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Home My WebLink About196-015MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-24 KUPARUK RIV UNIT 3H-24 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-24 50-103-20235-00-00 196-015-0 W SPT 5939 1960150 1500 2180 2180 2180 2180 560 780 780 780 4YRTST P Austin McLeod 6/1/2025 MITIA. 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 3H-24 Inspection Date: Tubing OA Packer Depth 990 2910 2850 2840IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602192220 BBL Pumped:3.5 BBL Returned:3.4 Thursday, July 24, 2025 Page 1 of 1           aM1"411`[1111101 State of Alaska Alaska Oil and Gas Conservation Commission TO. Jim Regg /DATE: Tuesday, June 8, 2021 P.L Supervisor �@6r4 6((1Z,( SUBJECT: Mechanical Integrity Tests / ( Conoc MIIips Alaska, Inc. 3H-24 FROM: Bryan Bixby KUPARUK RIV UNIT 3H-24 Petroleum Inspector Sret Inspector Reviewed By: P.I. Supry jpl�— Comm Well Name KUPARUK RIV UNIT 3H-24 API Well Number 50-103-20235-00-00 Inspector Name: Brian Bixby Permit Number: 196-015-0 Inspection Date: 6/12021 " InSp Num: mitBD6210602041457 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 311-24 'Type Inj W'TVD 5939 Tubing 2815"281=2815' 2814 PTD 1960150 Type Test sPr Test psi 1500 - IA 190 1810 ` 1770 I75s ' BBL Pumped: 123 BBL Returned: 2 OA 485 670 ' 670 " 670 Interval 4YRTST P/F P ' Notes: Tuesday, June 8, 2021 Page I of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Tuesday, October 1, 2019 5:02 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: 3H-24 (PTD 196-015) IA pressure investigation Chris, KRU injector 3H-24 (PTD 196-015) showed an IA pressure increase yesterday from 500 psi to 1000 psi while injecting water. We suspect it was an intentional annulus charge that was accidentally not recorded, and we are investigating. If we find that is the case, then we will update our records and continue to operate the well as a normal injector. If we can't find an explanation, then we will send DHD to investigate and follow-up with you about what they find. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,June 28,2017 P.I.Supervisor 1`e C� X17 /7 SUBJECT: Mechanical Integrity Tests / CONOCOPHILLIPS ALASKA,INC. 3H-24 FROM: Chuck Scheve KUPARUK RIV UNIT 3H-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-24 API Well Number 50-103-20235-00-00 Inspector Name: Chuck Scheve Permit Number: 196-015-0 Inspection Date: 6/24/2017 Insp Num: mitCS170625093743 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-24 "Type Inj vv" TVD 5939 Tubing 2330 2330 - 2330 2330 - PTD 1960150 Type Test SPT Test psi 1500 - IA 940 1710 1670 • 1670 - • BBL Pumped: 11 -IBBL Returned: I SOA 500 560 • 560 560 Interval 4YRTST P/F P ,/ Notes: - C,tt ,2 J�f.9etr 2e�t 7 SCANNED AUG 2 22017, Wednesday,June 28,2017 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE 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. File Number of Well History File PAGES TO DELETE Complete RESCAN [] 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 COMMENTS: S cannedby: Beved('Dianna~ncent Nathan Lowell -- TO RE-SCAN Notes: Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: Isl MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 12,2013 TO: Jim Regg /(./ZI 13 P.I.Supervisor �� 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-24 FROM: P John Crisp KUPARUK RIV UNIT 3H-24 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Comm Well Name KUPARUK RIV UNIT 3H-24 API Well Number 50-103-20235-00-00 Inspector Name: John Crisp Permit Number: 196-015-0 Inspection Date: 6/9/2013 Insp Num: mit.1Cr130610092226 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min J Well 3H-24 - Type In' W''TVD 5939 IA 1100 zlso 2140 - 2130 - PTD I 1960150 'Type Test SPT Test psi 1500 OA 400 510 500 500- — � Interval 4YRTST P/F P Tubing 2772 - 2770 2769 2765 Notes: 1.7 bbls pumped for test. SCANNED FEB 2 0 2014 Wednesday,June 12,2013 Page 1 of 1 STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r Convert to WAG Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r lime Extension r Change Approved Program r Operat. Shutdown r Stimulate - Other T Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 196 -015 3. Address: 6. API Number: Stratigraphic r Service r,% P. 0. Box 100360, Anchorage, Alaska 99510 - 50 - 103 - 20235 - 00 -- GO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25524 - - 3H - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12044 feet Plugs (measured) None true vertical 6268 feet Junk (measured) None Effective Depth measured 11936 feet Packer (measured) 11635 true vertical 6180 feet (true vertucal) 5940 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 4948 9.625 4989 3135 PRODUCTION 12001 7 12025 6253 REC EIVED Perforation depth: Measured depth: 11716'- 11736', 11746'- 11776' AUG 3 0 2012 True Vertical Depth: 6004'- 6020', 6028' -6051' AOG C Tubing (size, grade, MD, and ND) 3.5, L - 80, 11660 MD, 5959 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER SAB -3 PERMANENT PACKER @ 11635 MD and 5940 ND SSSV - CAMCO DS NIPPLE @ 518 MD and 517 ND 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 400 162 Subsequent to operation 2057 400 3651 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory T Development r Service n Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen / Darrell Humphrey Printed Name Bo. Christensen Title NSK Production Engineering Specialist Signature op Phone: 659 -7535 Date i . i Cif A / y/Z- RBDMS AUG3 0 2012 p. 3 c , 1' L . Form 10-404 Revised 11/2011 % �, Submit Original Only • • 3H -24 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03 /02 /09IConvert from Water Injector to WAG injector I I r . KUP • 3H -24 ConocoPhillips ' Well Attributes Max Angle & MD TD Aidska 1 ,,,, Wellborn API/UWI Field Name Well Status Inca( ") MD (RKB) Act Btm (RKB) • Lo ,,,,,. ou ,,, m 501032023500 KUPARUK RIVER UNIT INJ 71.89 4,269.78 12,044.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (R) Rig Release Date Weil comN:- 3H -zb, 3/5/2012 11 AM - SSSV: NIPPLE Last WO: 45.11 2/6/1996 Schematic - Aclwl Annotation Depth (61(13) End Date Annotation Last Mod ... End Date Last Tag: RKB 11,917.0 4/5/2009 Rev Reason: WELL REVIEW osborl 3/5/2012 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (8... