ~!D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (ET): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIOn, S FLUID TYPE~ FLOIO DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TENPERATURE (DEGF): FLUID SAblN!TY (PPg): FLUID LEVEL FLUID RATE AT ~ELLHEAD WATER CUTS (PCT): G~S/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITH~RMAL UR MATRIX: ~ATRIX DENSITY: HOLE CORRECTION (IN): 18-MAY-9] CP ]2,6 400 18-MAY-93 8682.0 8684.0 795~.0 868 ,0 900.0 NO TOOL NUMBER TCC ~ 420 SGC S~ 40 CNC G 65 HLDT 20 TC~ 19 12 25 BRINE 12,50 172.0 EPITHER~Ab SANDSTO~!E 2.65 ~I$ Ta~e verification Listing ~chlumberqer Alaska Com[~utln~ Center 8-0CT-1993 07:25 BLUELINE COULT RATE NORMALIZATION IM 016 ZONE TOP NORMALIZ[~G WINDO~ BASE NOR~ALI~ZING ~;INf30~ (FT): TOOL STANDOFF RE~ARKS: TIED INTO $W$ CET DATED 5=17=93, HLDT/CNTG IS RA~ DATA PRODUCT PERFORMED BY SWS COMPUTING CENTE~. 50GS 90o $ LIS FORMAT DATA COMPUTATIONS TO BE PAGE{ 18 ** DATA FORh~AT SP.CIFICATION RECORD ** ** SET TYPE.] - 64EB ** TY E REPR C{)DE VALUE ~ 66 0 2 66 0 3 73 168 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 1! 66 6 i~ 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** DEPT FT 469782 O0 000 O0 0 6 1 1 4 68 0000000000 ENP~ CN2 PU ~69782 O0 (}00 O0 0 6 i 1 4 68 0000000000 ,IS %a~e Verification L, istlng ;chlumberger AlasKa Computlnq Center 8-0CT-1993 97:25 PAGE: 19 SERVICEAA.AP1API~ ; M NAME SERV UNIT PI PI FILE NUmB ~U B SiZE REPR PROCE$ ID ORDER # I~OG TYPE CLASS MOD NUmB SA~P EbEM CODE (HEX) ~ mm~m~ m m~ ~mm~m~m ~ ~m~m~ m~m~~ ~m~mm~m~mm~mm~mm~~mmm~~m~m~m EMR~ CN2 469782 O0 o00 O0 0 6 ! 1 4 68 CFEC CN2 CPS 469782 O0 00o O0 0 6 1 1 4 68 CNEC C~2 CPS 469782~ O0 o00 O0 0 6 1 I 4 6~ RCEF C~2 CPS 469782 O0 000 O0 0 6 1 1 4 68 RCEN C~2 CPS 469782 O0 000 O0 0 6 1 ! 4 68 NPH! CS2 PU 469782 O0 000 O0 0 6 ~ i 4 68 TNpH CN2 PU 469782 O0 000 O0 0 6 ! I 4 68 TNRA C~2 469782 O0 000 00 0 6 ! ~ 4 68 RTNR CN2 469782 O0 000 O0 0 6 ! I 4 68 NPOR C~2 PU 469782 O0 uO0 O0 0 6 I i 4 6~ RCNT CN2 CPS 469782 O0 000 O0 0 6 1 1 4 68 RCFT CN2 CPS 469782 O0 000 O0 0 6 ! 1 4 68 CNTC CN2 CPS 469782 O0 o00 O0 0 6 1 1 4 68 CFTC CN2 CPS 469782 O0 o00 O0 0 6 1 % 4 68 GE CN2 GAP! 469782 O0 000 O0 0 6 1 I 4 68 CALI CN2 TN 469782 O0 000 O0 0 6 ! I 4 68 TENS CN2 LB 469782 O0 000 O0 0 6 ~ 1 4 68 CCh CN2 V 469782 O0 o00 O0 0 6 ! 