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 37 SURFACE 95/8 8.835 41.0 4,989.4 3,134.9 40.00 L BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (/... set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 24.8 12,025.4 6,252.6 26.00 L -80 BTC -MOD Tubing Strings P Tubing Description String 0... String ID _. Top (RKB) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 37.0 11,660.9 5,960.0 9.30 L -80 ABM -EUE Completion Details Top Depth (TVD) Top Incl Noml... Top (RKB) (B) (°) Item Descrlpton Comment ID (In) CONDUCTOR, 37.0 37.0 1.00 HANGER FMC GEN IV HANGER 3.500 42 - 121 517.6 517.0 5.46 NIPPLE CAMCO DS NIPPLE 2.812 11587.6 5,902.8 38.99 SLEEVE-C BAKER CMU SLIDING SLEEVE; SHIFT CLOSED 6/13/96 2.812 ill 11,633.9 5,938.8 38.56 SEAL ASSY BAKER KBH -22 ANCHOR SEAL ASSEMBLY 3.250 11,634.8 5,939.5 38.55 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 NIPPLE, 518 it. _ 11,650.9 5,952.1 38.41 NIPPLE CAMCO D NIPPLE NO GO 2.750 11,660.0 5,959.3 38.32 SOS BAKER SHEAR OUT SUB 3.000 Illr Perforations & Slots Shot Top (TVD) elm (TVD) Dens Top (RKB) Btm (RKB) (RKB) (RKB) zone Date OR-« Type Comment 11,716.0 11,736.0 6,003.6 6,019.6 C-4, A -2, 3H -24 5/9/1996 4.0 IPERF 21/8" EnerJet; 0 deg. phasing GAS LIFT, 11,746.0 11,776.0 6,027.5 6,051.1 A -1, 3H -24 5/9/1996 4.0 IPERF 21/8" EnerJet; 0 deg. phasing 2'130 _ Notes: General & Safety I End Doh Annotation 9/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 f SURFACE, . 41 - 4,969 SLEEVE -C, 11,588 SEAL ASSY, 11,634 1. _\I PACKER, 11,635 W r NIPPLE, 11 651 'Hi SOS, 11,660 - 1 IPERF, _ - _ Mandrel Details 71,71 &77,736 - _ Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top (RKB) (RKB) PI Make Model (in) Sery Type Type (in) (PO Run Date Com... 1 2,130.2 2,004.4 43.52 CAMCO MMM 1 GAS UFT DMY RK 0.000 0.0 5/8/1996 IPERF, 11,74611,776 PRODUCTION, 2512,025 A ' TD, 12,044 ~ ~ • • ConocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2009 `;~~ ~~~~~°~' t~.l~G ~KS ?C1n} d,. ~y Y.str~~ _" ~ Q~J ! q~~ 1` . 3 ~ - 2~'~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Axichorage, AK 99501 Dear Mr. Maunder: Enclosed please fmd a spreadsheet with a list of wells from the Kupan~lc field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed 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 June 26~', 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16~', 2009. 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 Perry Klein at 907-659-7043, if you have any questions. Sincerel , \ Perry Klein ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/18/09 3H, 31 & 3Q PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibftor Corrosion inhibitor/ sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 7870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27:' NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 , 7/16/2009 3H-24 501032023500 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA ' 2.97 7h6/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 1911260 SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6.8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/30/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30/2009 MEMORANDUM To: Jim Regg ~~ Z~ZZ~a % P.I. Supervisor ~ FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-24 KUPARiJK RIV iJNIT 3H-24 ~ Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~~ Comm Well Name: KUPARUK RN iJNIT 3H-24 API Well Number: 50-103-20235-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS090608145708 Permit Number: 196-015-0 f Inspection Date: 6/7/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~] 3H-24 Type Inj. i N 'f~ 5939 jA 340 2200 ' 2150 ` 2150 P.T.D 196oiso TypeTest SPT Test psi ~ I500 ~~ QA Interval 4YRTST p~F P ~ TUblrig 350 1900 550 _ 1900 550 1900 550 ]90~~ Notes: Pretest pressures observed and found stable. Injection shut in recently, well still in warm condition. ~ . { F ^)rif~tT , .. ~~'~ ~~•~.. 1 i ~;. . '~ ! ~i~,., Wednesday, June 10, 2009 Page 1 of 1 ~~r~~~~~i~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .~ ~k u~~ Well Job # ~~ Log Description ,i~' f 5 ~ N0.4957 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11 /10/08 1C-119 11978488 INJECTION PROFILE 10/16/08 1 1 1J-101 11978491 PRODUCTION PROFILE 10/19/08 1 1 3H-02 12080447 INJECTION PROFILE ~ ~- ~- 10/24/08 1 1 3K-24 11978500 SBHP 10/26/08 1 1 1J-120 11978501 PRODUCTION PROFILE 10/27/08 1 1 3H-24 12080454 INJECTION PROFILE 10/28/08 1 1 3S-15 11978491 SBHP SURVEY - 10/18/08 1 1 i H-08 12100434 INJECTION PROFILE J 10/30!08 1 1 1 H-09 12096560 INJECTION PROFILE ~~ ZC to~3 ~~ (~} ('}~ 10/30/08 1 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 J MEMORANDUM TO: Jim Regg ':'J¡ / ~~/., ~)('?{)iì) ':...; . "'~r""ill' -. P.I. Supervisor . f. ,,-,( FROM: John Crisp Petroleum Inspector Well Name: KUPARUK RIV UNIT 3H-24 Insp Num: mitJCr060613 130121 Rei Insp N urn ) ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-24 KUPARUK RIV UNIT 3H-24 I qÞ-- DIS Src: Inspector Reviewed By: P.I. Suprv "Iß?- Comm NON-CONFIDENTIAL API Well Number 50-103-20235-00-00 Permit Number: 196-015-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth -W~II I 3H~~'Frype Ini~ I w I TVD -- ! 5940 P.T. 1960150 ITypeTest I S"PT ! !est -pSi 1.._.-··15~'~h Interval 4YRTST PIF P Notes 1.2 bbl's pumped for test. Wednesday, June 14,2006 Pretest I IA 1000 I OA I 400 -----r-::-'... Tubing I 2650 Initial 15 Min. 30 Min. 45 Min. 60 Min. j-i7~r"-- 1720 /:'''---1---:- ~4šõ-" I 450- 14~¡-+-..---·-J·_--·_· .1 26~-- 2650 1'-----2650 '-'1 .--=--=-__ SCANNED JUN 2 7 2006 Page I 0 f 1 t ~:<. ~ WEll NAME 2C-09 2M-33 3H-21 3H-24 3H-28 3H-32 3K-12 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field April 29, 2004 PTD# SERVICE CEMENT TOP VOLUME ':Jv.'V~: TYPE ft BBlS ,K \oJ ~',S': 1842210 Producer 54.0 9 ~ \:; , 1960720 Producer 40.0 5 ';t~í 1880080 Producer 34.0 5 L-\ ,L-\ ( 1960150 Injector 25.0 3 <,.,;) 1960370 Producer 20.0 4 J, Cc \ 2000010 Producer 10.0 2 l,3 \ 1861650 Injector 48.0 10 ~,~ ~ Arctic Set 1115.7 PPG Cement \ ~\ -'ï'~ \S t\ \ \) -..¡. c... ':>/ '(," <-u^' \,\ - . \a~ 'ù°"¥) y+- \- ~ ~ ConocoPh ill ips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 2, 2004 Mr. Tom Maunder )x t) rrv! Alaska Oil & Gas Commission ?4 r 5 if 0 l-\ 333 West ih Avenue, Suite 10 Il-\.~ Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on April 29, 2004. Dowell-Schlumberger batch-mixed Arctic Set II cement to 15.7 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, ~4.\c....CL~~""-\.\"-~ <:..L,~\~\a ~~~~« ('~~ " "\ ~ "'ù \-- U 'f'-- ,::f"/<...:..:c,..\ ~ \~ -\-\",(c CCé (v,Cd"'- ~ ,..k, V Vu II. ~'-'" \ \JQ.~ ~i( . (~ \ \ <-~ ~'-'C( ~"-- \- \a \?~ \:' v' .~ \...Q Cf-ç ',-,~ \ \. ~ '-..}....)« ì.,~ '-J--S \.\ ~..;\. v"-- '~.\"--f: rr~,,-~ ' r \ - r- \....Ä-.l~ ~; ~ '-~ "j;. . {;¡ 1"1N7 ~ f- I . ( ç (~- G t;j jZ--tceÞr Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment RECEIVED MAY 042004 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor ('.~\ Chair THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector DATE: June 27, 2002 SUBJECT: Mechanical Integrity Tests PAl 3H multiple KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. .. 'We'lli 3H-15 ITypelnj. I ' G .... i.T'.V.D, i~=I,u~!.n~.l ~oo I ~.~°6 t'~'°° I.' ~.,00 Ilnterval'l 4 .P.T.D:! 