1 4 68 LSRM Hb2 G/C3 46978~ O0 000 O0 0 6 1 ! 4 68 SSRH NL2 G/C3 469782 O0 000 O0 0 6 ! I 4 68 PEFL ML2 469782 O0 000 O0 0 6 ! 1 4 68 PEFS HL2 469782 O0 006 O0 0 6 ! i 4 68 PEF Mb2 469782 O0 000 O0 0 6 1 1 4 68 LSW1HL2 CPS 469782 O0 000 O0 0 6 1 1 4 68 LSW~ Hb2 CPS 469782 O0 000 O0 0 6 1 ~ 4 68 LSW~ HL2 CPS 469782 O0 000 O0 0 6 1 i 4 68 LSW4 HL2 CPS 469782 O0 000 O0 0 6 1 1 4 68 LSW5 HL2 CPS 469782 O0 000 O0 0 6 1 1 4 68 SSW1HL2 CPS 469782 O0 ()00 O0 0 6 1 1 4 68 SSW2 Nh2 CPS 469782 O0 00o O0 0 6 ! 1 4 68 SSW3 HL2 CPS 469782 O0 OOO O0 0 6 i I 4 68 SSW4 HL2 CPS 469782 O0 000 O0 0 6 ! 1 4 68 SSW5 HL2 CPS 469782 O0 000 O0 0 6 1 1 4 68 RHOB NL2 G/C3 469782 O0 000 O0 0 6 1 1 4 68 DRHO HL2 G/C3 469782 O0 000 O0 0 6 ! i 4 68 CS Hb2 F/HR 469782 O0 OOO O0 0 6 1 I 4 68 TENS Hb2 58 469782 O0 000 O0 0 6 ! I 4 68 CAbI Hb2 IN 469782 O0 000 O0 0 6 I. 1 4 68 GR HL2 GAPI 469782 O0 000 O0 0 6 ! 1 4 68 CCL Hb2 V 469782 O0 OOO O0 0 6 ~ I 4 68 0000000000 0000000000 O000uO0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA ** DEPT, 8702,000 ENPH,CN2 40,530 ENRA,CN2 CNEC,CN2 ]388,973 RCEF,CN2 584.993 RCEN'CN2 TNPH,CN2 35,846 TNR~,CN2 3,305 RTNR,CN~ RCNT,CN2 1481,68t RCFT.CN2 426.276 CNTC,CN2 GR,CN2 80,4~ CAbI.CN2 3,~52 TENS,CS2 bSRH.HL2 2.803 SSRH.Hb2 3.354 PEFL.HL2 3144:780 NPHI N2 435 NPOR,CN2 146 [16~ CFTC,CN2 ooo 598,212 34,680 35,846 453,397 g:ooo 000 ,IS Ta~e Verification T,Jstinq ;chlumberger Alaska Computin_6 Center PEF HL2 37.563 LSWl.HL2 LSW4iHL2 364.000 LSWL.HL2 $SW3 HL2 491~o000 SSW4.HL2 DRHO.HL2 -0.384 C$.HL2 GR.HL2 80°438 CCL.HL2 DEPT 7935,000 ENPH.CN2 CNEC:CN2 3073.611 RCEF.CN2 TNPH.CN2 58.536 TNRA.CN2 RCNT,CN2 96~..907 RCFT.CN2 G~.CN~ 6~.375 CALI.CN2 LSRH.HL2 3.055 SSRH.HL2 PEF.HL2 40.O00 LSWi.HL2 LSW4.HL2 195.875 LSWL.H52 SSW3.~L2 2550.000 SSW4.HL2 DRHO.HL2 -0.761 C$.HL2 GR.HL2 63.375 CCL.HL2 E~D OF DATA 8-OCT-1993 07:25 8~.81] LSW2.HL2 162.625 32 .250 SSWI.HL2 561.000 2406.0~0 SSW5.HL2 408.750 309'500 TEN$.HL2 830.000 O.OU0 4.8.506 ENRA.CN2 6.3]1 474.919 RCEN.CN2 2838.792 4.782 RTNR.CN2 4.937 210.868 CNTC.CN2 ~001.795 4.020 TENS,CH2 1885.O00 4.