1871030 Type test. I P ITestpsi. I 1458.. J Casing I 2275 I 2875 I ..... 2850 I 2850 I P/F ~ .... P Notes: ~e,'I ~.-~ l~e,.nj.! ~ I ;'~'~i' I' ~ 'l'~u~n~ I ~0' I' ~0 I .~.~ I...~ I"n~e~a'! P.T.D.I 1870990 ITypetestl P JTest.psiI 1,482 I Casingl 200 I 2280 I 2270 I 2260 Notes: ."Well[ 3H-18I TypeIni.I".~ . !i~.v:°. I ~'~ I TUbing [. 1400 I 1400 I ~o I ~=~ .ll~tervall 4 P.T.D.[ 1880090ITypetest. ~, P lTestpsil 1458 ICasing, ~ 1875 ~ 2320 ~, ,,2320 ~ .2320 , I P/F. I _P Notes: WellI 3H-22 I Type,nj:l' s'1%V.D. I 5951 !Tubing I' 15'00 I .1490 I 1490 [ 1460 I'nterva'l 4,, P..T.D.! 1880110 ITypetesti P.. ITestpsiI 1488 I Cas!ngI ,110.0 I 2180 I 2150 !. 2140 I P/F Notes: WeilI 3H-24 ITypelnj. I s I T'.v.D. I 594b"lTUbingl 1600i'~o i ~=~i~0 II'ntervall 4 p.T.D,I 1960150 IType{esti P 'lT~stpsi'l ';1485'I casingI 1100 'i 2275 I 2260 J "2250'I P/F I E I Notes: ......... Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 2. of 3 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) M.I.T.'s performed: 5_ Attachments: none Number of Failures: g Total Time during tests: 3 hrs. cc: none ,SCANNED AUG 0 ~. ;;'002 MIT report form 5/12/00 L.G. mit(2) kru 3h 6-27-02js.xls 7/16/2002 oN oR BEFoPd c:t.o~-'~t~v°c PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/13/98 RUN DATE RECVD 96-015 96-015 96-015 96-015 CBL CDR 7212 CDR ~sEpIA ~DR/MWD ~SEPIA 04/26/96 05/20/96 05/07/96 05/07/96 96-015 8003 10-407 D SPERRY GR/ROP LR~OMPLETION DATE ~ q / f6 / 1-3 06/20/97 712 r/ DAILY WELL OPS R I/,,2o~/q~/ TO 37 ~ /9~/ yes ~d received? Are dry ditch samples required? Was the well cored? yes ~Analysis & description received? Are well tests required? yes ~ Received? Well is in compliance ~) Ihi6ial COMMENTS ye s~--r~r--~ ye s~r~-- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 28, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Annular Pump Volumes on Well Completion Reports COMM .... __ COMM ICOMM ~'~ R~ES,,ENG SRENG NRO - v- __ 6EOL isTAT TECH~ ~- STAT TE~CH~ ~' _ ___ -- -- F!LE ..~ Dear Mr. Commissioner: It has come to our attention volumes were not reported submitted. In an effort to reports these volumes. that there are 3 wells whose annular injection on the well completion reports as originally correct this oversight, the enclosed spreadsheet If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development 99e Alaska n,._:, a Gas cons.C~.mm,o..,,on-. '""~ Anchorage DKP/skad ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 23, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3H-24 (Permit No. 96-15) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3H-24. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA , ,-ASKA OIL AND GAS CONSERVATION CL...,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status et Well Classification of Service Well OIL [~] GAS ~ SUSPENDED [-'--] ABANDONEI~ SERVICE ~ Classification changed to an Injeclor 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-15 3 Address i8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20235 4 Location of well al surface -~'~' .............. 4. 9 Unit or Lease Name 998'FNL282'FVVL, Sec. 12, T12N, R8E, UM i .:_':,:~:~.~i,L~-~!~-.!i! ~ ~ ~.,~ KuparukRiver Unit 2335' FSL 1857' FEL, Sec. 34, T13N, RSE, UM i' '~;~"~ i -~ ./--~: ~,. 3H-24 2516' FSL, 1926' FEL Sec.34, T13N, RSE, UM ~ - -.' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Rig RKB 41', Pad 38' ADL2.5524 ALK2655 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 29-Jan-96 03-Feb-96 09-May-96 (perrd) NA feet MSL 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 12044' MD & 6268' TVD 11936'MD&6180'TVD YES ~XJ NO LJI NA feetMDI ~ 1380'ss APPROX 22 Type Electric or Other Logs Run SLT-J/GR/CCL, CDR 23 CASING:;.~IN~ ER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24" _ 200 CF 9.625" 40,0# L-80 SURF. 4989' 12.25"1090 sx AS III Lead, 660 sx Class G Tail 7" 26.0# L-80 SURF. 12025' 8.5" 200 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET {MD) 3.5" 11661' 11635' 11716'-11736'MD 4spf 6004'-6020'TVD 11746'-11776' MD 4 spf 6028'-6051"1'VD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Data First Production J Method of Operation (Flowing, gas lift, etc.) I Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ¢ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of litholo'gy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data. all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and t~me of each phase. Top Kuparuk C 11714' 6002' Bottom Kuparuk C 11726' 6011' Top Kuparuk A 11726' 6011' Bottom Kuparuk A 11806' 6025' Freeze protected wdh diesel 31. LIST OF ATTACHMENTS Daily Drillin~l History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~'J~" ~° ~,~.~,~L Title I~;~..i.~N'~ ~,l~l(rf.l,~l[l~ 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, a~r 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, jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 6/17/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:3H-24 RIG'PARKER 245 WELL ID: AK8429 AFC: AK8429 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD' KUPARUK RIVER UNIT SPUD:01/29/96 START COMP: BLOCK' FINAL: WI: 55% SECURITY'0 AFC EST/UL:$ 1590M/ 1910M API NUMBER: 50-103-20235-00 01/28/96 ( 1) TD: 121' (121) SUPV'RLM DAILY: 01/29/96 ( 2) TD: 272'(151) SUPV:RLM DAILY: 01/30/96 ( 3) TD: 2149' (1877) SUPV:RLM DAILY: 01/31/96 ( 4) TD: 4998' (2849) SUPV:GRW DAILY: 02/01/96 ( 5) TD: 4998' ( 0) SUPV:GRW DAILY: 02/02/96 ( 6) TD: 6150' (1152) SUPV'GRW DAILY: 02/03/96 { 7) TD: 10520' (4370) S UPV- GRW DAILY: 02/04/96 ( 8) TD.12044' (1524) SUPV:GRW DAILY' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Moved rig 4.5 of 6.2 miles from 3M pad enroute to 3H pad. $100,681 CUM: $100,681 ETD: $0 EFC: $1,690,681 MW: 8.8 PV/YP: 8/18 APIWL: 12.4 DRILLING Accept rig at 1500 hrs. 1/28/96. Spud at 0400 1/29/96. Drilled from 121' to 272' with hwdp. $61,531 CUM: $162,212 ETD: $0 EFC: $1,752,212 MW: 9.9 PV/YP: 28/30 APIWL: 8.8 DRILLING Directional drill from 270' to 2149' $103,035 CUM: $265,247 ETD' $0 EFC' $1,855,247 MW: 10.0 PV/YP' 19/28 APIWL: 8.2 DRILLING Directional drill from 2149' to 4998' $82,141 CUM: $347,388 ETD: $0 EFC: $1,937,388 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 N/U BOPE Held safety meeting. Run 9-5/8" casing. Cement surface casing. Washout and N/D diverter system. Install speedhead. N/U BOPE. $230,676 CUM: $578,064 ETD: $0 EFC: $2,168,064 MW: 8.5 PV/YP' 3/ 1 APIWL- 25.0 DRILLING Test casing to 2050 psi for 30 min. Run FIT. Drill from 5009' to 6150' $98,010 CUM: $676,074 ETD: $0 EFC: $2,266,074 MW: 9.4 DRILLING Drill from 6150' - 10520' $79,253 CUM: $755,327 ETD: PV/YP' 8/ 4 AP IWL' 6.8 $0 EFC: $2,345,327 MW: 10.9 PV/YP: 26/18 APIWL: 0.0 CIRC Drill from 10520' - 12044' Short trip, pump out 6 stds. Tight in sands, pull 21 stands to 9600' Monitor well- pump pill - pull 2 stds well flowing. Tight in hole. Monitor well. $85,652 CUM: $840,979 ETD: $0 EFC: $2,430,979 Date: 6/17/96 ARCO ALASKA iNCORPORATED WELL SU~{ARY REPORT Page: 2 02/05/96 ( 9) TD:12044' ( 0} SUPV:GRW DAILY: MW: 11.2 PV/YP: 35/40 APIWL: 5.8 CIRC POOH. Held safety meeting. Run 7" casing to 12030' Circ and condition mud. Hole initially packing off. Get full returns. Unable to move pipe. $163,604 CUM: $1,004,583 ETD: $0 EFC: $2,594,583 Date: 6/17/96 ARCO ALASKA iNCORPORATED WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:3H-24 RIG'PARKER 245 WELL ID: AK8429 AFC: AK8429 TYPE' STATE:ALASKA AREA/CNTY' NORTH SLOPE WEST FIELD' KUPARUK RIVER UNIT SPUD:01/29/96 START COMP' BLOCK: FINAL: WI: 55% SECURITY'0 AFC EST/UL'$ 1590M/ 1910M API NUMBER' 50-103-20235-00 04/13/96 (10) TD:12044' PB:11936' SUPV: dEB DAILY: MOVING RIG Move camp from 2M to 3H pad. Move rig. $0 CUM: $1,004,583 ETD: MW: 0 . 