~29 PEFb. HL2 40.000 55.031 LSW2.HL2 100 188 17~.875 SSWi.HL2 327~250 1296,000 SSW$.HL2 249.375 97~.500 TENS.HL2 1885.000 -0.023 LSW~.HL2 SSW .HL2 RHOB.HL2 CALI.HL2 CFEC.CN2 NPHI.CN2 NPOR.CN2 CFTC.CN2 CCL.CN2 PEFS.HL2 LSW].HL2 SSW2.HL2 RHOB.HL2 CALI.H~2 PAGE: 20 440.750 1558,000 2,420 3.352 485.490 61.615 61,908 225,446 -0,023 40.000 000 !iooo O2O **** FILE TRAILER FILE NAME : EDIT .006 SERVICE : FLIC VERSION : DATE : 93/06/14 MAX AEC SIZE : 1024 FIL~ TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT ,007 SERVICE : FLIC VERSION : 00~A07 DATE : 93/06/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMOER 7 RAW CURVES Curves and log header data for PASS NUMBER: 3 DEPTH INCREMENT: -.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH each pass in separate files; raw STOP DEPTH background pass in last ,I$ Taoe Verification Listing icblumberger AlasKa Computing Center 07:25 PAGE: 21 CNTG 8701.5 7944.5 HbDT 9701.5 7944.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGCER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL BOTTOM LOG INTERVAL LOGGING SPEED DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTG CALIPER CNTG TELEMETRY CARTRIDGE CNTG GAM~A RAY' CNTG COMPENSATED NEUTRON CNTG M~DT CNTG TELE~T~Y MODULE $ BOREHOLE AND CASING DATA OPEN ~OLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT)~ BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TE~PERAT[iRE (DEGF)~ BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT ~LLHEAD WATER CUTS (PET): GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMA~ OR THERMAL): ~ATRIX: ~ATRIX DENSITY: HOLE CORRMCTION (IN): BLUEbINE COUNT RATE NORMALIZATION IN OIL zONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE bOW SCALE (CPS): 18-MAY-g3 CP 32,6 4O0 8682.0 8684.0 7950.0 8681.0 900.(t 18-~AY-93 TOOL NUMBER CA A TCC S 420 SGC SA 40 CNC G 65 HLDT 20 TC~ i9 BRINE 12,50 t72,0 EPITHERMAL SANDSTONE 2,65 ~IS Tame verification [~istlng ,chlumberger AlasKa Computing Center 8-0CT-1993 07:25 NEAR COUNT RATE LOW SCALE (CPS)~ 0 NEAR COUNT RATE HIGH SCALE (CPS : 25000 TOOL STANDOFF (IN): REMARKS: TIED IDiTO SWS CET DATE[) 5-17-93. HLDT/C]TG IS RAW DATA PRODUCT,z,. COMPUTATIONS TO BE PERFOR~iED BY SWS COMPUTING CENTER. LOGS RDN AT 900 FPH, $ LIS FORMAT DATA PAGE: 22 ** DATA FORNAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 4 66 5 66 6 73 7 65 9' 65 I1 66 6 1~ 68 1] 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** N M S N SERVICE API API P I E NUMB NUmB SIZE REPR PR E ID ORDER ~ LOG TYP~ CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 469782 O0 000 O0 0 7 i ! 