0 $0 EFC' $2,594,583 04/14/96 (11) TD:12044' PB:11936' SUPV:dEB DAILY: LOADING PIPE SHED W/TUBIN MW: 0.0 Accept rig 1400 hfs 4/13/96. Check well for pressure. ND tree. NU BOPE. Function test BOPE. Test BOPE to 300/3500 psi. Annular to 300 psi & 3000 psi. Accumulator capacity tesst, OK. Test 7" casing to 3500 psi for 30 minutes, lost 50 psi, OK. $46,860 CUM: $1,098,303 ETD' $0 EFC' $2,688,303 04/15/96 (12) TD:12044' PB:11936' SUPV:dEB DAILY: RIH WITH CBL/GR/CCL MW: 0.0 SW RIH 3-1/2" tubing to 10,912' RIH with 1-11/16" CBL/GR/CCL tools. Hung up at 470' due to stranded wire in lower sheave. Clear sheave & POH. RIH with CBL/GR/CCL tools. $31,200 CUM: $1,160,703 ETD: $0 EFC: $2,750,703 04/16/96 (13) TD:12044' ?B: 0' SUPV:DEB DAILY: NU 3-1/8" 5 KSI TREE MW: 0.0 Run SWS !-11/16" CBL/GR/CCL from 11918' to 10910' ELM. Tied into CDR log. POH with logging tools. Run 3-1/2" single completion assembly. Drop packer setting ball. Land hanger. Pressure tubing to 2500 psi & set packer. Held 2500 psi for 30 minute test, OK. Reverse circulate recovered diesel into well thru open GLM @ 2130' MD and freeze protect well. Set BPV. ND BOPE. Prepare to NU tree. $160,917 CUM: $1,482,537 ETD: $0 EFC: $3,072,537 04/17/96 (14) TD:12044' PB:11936' SUPV: DEB DAILY: RIG RELEASED MW: 0.0 NU tree. Test packoff to 5000 psi, OK. Test tree to 250/5000 psi, OK. Secure well. Release rig @ 0730 4/16/96. $4,830 CUM' $1,492,197 ETD' $0 EFC' $3,082,197 End of WellSummary for Well'AK8429 Sheet1 ANNULUAR PUMP VOLUMES: I TOTAL THIS TOTALS TO WELLS: CATEGORY 1 CATEGORY 2 CATEGORY 3 TIME PERIOD DATE 3H-24 2701 7 1 00 0 27117 27117 2M-33 301 01 1 00 0 30201 30201 3M-27 , 15328 1 00 0 15428 15428 Page 1 ARCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3H-24(W4-6)) WELL JOB SCOPE 3H-24 PERFORATE, PERF SUPPORT DATE 05~09~96 DAY 1 DALLY WORK INITIAL PERFS - INJECTOR OPERATION COMPLETE ~ SUCCESSFUL YES! YES InitialTbgPress I FinalTbgPress I lnitiallnnerAnn 0 PSI 600 PSI 0 PSI JOB NUMBER 0501961241.2 UNIT NUMBER KEY PERSON SUPERVISOR SWS-SC HWARTZ PEN ROSE Final Inner Ann I Initial Outer Ann I Final Outer Ann 600 PSI! 0 PSII 0 PSI DALLY SUMMARY PERFORATED WELL W/2 GUN RUNS. FIRST RUN INCLUDED CORRELATION GR/CCL AND 20' OF GUN. SECOND RUN CONTAINED ONLY 30' OF GUN. PERF'D INTERVALS 11,716' TO 11,736' (20') AND 11,746' TO 11,776' (30') W/2-1/6" ENERJET DEEP PENETRATORS @ 4 SPF, 0 DEG PHASING, ORIENTED @ 0 DEG F/LOW SIDE OF HOLE. HIGH ANGLE OF WELL (71 DEG) NECESSITATED PUMPING BOTH GUN RUNS DOWN W/DIESEL TIME LOG ENTRY 09:00 SWS ARRIVED, R/U. M/U GR/CCL/GUN #1. 10:15 ARM GUN, PAJ INTO LUBRICATOR AND M/U LUB ONTO WELL. 10:30 PRE-JOB SAFETY MEETING, P-TEST LINES/EQUIP TO 3500 PSi. 10:40 ~,! 12:00 12:50 13:30 14:00 15:10 15:20 RIH W/GUN RUN #1. HIGH WELL ANGLE (71 DEG) NESSESITATED PUMPING TOOLS DOWN W/DIESEL ~ 2 BPM. ON Bo'FrOM. CORRECT DEPTH AND LOG 11,900' TO 11,550' (DIFFICULT TO GET GOOD COLLAR LOG BECAUSE OF E-LINE STICK/SLIP ON TUBING WALL!. TIE IN. FIRE GUN: PERF'D INTERVAL 11,716' TO 11,736' (20') W/2-1/8" ENERJET DEEP PENETRATORS @ 4 SPF, 0 DEG PHASING, ORIENTED ~ 0 DEG F/LOW SIDE OF HOLE. POH. OOH. ALL SHOTS FIRED. M/U GUN FOR PERF RUN #2. RIH. PUMP DOWN GUN W/DIESEL ~ 2 BPM. ON BOTTOM. CORRECT DEPTH AND TIE IN. 16:00 16:45 R/D COMPLETE. SECURE WELL, MOVE OFF LOCATION. FIRE GUN: PERF'D INTERVAL 11,746' TO 11,776' (30') W/2-1/8" ENERJET DEEP PENETRATORS @ 4 SPF, 0 DEG PHASING, ORIENTED ~ 0 DEG F/LOW SIDE OF HOLE. POH. , , OOH. ALL SHOTS FIRED. R/D SWS. PA~£ COMPANY ARCO ALASKA~ INC, WELL NAM£ 3H-24 LOCATION 1 XUPARUK LOCATION 2 ALASKA MAGN£TIC DECLINATION 27.78 GRID CONVERG£NC£ ANGLE 0,00 DAT£: 31-JAN-96 WELL NUMBER 3H-24 AF£#: AX8429 APl WELL HEAD LOCATION: LAT(N/-S) 0,00 DEP(£/-W) 0,00 AZIMUTH FROM ROTARY TADL£ TO TARG£T IS TIE IN POINT(TIP) : M£ASURED DEPTH 121,00 TRUE V£RT D£PTH 121.00 INCLINATION 0.00 AZIMUTH 0,00 LATITUDE(N/-S) 0,00 338,29 PAGE NO, MEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft ft 121,00 0,0 121.00 156,00 35,0 156,00 250,00 94,0 249,98 342,00 92,0 341,95 461.94 119,9 461,64 550,87 645,50 735,48 825,38 915,08 1003.58 I094,02 1186,58 1281,00 1374,91 1467.29 1557,93 1653,67 1747,20 1839,06 1932.14 2025.13 2117,64 2213,30 2305,72 2397,16 2492.54 2587,62 2681,28 2776,55 2869,65 3148.09 3429,11 3708,72 3990.37 4269.78 4552,28 4832,55 4912.60 5113,35 88,9 550,12 94,6 643,83 90,0 732,20 89.9 819,89 89,7 907,12 88,5 993,27 90,4 1081,23 92,6 1170,44 94,4 1260,41 93.9 !348,99 92,4 1435,57 90.6 1520,23 95.7 1608.49 93.5 1692.86 91.9 1772,97 93.1 1850,90 93,0 1925,98 92,5 1996,73 95.7 2064,70 92,4 2125,45 91,4 2181,24 95,4 2236,23 95,1 2287,44 93,7 2332,65 95,3 2372,95 93,1 2406,84 278,4 2503.44 281.0 2601,18 279,6 2699,36 281,7 2800,48 279,4 2893,13 282,5 2982,93 280,3 3078,52 80,1 3107,60 200,7 3183,69 ************* ANADRILL ~************* SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMUTH LATITUDE SECTION !NCLN, N/-S ft de9 de9 ft 0.00 0,00 0.00 0.00 0.06 1,00 57,00 0,17 0,22 1,00 68,00 0,92 !,73 2,25 12,00 2,99 9,04 5,12 339,26 10,30 3H-24 DEPARTURE DISPLACEMENT at AZIMUTH ft ft de9 0.00 0,00 0.00 0,26 0.31 57,00 1.70 1,94 61,63 2,82 4,11 43,39 1,42 10,40 7,84 DLS deQ/ lOOft 0,00 2,86 0,21 2,05 2,87 I7,75 6,49 357,75 I?,03 -0,18 19,03 359,45 2,59 30,22 9,43 354,90 32,10 -1,OB 32,11 358,07 3,14 46,27 12,22 357,58 48,96 -2,14 49,00 357,50 3,I5 64.90 13,23 358,64 68,75 -2,78 68,80 357,68 1,16 84,68 13,75 356.07 89,65 -3,76 89,73 357,60 0.88 103,76 12,67 359,14 109,84 123,81 !4.28 353,24 130,84 148,01 16.64 344,75 154,97 176,58 I8.69 338,48 182.09 207.80 20,14 337,77 211,06 239,97 20,64 336,87 240,74 272,33 21,22 336,36 270,46 309,38 24,36 335,47 304,31 349,66 26,76 334,25 340,83 394,43 31,77 334,18 381.24 445,21 34,53 334,47 427,11 499,92 37,74 334,85 476,66 559.35 42,46 333.90 530.36 626,41 46,97 333,26 590.62 695,80 50,81 333,94 652.99 768,06 53,97 334,9I 718,32 845,90 55,63 336,00 789,2I 