4 68 ENPH CH3 PU 469782 O0 000 O0 0 7 1 ~ 4 68 ENR~ CH3 46q782 O0 OOt) O0 0 7 1 1 4 68 CFEC Ci~3 CPS 469782 O0 OOO O0 0 7 1 1 4 b8 CNEC Ca3 CPS 469782 O0 000 O0 0 7 I I 4 68 RCEF ca3 CPS 469782 O0 000 O0 0 7 I I 4 68 RCEN CH3 CPS 469782 O0 00() O0 0 7 1 1 4 68 NPHI CH3 PU 469782 O0 0()0 O0 0 7 1 i 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Tape verification l,isting ~chlumberger Alaska ComputiDg Center 07:25 PAGEs 23 ID TNPH CM3 PU TNRA CN3 RTNR CN3 NPOg <N3 PU RCNT CN3 CPS RCFT C~3 CPS CNTC C~3 CPS CFTC CN3 CPS GR CN3 GAPI CAbI CN3 IN TENS CN3 CCL CN3 LSRH gL3 G/C] SSRH HL3 G/C3 PEFL HL3 PEFS HL3 PEF HL3 LSW1 HL3 CPS LSW2 HL3 CPS LSW3 ilL3 CPS LSW4 HL3 CPS LSW5 HL3 CPS $8W1HL3 CPS SSW2 HL) CPS SSW3 HL3 ~PS SSW5 HL3 CPS RHOB HL] G/C3 DRHO HL3 G/C3 C8 Hb3 F/HR TENS Mb3 LB CA5I HL3 IN GR HL3 GAPI CCh HL3 V ** DATA ¸7' DEP. 8701 CNEC]CN3 3512 TNpH,cN3 31 RCNT,CN3 1335 GR.CN3 75 LSRH.HL3 2 PEF,~3 39 LSW4.~L3 357 SSW3.~L3 4744 DRHO,HL3 -0 I E AP][ AP1 AP1 APl FILE NUMB NUMB $ ZE R PROC R # bOG TYPE CLASS MOD NUMB SANP EI, EM CODE (HEX) ORDW 469782 00 000 O0 0 7 1 I 4 68 0000000000 469782 00 000 O0 0 7 I 1 4 68 0000000000 460'782 O0 oO0 O0 0 7 1 I 4 68 0000000000 469782 00 000 O0 0 7 I 1 4 68 0000000000 409782 O0 000 OO 0 7 I 1 4 68 0000000000 469782 O0 O00 00 0 7 1 i 4 68 0000000000 469782 O0 O00 00 0 7 1 1 4 68 0000000000 469782 O0 0(}0 O0 0 7 1 1 4 68 0000000000 46978~ O0 0O0 O0 0 7 1 i 4 68 0000000000 469'182 00 000 O0 0 7 1 1 4 68 0000000000 469782 O0 000 00 0 7 I ! 4 68 0000000000 469782 00 000 O0 0 7 1 1 4 68 0000000000 469782 O0 000 O0 0 7 I 1 4 68 0000000000 469782 00 000 00 0 7 1 1 4 68 0000000000 469782 O0 000 O0 0 7 I 1 4 68 0000OO0000 469782 00 000 00 0 7 I 1 4 68 0000000000 469'782 O0 000 O0 0 7 I i 4 68 0000000000 469782 00 000 O0 0 7 ! I 4 68 0000000000 469782 00 000 00 0 7 1 I 4 68 0000000000 469782 O0 000 00 0 7 1 1 4 68 0000000000 469782 00 000 00 0 7 1 I 4 68 0000000000 469782 00 000 00 0 7 1 1 4 68 0000000000 469782 00 000 O0 0 7 1 I 4 68 0000000000 469782 O0 000 00 0 7 1 1 4 68 0000000000 469782 O0 000 00 0 7 1 1 4 68 0000000000 469782 00 000 O0 O 7 1 1 4 68 0000000000 469782 00 000 00 0 7 1 1 4 68 0000000000 469782 00 000 00 0 7 1 1 4 68 0000000000 469782 O0 000 00 0 7 1 1 4 68 0000000000 469782 00 000 00 0 7 ! 