925,95 59,18 337,00 862,67 1007,93 63,08 336,87 938,11 1094.22 66,85 337.97 1017,80 1180.92 70,45 339,22 1098,53 1442,04 68.95 338.66 1342,23 I705,50 70,34 338,18 1587.23 1967,29 68,54 337,6I 1829,77 2230,15 69,38 337,76 2072,97 2493,73 71,89 338,44 2317,53 2761.56 71,04 337,64 2565,94 3024.90 69,07 335,84 2807,97 3099,43 68,33 336,34 2876,15 3285,I4 67,13 337,40 3046,98 -4,62 109,94 357.59 1,45 -6,09 130,98 357,34 2,33 -10,92 155,35 355,97 3,53 -20,02 183,19 353,73 2,96 -31,66 213,42 351,47 1,56 -44,07 244,75 349,63 0,64 -56,92 276,39 348,11 0,67 -72,08 312,73 346.67 3,30 -89,24 352,32 345,33 2,62 -I08,77 396,46 344,08 5,45 -130,81 446,70 342,97 -154,27 501,01 342,07 -180,06 560,10 341,25 -210,01 626,85 340,43 -240o96 696,03 339.75 2,98 3,46 5,14 4,74 4,20 -272,21 768,17 339,25 3,55 -304,58 845,95 338,90 1,98 -336.50 925,97 338,69 3.84 -368,63 1007,94 338,55 4,17 -401,76 1094,23 338,46 4,09 -433,39 1180,93 338,47 -527,21 1442,06 338,56 -624,11 1705,52 338,53 -722,61 1967,29 338,45 -822,42 2230,15 338,36 4,06 0,57 0,52 0,67 0,30 -920,71 2493,73 338,33 -1020,87 2761,56 338,30 -1124,89 3024,91 338,17 -1155,12 3099,44 338,12 r 0,93 0,40 0.93 I,I0 0,77 PAGE NO, 3 3H-24 ANADRILL ************** SURUE¥ CALCULATIONS CIRCULAR ARC MEASURED INTERVAL VERTICAL 5397,18 283,8 3292,30 5587.06 189,9 3359,70 5870,02 283.0 3458.70 6148,25 278,2 3557,02 6425,64 277,4 3650,11 TARCET STATION AZIMUTH LATITUDE SECTION INCLN, N/-S ft deg deg ft 3547,34 67,88 337,52 3289,19 3724,82 70,54 339.88 3454,56 3989.84 68,50 338,11 3702,00 4250.10 70,12 339,39 3944.57 4511.26 70,67 340,98 4190,40 DEPARTURE OISPLACEMENT at £/-W ft ft '1328,61 3547,3? '1393.05 3724,86 '1488.03 3989,86 -1582,35 4250.12 -1670,91 4511,26 AZIMUTH deg 338,00 338,04 338,10 338,14 338,26 DLS deg/ 10Oft 0,27 1,82 0,93 0,72 0,58 6613,80 6707,68 6?88,20 7265,85 7543,83 188,2 3714,03 93,9 3747.08 280,5 3842,12 277.6 3932,86 278.0 4027.78 4688,05 69,62 340,59 4357,51 4775,87 69,15 339,91 4440,21 5039,62 71.24 340,66 4688,66 5301.80 70.61 340,60 4936,20 5562,88 69.46 340.35 5182,44 -1729.15 4688.06 338.36 -1758,85 4775,88 338,39 -1847,87 5039,65 338,49 -1934,90 5301,87 338.60 -2022,22 5563.01 338,68 0,59 0.83 0,78 0,23 0,42 7826.32 8104,73 8390,88 8671.57 8950,60 282,5 4129,75 278,4 4236,9! 286,1 4347,40 280,7 4456,28 279.0 4572,45 5826,14 68,22 340,47 5430,64 6082,91 66,50 340,28 5672.65 6346,63 68,08 341,12 5921,77 6605.05 66,27 340,82 6166,34 6858,35 64,52 342,01 6406,79 -2110,56 5826,34 338.76 -2196.85 6083,18 338,83 -2284,08 6347,00 338,91 -2368,42 6605,54 338.99 -2449,27 6859,00 339,08 0,44 0.62 0,62 0,65 0.74 9232,79 9508,57 9792,99 10074,40 10352,64 282.2 4690,49 275,8 4807.25 284,4 4929,93 281.4 5050,59 278,2 5174,84 7114,05 66.02 342,44 6650.86 7363,10 63.87 343,14 6889.49 7618,88 65.02 342,58 7134,69 7872,51 64,20 341,89 7376,80 8121,04 62,75 341.29 7613.01 -2527.51 7114,93 339,19 -2601,44 7364,28 339,31 -2677.07 7620.40 339,43 -2754,63 7874,33 339,52 -2833,22 8123,12 339,59 0,55 0,81 0,44 0,37 0,56 10629,48 10816,33 10908,76 11003,83 11098,50 276.8 5305,38 186,8 5399,02 92,4 5448,20 95,1 5501.38 94,7 5557,37 8364,88 60,98 340,7? 7843,90 8526,48 58.86 338,96 7995.71 8604,73 56,84 339,16 8068,79 8683,53 55.15 339.04 8142.41 8759,85 52,32 339,28 8213,74 -2912,52 8367,17 339,63 -2968,11 8528,83 339.63 -2996,07 8607.08 339.63 -3024,20 8685,89 339,62 -3051,35 8762,21 339,62 0,66 1,42 2,20 1.78 2.99 11192.02 11283.26 11374,90 11462,68 11640,76 93,5 5616,27 91,2 5677,12 91,6 5741,58 87.8 5806,67 178.1 5944.19 8832,47 49.60 338,86 828i,58 8900.43 46,72 339,44 8345,i0 8965,54 43,87 339.34 8406.05 9024,39 40.40 340,32 8461,30 9137.50 38.50 339.03 8567,40 -3077,29 8834,84 339,62 -3101,49 8902,80 339,6I -3124,41 8967,92 339,61 -3144,73 9026.79 339,61 -3184.01 9139,93 339,61 2,94 3.19 3,12 4,02 1,16 11832,46 191,Z 11966,14 133.7 PROJECTED TO T~: 12044.00 77,9 6096.05 9254.47 36,72 338,34 8676.38 6204.22 9333.00 35.24 339.20 8749,58 6267,81 9377,92 35,24 339.20 8791,58 -3226,52 9256,89 339.60 -3254,96 9335,42 339,59 -3270,92 9380,34 339,59 0,95 1.17 0,00 · ARCO Alaska, Inc: - ..: Date: May 13; 1996 · _ RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-11!9 B P.O. Box 100360 Anchorage, AK 9951 0-0360 Transmittal #: 9688 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 Q-22_ ARC 5 10/09/95 1F-19 ARC 5 03/22/96 3H-24 CDR 02/04/96 .,.3 H-28 .... CDR 02/13196 ACknoWledged: . .. ' 4957-879O 4568-9457 50-103-20235-00 50-103-20236-00 50-i03-20236-00 Date: DISTRIBUTION' Mr. Vernon E. Pringle Jr. DeGloyler and MacNaughton One Energy Square Dallas, TX 75206 Sharon Allsup-Drake DS Development ATO - 12O5 Clifton Posey Geology ATO - 1251 ChapmanZuspan NSK Wells Group NSK 69 ? Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10'173 Company: Alaska ()il S, Gas Cons C:omrn Attn: Larry Grant 300'1 Porcupine [:)rive Anchorage, Al( 995[)1 Field: i(u[)aruk (Open Hole) 5/6/96 MS Well Job # Log Description Date BL RF Sepia DIR IViWD Tape 1 Q-22 ?~-- ! ~-,] 0 ...... 95340 ARC5 ............. 951 009 --1 ! F-1 9 ~() -- O ~,-;z 96099 ARC5 ..960322 1...... 3H-24 ~(~'-0~- 960.7,3' CDR .. 960204 I1 1 3H-28 ..~[~p, _ .., 96087 CDR. 960213 I 1 ........ 3, H'28 ~/ "' 96087 CDN ,, 960213 I I ........... 3H-28 96087 CDR/CDN 960213 1 ...... , ....... .. .... ..... ,.. _.~_ Please sign and retur~ one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Date: April 23, 1996 Transmittal #: 9673 RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATOo1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. %- 07;,. 1F.19 c/l---.~ ~,-~ 1Q-21 ~¢'---¢ ~ol Q-22A ~-//"fl 2X- 1 7 ~l,-eJ¢ 3H-24 Cement Bond Log SLTJ-GR/CCL 04/12/96 Cement Bond Log SLTJ-'GR/CCL 04/14/96 Cement Bond Log SLTJ-GR/CCL 04/14/96 Cement Bond Log SLTJ-GR/CCL 04/11/96 Cement Bond Log SLTJ-GR/CCL 04/14/96 Receipt Acknowledge: DISTRIBUTION' Date' Sharon AIIsup-Drake DS Development ATO-12O5 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage. AK 99501 Please acknowledge 6682-9356 9155-10318 8172-9383 6000-7644 10910-11912 c hapman/Zuspan NSK Wells Group NSK69 KA OIL AND GAS CONSERVATION COMMISSION / I i' 1 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januaw 26.1996 Michael Zanghi, Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 ---Re: Kuparuk River Unit. 3~-24 ARCO Alaska, Inc. Permit No 96-O15 Surf Loc. 9g4'FNL, -281'FWL, Sec. 12, T12N, R8E, UM Btmhole Loc. 2755'FSL, 2262'FEL, Sec. 34, T13N, R8E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to ddii 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddlling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the (::: um field inspector 659-3607. David W. Johnston Chairman BY ORDER OF THE COMMISSION lencl c: Dept of Fish & Game, Habitat Section - w/o end Dept of Environmental Conservation - w/o end STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMIS,~ION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill [--~ lb Type el Well Exploratory r'] Stratigraphic Test D Development Oil X Re-Entry [~] Deepen [~ Service [~ Development Gas [~ Single Zone X Multiple Zone r~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 38' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ~¢,DL 25524, ALK 2655 4, Location of well at surface 7. Unit or property Name 1 1, Type Bond (see 2o AAC 25,025) 994' FNL, 281' FWL, Sec. 12, T12N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8, Well number Number 2579' FSL, 2192' FEL, Sec. 34, T13N, RSE, UM ~3H-24 '~U-630610 At total depth 9, Approximate spud date Amount 2755' FSL, 2262' FEL, Sec. 34, T13N, RSE, UM 1/23/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 3H-21 12126' MD 2192 @ Target feet 11.7' @ 425' feet 1 920 6244' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 66.5° Maximurnsurface 1852 pslg At total depth (TVD) 3400 pslg 18, Casing program Setting Depth size Specifications Top Bottom Quantity/of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD linclude stage data) '24' 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' ±200 CF 12.25' 9.625" 40.0# L-80 BTC 5182' 41' 41' 5223' 3129' 1090 Sx Arcticset III & HF-ERW 660 Sx Class G 8.5' 7' 26.0# L-80 BTCMOE 12085 41' 41' 12126' 6244' 150SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~=~"~ ~, i V~-D Intermediate Production Liner JAN 1 6 Pedoration depth: measured true vertical AJa~a Oil & Gas Cons. Commission 20. Attachments Filing fee X Property plat ~] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis [~ Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify ~hat the fore. lng is true and correct to the best of my knowledge Signed ~-?~{/~ / ' Title Drill Site Develop. Supv. Date / "'"fCl~'~ Permit' mber ('-" 4~' )P~lnumber Commission Use Only ~"~--1~"' LF~O- ~O'~- ~ 0 ~3~>'" I Appr°valdate/ ~, ~2 JSeocoverlotterfor other requirements Conditions of approval Samples required [--J Yes J~Tj' No Mud log required [--J Yes [~ No Hydrogen sulfide measures D Yes [] No Directional survey required J~ Yes J~ No Required working pressure for BOPE D 2M [] 3M [-I 5M D 1OM r"l 15M Other: Original Signea By David W, J0hnstonby order of /4 /(~) Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 ;ate , 0 , 1 1 1 , . 1 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3H-24 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,223')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. 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 (12,126') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (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.) ND BOPE. NU tubinghead & either full opening valve. Run cased hole cement bond logs. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. JAN 1 6 1 )96 AI~sK8 Oil & 0~ Con,q, OODltili~ioD Anchorage DRILLING FLUID PROGRAM Well KRU 3H-24 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 through 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 General 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 1852 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3H-24 is 3H-21. As designed, the minimum distance between the two wells would be 11.7' @ 425' MD. Drillin~ Area Risks: Risks in the 3H-24 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 7" casing will be topset above the Kuparuk and Nordic Rig #1 will drill out a 6-1/8" hole, and run a 5' liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.4 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS Well KRU 3H-24 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 an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3H-24 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3H-24 be permitted for annular pumping occurring as a result of the drilling project on DS 3H, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3H surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe 'I-VD) + 1500 psi 3H-24 Max Pressure = 3452 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ,, ' ~"'-~' "' ';' V ~:~; ~ ARCO ALASKJ~, Inc. Pad 3H 24 slot #24 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes ]NTEQ Your ref : 24 Version #8 Our ref : prop1441 License : Date printed : 11-Jan-96 Date created : 26-0ct-95 Last revised : 11-Jan-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nTO 24 56.740,w150 0 47.688 Slot location is n70 24 46.964,w150 0 39.451 Slot Grid coordinates are N 6000663.082, E 498654.360 Slot local coordinates are 994.00 S 281.00 E Reference North is True North Main calculation performed with 3-D Minimu~ Distance method Object wel [path PGMS <O-7370'>,,13,Pad 3H PG/4S <O-10234'>,,22,Pad 3H PGNS <O-11346'>,,21,Pad 3H P#SS <1506-2076~>,,20,Pad 3H PMSS <1622-4449">,,20,Pad 3H PC~S <O-9050*>,,20,Pad 3H PMSS <1506-3878,>,,20,Pad 3H Pr.~tS <O-10293~>,,18,Pad 3H PMSS <1743-6660~>,,26,Pad 3H PIllS <O-10730,>,,31,Pad 3H PGMS <O-12610'>,,25,Pad 3N PGNS <O-9360'>,,23,Pad 3H Closest approach with 3-D minimu~ distance method Last revised Distance M.D. Diverging from M.D. 13-Nov-91 552.1 40.0 11807.0 13-Nov-91 500.9 325.0 11925.9 13-Nov-91 477.0 300.0 12125.9 13-Nov-91 452.0 300.0 11230.6 13-Nov-91 428.0 100.0 9420.0 13-Nov-91 401.5 325.0 325.0 13-Nov-91 3T5.4 325.0 325.0 13-Nov-91 353.0 120.0 12120.0 13-Nov-91 525.4 325.0 11920.0 13-Nov-91 328.1 60.0 120.0 13-Nov-91 238.0 100.0 120.0 13-Nov-91 37.2 300.0 1746.6 13-Nov-91 113,0 220.0 220.0 13-Nov-91 88,1 100.0 300.0 13-Nov-91 138.1 100.0 300.0 13-Nov-91 163.2 100.0 120.0 13-Nov-91 213.0 20.0 20.0 13-Nov-91 187.5 300.0 300.0 13-Nov-91 37.0 220.0 220.0 13-Nov-91 11,7 425.0 425.0 13-Nov-91 13.0 200.0 200.0 13-Nov-91 13.0 200.0 200.0 13-Nov-91 13.0 200.0 6340.0 13-Nov-91 13.0 200.0 200.0 13-Nov-91 63.0 325.0 325.0 20-Mar-94 389.7 300.0 8920.0 20-Apr-94 25.0 0.0 0.0 19-Apr-94 222.1 100.0 100.0 31-0ct-95 25.0 0.0 0.0 ARCO ALASKA, Inc. Structure : Pod 3H Well Field : Kuparuk River Unit Location : Nor'th Slope, Alaska Created by : jone~ For: D P~H Date plotted : II--Jan--96 Plot Referer~e is 24- Vemi~,~ ~8. [ Coordin~ee are in feet referm~ce slot rrue Vertical Depths ore reference EKB (Porker ~245). N 21.71 DEG W 9529' (TO TARGET) 600 _ - 0 _ - 600 _ 1200_ _ 1800_ _ 2400_ _ 3000_ - - ~2~_ 4g~, 6600_ TARGET LOCATION: 257g' FSL, 2192' TEL SEC. 54, T13N, RSE TARGET TVD=6018 TMD=I 1851 DEP=9529 NORTH 8853 WEST 5525 <-- Wesf 4200 3600 3000 2400 1800 1200 600 0 600 TD LOCATION: 2755' FSL, 2262' FEL SEC. 54, T13N, RSE Bose HRZ . 10200 9600 9000 8400 7800 7200 6600 6000 - _ 5400 _ _ 4800 _ _ 4200 _ Begin Angle Drop RKB EI..EVAllON: 79' _ 3600 I KOP 1¥D=3OO TMD=300 DEP--O - 9 5/8 Cosing Pt ~ 6.oo \ 3o~ 12 ~ Base West Sak Sands _ uu ;.oo \ _ ,oo '~36.00 '~ Top west Sak Sands - "X.~2'00 B/ PERMAFROST TVD=1629 TlVlD=1770 DEP=558 ~.