1 4 68 0000000000 469782 00 000 00 0 7 1 i 4 68 0000000000 4697~2 00 000 00 0 7 1 1 4' 68 0000000000 469782 O0 '000 O0 0 7 1 1 4 68 0000000000 469782 00 000 O0 0 7 I 1 4 68 0000000000 mmmmmmmmmmmmmmmmm#mm#{mmm~#~m! .500 ENPH.CN3 36.039 ENRA.CN] 5.256 CFEC.CN3 .731 RCEF.CN3 653 570 RCEN.CN3 3259.622 NPHI.CN3 .696 TNRA,CN3 3~036 RTNR.CN3 3.156 NPOR.CN3 .535 RCFT.CN3 4t8.901 CNTC.CN3 1317.942 CFTC.CN3 .375 CAf, I.CN3 3.1~5 TENS.CN3 930,000 CCL.CN3 .752 SSRH.HL] 3.340 PEFL.HL3 39.031 PEFS,HL3 .03i LSWI.HL3 107.313 LSW2.HL3 193.375 LSW3.HL3 .000 LSW5.ML3 350.500 SSwi.HL3 654.000 $SW2.H53 .o00 SSW4.HL3 2524.000 $$W5.H[.,3 505.750 RHOB.HL3 .4~0 CS. HL3 298.750 TENS.HL3 930.000 CALI.Hb3 .375 CCL.NL~ -0.004 668.3~9 445553 -0 004 34 938 587 500 1494000 3.1,45 IS Tape Yerif]cation Listing chlumberqer AlasKa Computinq Center 8-OCT-1993 07:25 PAGE: 24 DEPT. 7944.50~ ENPH.CN3 CNEC.CN3 3053.688 RCEF.CN3 TNPH.CN] 57.017 TNRA.CN3 RCNT.C,~3 i009.67o RCFT.CN3 GR.CN3 56.344 CALI.CN3 LSRH.HL3 3.06~ SSRH.HL3 PEF.NL3 40.000 LSW1.HL3 LSW4.Hb3 175.175 LSW5.HL3 $SW3.HI.,3 2442.000 SSW4.HL3 DRHO.HL3 -0.778 CS,HL3 GR.HL] 56.34~ CCL.}~L3 46.392 ENRA.C~3 6.162 477.40~ RCEN.CN3 2846.375 4.578 RTNR.CN3 5.043 226.~21 CNTC,CN3 1031.983 4.023 TENS.CN3 1725.000 4.i. 64 PEFL.HL3 40.000 ~3.656 LS~2.HI,3 81.250 174.375 SSWl.Hb3 325.000 ~3~3.000 $SW5.HL3 234.250 987.500 TENS.Hb3 ~725.000 0.039 CFEC.CN3 NPHI.CN3 NPOR.CN3 CFTC.CN3 CCL.CN3 PEFS.HL3 BSW3.Hb3 SSW2.HL3 RHOB.HL3 CALI.HL3 495.606 57,886 59.153 234.789 0,039 40,000 84 000 2.287 4,023 ** END OF DATA ** **** FIL~ TRAILER **** FILE NA~E : EDIT ,007 SERVICE : FLIC VERSIO~ : 00lA07 DAT~ : 93/06/i4 MAX AEC SIZE ~ 102~ FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NA~E : EDIT DATF: : 93/06/14 ORIGIN : FLIC TAPE NAME : 932]9 CONTINUATION # ~ PREVIOUS TAPE COMMENT : ARCO ALASKA I~.IC.,KUPARUK RIVER,IB-12,50-029-22365-O0 **** REEL TRAILER SERVICE NA~4E : EDIT DATE : 93/06/~4 ORIGIN : FLIC REEL NA~E : 93239 CONTINUATION # : PREVIOUS REEL CO~UENT I ARCO ALASKA INC,,KUPARUK RIVER,IB-12,50-029-22365-O0