~ 48.00 \ _ 1800 ~'-~oo T/ ucNu SN~S ~=19~9 T~=225~ ~E~=913 \ ~ EOC TVD=2052 TMD=2518 DEP=1149 \ _ 12oo ~ T/ W SAK SNDS TVD=2529 TMD=$716 DEP=2249 ~ ~op U~nu 95/8"CSGPTTVD=5129TMD=5225DEP=3631~'~ rmofrost ~ EC 12 I12N 88E 800 66.54 DEG TARGET DEG TI) / 7" CSG PT TVD=~244 TMD=I21g0 D~P=0710 { I I I I I I I I I { I I I } I I I } } J I I I I I I I I { J { I I I I 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 Scole 1 · 500.00 Vertical SecHon on 358.29 ozimu{h wifh reference 0.00 N, 0.00 E from sial #24 !Created by : jone~ For: D PETRASH ate plotted : 11-Jan-96 !Plot Reference is 24- Version ITrue Verticol DepU~s ore reference RKB (Porker ~245). ARCO ALASKA, Inc. Structure : Pad 5H Well : 24 Field : Kuparuk River Unit Location : North Slope, Alaska <-- Wesf ~o,~, · ,o.oo 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 t''''' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' , oo'"t 280t t28° ~o1 ,% ~,,oo ~ ~2~o 2~~ ~ ~ ~ O0 240 ~o~ ~ ~,ooo ~,~o~ 1 60 60 1200 900 ~0 2.500 40 20 20 1700 0 ~00 I O~ 12OO 8~ 800 1 ~ · · 70O 240 220 200 < West ~ ,. ~o.oo JAN 16 2O Created by : jones For: D PETRASH Date plotted : 11-Jan-96 Plot Reference is 24 Version #8. Coordinates are in feet reference slot ~24. Tr~e Ve~icol Depkhs are reference RK~ (Pad(er ~245). I I 960_ _ 920_ 880_ 840_ 800_ 760_ 720_ 680_ _ 640_ _ 600_ _ 560_ ARCO ALASKA, Inc. Structure : Pad 5H Well : 24 520_ ~0 ~ ~ 3200 4OO 360 2000 320 Field : Kuparuk River Unit Location : North Slope, Alaska < - - W e s f sco,~ 1 ' 20.00 520 480 ~0 400 560 320 280 240 200 160 120 80 40 0 40 80 120 __960 __ __920 _680 2000 _840 0 _800 _720 3500 / - _680 ~0 2000 _ 1800 _640 3400 _ 1600 _600 _ 1700 _560 1700 1900 _520 _ 1600 1800 5100 3000 14oo 14OO 1300 _480 _ _440 _ _400 _ _360 13oo _ _320 1200 _280 240 200 16O 12O West 80 40 0 40 80 120 Scale 1 · 20.00 0 !Creoted by : jones For: D PETP-,ASH !Date p~otted : 11-Jon-96 Plot Reference is 24 Version #8. iCoord[nates are in fee~ reference slot ~24. True Vertical DepLhs~EKB (Porker ~245). 2700_ _ 2600_ _ 2500_ 2400_ _ 2300_ _ 2200. 2100. /X 2000_ 1900_ ARCO ALASKA, Inc. Z Sfrucfure : Pad 5H Well : 24 Field : Kuporuk River Unif Locotion : North Slope. AIosko <-- Wesf Scole 1' 50.00 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 100 ~ 1800_ I 1700. 49O0 - 2900 1 600__ ~ 4~00 ~300 2400 1500__ 0 4700 ~ 2800 _ 4600 1 400_ . 4500 0 2700 2300 1200_ 0 '-%,28oo '~200 ~, 2100 2500 o tn 11oo 41oo -' ~ 2400 - 4000 ~ 1 ooo_ ° I I I I t I I t I t I 3700 9OO 3600 !2800 2700 3500 5800 0 3400 '2700 5700 54005300 3200 t i2600 5200 5100 51005000 ~ 3OO0 2500 2100 _2700 _ _2600 _2500 _ _2400 _ _2300 _ _2200 _ _2100 - _2000 j _1900 I 1800 Z 0 _1700 I - _1600 _ _1500 _ _1400 _ _lJO0 1200 1100 .. 1000 0 0 0 1500 14.00 1500 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 <-- Wesf 0.oo KUPARUK RIVER UNi, 20" DIVERTER SCHEMATIC 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 2. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE 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 ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20' - 2000 PSI ANNULAR PREVENTER. DKP 11/9~J4 I 7 , 6 5 4 I 13 5/8" 5000 PS, STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 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 FILL BOP STACK AND MANIFOLD WITH WATER. 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. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINLrrEs. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 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 ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST BOttOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. lO. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 50(X) PSI SPACER SPOOL 4. 135/8" - 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 II VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KO(:~ PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE ELOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. GEOL AREA ttached ................... ~ N appropriate ................ ~ N name and number ............... ~ N in a defined pool ............. ~ N proper distance from drlg unit boundary. . .~ N proper distance from other wells ...... ~> N .creage available in drilling unit ...... ~ N is wellbore plat included ......... ~ N y affected party .............. ~ N appropriate bond in force ......... ~ N ~e issued without conservation order ..... ~ N e issued without administrative approval.. ~ N ~e approved before 15-day wait ........ ~ N :ring provided ............... .~ N .rig protects all known USDWs ........ ~ N luate to circulate on conductor & surf csg.. N tuate to tie-in long string to surf csg . . . Y ~ 'er all known productive horizons ...... ~ N 'ns adequate for C, T, B & permafrost .... ~ N ~kage or reserve pit ............. ~ N [1, has a 10-403 for abndnmnt been approved..__y_~/~l--- £1bore separation proposed .......... ~ N required, is it adequate .......... -~ N ~id program schematic & equip list adequate .~-Y~' N ~te .............. .~ N :ating adequate; test to ~'~ ;s~g~ N ~ld complies w/API RP-53 (May 84) ...... ~i~----{%-~ =cur without operation shutdown ....... ~ N of H2S gas probable ............ (J~ N )e issued w/o hydrogen~N~ ted on potent~~r~essure zones. .... Y N lysts o_~_~_ow gas zones. ......... Y N · on survey (if off-shore) ......... Y N ~/phone for weekly progress reports ..... Y N [exploratory only] ENGINEERING: COMMI SS ION: Comments/Instructions: TAB PROGRAM: exp [] dev ~". redrll [] serv [] ~ellbore seg F~ v~# Ill ~, 0 ON/O~ SHO~ o~t REMARKS Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ************************* SCHLUMBERGER ............................ COMPAN~ NAME : ARCO ALASKA, INC. WELL NAIVE : 3H-24 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE S TA TE : ALASKA API NUMBER : REFERENCE NO : 96073 MAY .. 0 7 1996 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE: **** REEL HEADER **** SERVICE NAi~E : EDIT DATE : 96/04/26 ORIGIN : FLIC REEL NAME : 96073 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 3H-24, API #50-103-20235-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/26 ORIGIN : FLIC TAPE NA~E : 96073 CONTINUATION # : 1 PREVIOUS TAPE : COIZ~TFJFT : ARCO ALASKA, INC., KUPARUK 3H-24, API #50-103-20235-00 TAPE HEADER KUPARUKRIVER MWDLOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 96073 KADRMAS WHITLOCK WELL CASING RECORD 1ST STRING 2ND STRING 3H-24 501032023500 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 26-APR-96 BIT RUN 2 BIT RUN 3 12 12N 8E 994 281 79.00 79.00 38.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4990.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 3RD STRING PRODUCTION STRING Well drilled 1-FEB through 4-FEB-96 with CDR only. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED k~ERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SO?4~L~Y LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASUt~EDDEPTH) START DEPTH STOP DEPTH 4947.0 12043.0 BASELINE DEPTH 88888.0 11891.5 11871.5 11864.5 11773.0 11736.0 11698.5 11660.0 11631.0 11626.0 11607.0 11564.0 11449.0 11430.0 11403.5 11358.5 11328.5 11285.0 11172.5 .......... EQUIVALENT UNSHIFTED DEPTH MWD 88887.5 11891.0 11870.0 11863 5 11772 0 11735 5 11698 0 11658 5 11628 5 11624.5 11606.5 11563.5 11448.0 11430.0 11402.5 11357.0 11327.5 11284.0 11171.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE: 11154.5 11098.5 11016.0 10965.5 10929.0 4950.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ RE~L~gKS: 11153.0 11097.0 11013.5 10964.0 10928.5 4950.0 BIT RUN NO. MERGE TOP MERGE BASE The depth adjustments shown above reflect the MWD GR to the CBT GR logged bySWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 549019 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0HT4~549019 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0Iff4~I549019 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0H~4549019 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~ff4549019 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~M549019 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 549019 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 549019 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 549019 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI 549019 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12042.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 GR.MWD FET.MWD -999.250 GRCH. CBT -999.250 DEPT. 12000.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 249.579 GR.MWD FET.MWD -999.250 GRCH. CBT -999.250 DEPT. 11000.000 RA.MWD 4.317 RP.MWD 4.510 VRA.MWD VRP.MWD 4.471 DER.MWD 4.445 ROP.MWD 346.081 GR.MWD FET.MWD 0.860 GRCH. CBT 65.375 DEPT. 10000. 000 RA.MWD 3 . 880 RP.MWD 3 . 918 VRA.MWD VRP.MWD 3. 964 DER.MWD 3 . 905 ROP.MWD 301 . 714 GR.MWD FET.MWD O. 122 GRCH. CBT -999. 250 DEPT. 9000.000 RA.MWD 4.030 RP.MWD 4.210 VRA.MWD VRP.MWD 4.008 DER.MWD 4.148 ROP.MWD 278.001 GR.MWD FET.MWD 0.343 GRCH. CBT -999.250 DEPT. 8000.000 RA.MWD 4.065 RP.MWD 5.574 VRA.MWD VRP.MWD 5.527 DER.MWD 5.195 ROP.MWD 511.697 GR.MWD FET.MWD 0.112 GRCH. CBT -999.250 DEPT. 7000.000 RA.MWD 2.787 RP.MWD 3.038 VRA.MWD VRP.MWD 3.093 DER.MWD 2.938 ROP.MWD 311.377 GR.MWD FET.MWD 0.221 GRCH. CBT -999.250 DEPT. 6000.000 RA.MWD 4.155 RP.MWD 4.282 VRA.MWD VRP.MWD 4.330 DER.MWD 4.239 ROP.MWD 194.207 GR.MWD FET.MWD 0.296 GRCH. CBT -999.250 -999.250 -999.250 -999.250 -999.250 4.282 111.845 3.942 83.488 3.698 114.384 4.242 139.051 2.856 96.496 4.125 95.513 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE DEPT. 5000. 000 RA.MWD 4. 613 RP.MWD VRP.MWD 3. 980 DER.MWD 4. 737 ROP.MWD FET.MWD 1 . 059 GRCH. CBT -999. 250 DEPT. 4946.500 RA.MWD -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD FET.MWD -999.250 GRCH. CBT -999.250 4.799 -999.250 -999.250 -999.250 VRA.MWD GR. MWD 5. 031 115.211 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAi~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFi~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH MWD 4947.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (Ffl~MORY or REAL-TItlE): 7]9 DRILLER (FT) : STOP DEPTH 12043.0 04-FEB-96 FAST 4.0C MEMORY 12044.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE: TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 4947.0 12044.0 76 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 35.2 68.3 TOOL NUMBER RGS055 8. 500 4990.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.90 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 880 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 670 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 4990' - 12044' HOLE ANGLE AT TD = 35.24 DEG @ 12044' RES TO BIT: 43.04'; GR TO BIT: 53.46' TD WELL @ 20:44 03-FEB-96 CHLORIDES 600 PPM DATA FROM DOWNtIOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 78.0 78.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 549019 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LWl Otff4M549019 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LWl OH~k~549019 O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW1 0t~4M549019 O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LWl 0HM~549019 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OH~M549019 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 549019 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 549019 O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR 549019 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12043. 000 ATR.LW1 -999.250 PSR.LW1 -999.250 ATVR.LW1 PSVR.LW1 -999.250 DER.LW1 -999.250 ROPE.LW1 119.235 GR.LW1 TAB. LW1 -999. 250 DEPT. 12000. 000 ATR.LW1 3. 755 PSR.LW1 3.599 ATVR.LW1 PSVR.LW1 -999.250 DER.LWl 3. 648 ROPE.LW1 246. 851 GR.LW1 TAB. LW1 O . 274 DEPT. 11000.000 ATR.LW1 4.256 PSR.LW1 4.552 ATVR.LW1 PSVR.LW1 4. 638 DER.LW1 4. 448 ROPE.LW1 335. 609 GR.LW1 TAB. LW1 O. 859 -999.250 -999.250 -999.250 -999.250 4.438 115.432 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE: DEPT. 10000. 000 ATR . LW1 PSVR . LW1 4.037 DER. LW1 TAB. LW1 0.122 DEPT. 9000. 000 ATR . LW1 PSVR . LW1 4.120 DER. LW1 TAB. LW1 O . 344 DEPT. 8000. 000 ATR. LW1 PSVR . LW1 5.491 DER. LW1 TAB. LW1 0.111 DEPT. 7000. 000 ATR. LW1 PSVR. LW1 3. 093 DER. LW1 TAB. LW1 O. 221 DEPT. 6000. 000 ATR. LW1 PSVR . LW1 4.330 DER. LW1 TAB. LW1 O . 296 DEPT. 5000. 000 ATR. LW1 PSVR . LW1 3 . 980 DER. LW1 TAB. LW1 1. 059 DEPT. 4946. 500 ATR. LWl PSVR. LW1 -999. 250 DER. LW1 TAB. LW1 -999. 250 3. 893 PSR . LW1 3. 937 ROPE. LW1 4.065 PSR. LW1 4.184 ROPE. LW1 4. 048 PSR.LW1 5. 159 ROPE. LW1 2. 787 PSR. LW1 2.938 ROPE. LW1 4. 155 PSR. LW1 4.239 ROPE. LW1 4.613 PSR . LW1 4.737 ROPE. LW1 -999. 250 PSR. LW1 -999. 250 ROPE. LW1 3. 960 ATVR. LW1 299. 273 GR. LW1 4. 248 ATVR. LW1 277. 866 GR. LW1 5. 531 ATVR. LW1 498. 643 GR.LW1 3. 038 ATVR. LW1 311.377 GR.LW1 4. 282 ATVR. LW1 194 . 207 GR. LW1 4. 799 ATVR. LW1 -999. 250 GR. LW1 -999. 250 ATVR. LW1 -999. 250 GR. LW1 4. 005 87. 523 3. 786 112. 981 4.233 136.688 2.856 96.496 4.125 95.513 5.031 115.211 -999.250 61.031 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION ' O01CO1 DATE : 96/04/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/04/26 ORIGIN : FLIC TAPE NA~E : 96073 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : ARCO ALASKA, INC., KUPARUK 3H-24, API #50-103-20235-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-APR-1996 12:52 PAGE: **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 96/04/26 ORIGIN : FLIC REEL NAi~E · 96073 CONTINUATION # : PREVIOUS REEL : COf~!ENT . ARCO ALASKA, INC., KUPARUK 3H-24, API #50-103-20235-00