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Home My WebLink About191-125MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-01 KUPARUK RIV UNIT 3Q-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-01 50-029-22220-00-00 191-125-0 W SPT 6436 1911250 3000 1330 1332 1332 1330 100 110 110 110 REQVAR P Josh Hunt 8/28/2024 This is a 2 year MIT-IA required by AIO 02B.068. This well was tested to a starrting pressure of 3300 psi 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 3Q-01 Inspection Date: Tubing OA Packer Depth 200 3300 3130 3110IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240828155435 BBL Pumped:4.3 BBL Returned:4.2 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 99 99 9 9 9 AIO 02B.068 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 14:07:50 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-01 KUPARUK RIV UNIT 3Q-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3Q-01 50-029-22220-00-00 191-125-0 W SPT 6436 1911250 3000 1266 1267 1266 1266 240 270 270 270 REQVAR P Bob Noble 8/13/2022 MITIA to max anticipated injection pressure as per AIO 2B.068 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 3Q-01 Inspection Date: Tubing OA Packer Depth 720 3290 3140 3140IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814152707 BBL Pumped:3.2 BBL Returned:3 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 99 9 9 9 AIO 2B.068 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:32:20 -08'00' • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg DATE: Monday,August 08,2016 P.I.Supervisor r� `*'Gr j U�3(I L SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-01 FROM: Bob Noble KUPARUK RIV UNIT 3Q-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-01 API Well Number 50-029-22220-00-00 Inspector Name: Bob Noble Permit Number: 191-125-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804100950 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-o1 Type Inj W-TVD r 6436 . Tubing 2860 2860 - ! 2860 - 2860 . PTD 1911250 - Type Test SPT Test psi 3000 - IA 1075 3500 - 3360 - 3340 - Interval REQVAR P/F P OA 460 540 - 730 - 720 ' Notes: MIT-IA per AIO 2B.068,max injection pressure EKED MAY I. 9 2 0 1 7-4 Monday,August 08,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,November 19,2015 TO: Tun R � � 11(301 is SUBJECT: Mechanical Integrity Tests P.I.Supervisor CONOCOPHILLIPS ALASKA INC 3Q-01 FROM: Chuck Scheve KUPARUK RIV UNIT 3Q-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ggr NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-01 API Well Number 50-029-22220-00-00 Inspector Name: Chuck Scheve Permit Number: 191-125-0 Inspection Date: 11/13/2015 Insp Num: mitCS151115072228 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-01 Type Inj W TVD 6436 'Tubing 2633 - 2634 - 2632 - 2632 - PTD 1911250 - Type Test SPT Vest psi; 3000 IA 640 3400 - 3320• 3310 Interval REQVAR P/F P ', OA 240 500 - 500 - 500 - Notes: Tested per AIO 2B.068 SCANNED SEP 1 6 2016 Thursday,November 19,2015 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: n Other- Pages: DIGITAL DATA Diskettes, No. [] Other, No/Type OVERSIZED .El' Logs-of various kinds . Other COMMENTS: Scanned by: Beverly Dianna(~~than Lowell Date:~/¢ [] TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, December 13, 2011 TO: Jim Regg P.I. Supervisor C�(I (2-12 SUBJECT: Mechanical Integrity Tests r CONOCOPHILLIPS ALASKA INC 3Q -01 FROM: John Crisp KUPARUK RIV UNIT 3Q -01 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,_h NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3Q -01 API Well Number: 50- 029 - 22220 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr1 1 1 125084040 Permit Number: 191 -125 -0 Inspection Date: 11/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q -01 ' Type Inj. W TVD 6436 , IA 1374 3496 ' 3392 3378 ' P.T.D 1911250 ' TypeTest SPT Test psi 1609 . OA 600 830 830 830 Interval OTHER P/F P , Tubing 2872 2872 2872 2872 Notes: 4.1 bbls pumped for test. MITIA is in prep for upcoming AA. "' AM D FEB 1 6 2012 Tuesday, December 13, 2011 Page 1 of 1 ~ ~ COI'10C / ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder ~ Alaska Oil & Gas Commission 1~'~~- 333 West 7~' Avenue, Suite 100 ~ ~~~ Anchorage, AK 99501 ~ ~ ~ .., ~ ,E F s...+.. r ~, ._ „ ~ t :3 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. 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 July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, v~~~' ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ . ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field D1te 08/11/09 ~r± ~u ~v o ~n o.,,~ ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date VV( Corrosion inhibitor ~ PV Corrosion inhibitor/ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8l10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n!a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7130/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 MEMORANDUM To: Jim Regg 1r~y3 P.I. Supervisor 1 C~,C( 1 ~~ 1 w FROM: Bab Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October O1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-O1 KUPARUK RIV UNIT 3Q-Ol Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RN UNIT 3Q-O1 API Well Number 50-029-22220-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080927180055 Permit Number: 191-125-0 ~ Inspection Date: 9/25/2008 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j 3Q-ol Type Inj, W ~ 'rVD 6436 IA 1210 3000 2960 2960 p.T 191]250 TypeTest~SPT Test psi i 3000 , ~A 630 760 ~ 760 760 ~ Interval aYRTST p~ P ~ Tubing ~ z2oo zzoo ~ zzoo zzoo ~ Notes: ~ ,Y ~~;na Wednesday, October O 1, 2008 Page 1 of i MEMORANDUM State of Alaska TO: Jim Regg y P.I. Supervisor 'J.-...efl <ß1~{ù4- Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11,2004 SUBJECT: Mechanical IntegritY Tests CONOCOPHILLIPS ALASKA INC 3Q-OI KUPARUK RIV UNIT 3Q-OI FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::5ßr2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3Q-OI API Well Number: 50-029-22220-00-00 Inspector Name: John Crisp Insp Num: mitJCrO40810165302 Permit Number: 191-125-0 Inspection Date: 8/812004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-OI Type Inj. S TVD 6733 IA 600 2930 2880 2880 P.T. 1911250 TypeTest SPT Test psi 1609 OA 0 50 50 50 Interval 4YRTST P/F P Tubing 1400 1400 1400 1400 Notes: VVednesday,Augustl1,2004 Page I of 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P L M A T'E R THIS E E E W IA'L UNDER MARKER C:LORIkMFILM.DOC PERMIT DATA 91-125 CBT 91-12~ CDN 91-125 CDR 91-125 CET 91-125 407 91-125 91-125 DAILY WELL OP AOGCC individual Well Geological Materials Inventory 91-125 5165 T DATA_PLUS L 6395-7905 L 4548-8020, LWD L 4548-8020, LWD L 6395-7926 R COMP DATE:02/18/92 R 12/26/91-02/19/92 R o-8o o T 4548-8020, OH-CDR/CDN Are dry ditch samples required? yes ~nd received? Page- 1 Date: 01/18/94 SCALE DATE_RECVD 2&5 2&5 02/14/92 01/21/92 01/21/92 02/14/92 04/01/92 04/01/92 03/31/92 01/27/92 Was the well cored? yes~~-~description received? Are well tests required?.%~k/f~ ? ye~ Ii[itial Comments 1. Operations Performed: STATE OF ALASKA ~, :A OIL AND GAS CONSERVATION COMMI::... bN REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well ,5. Type of Well: Development ~ Exploratory Stratigraphic Service .~ ',~'e,~, 2. Name of Operator Other ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2199' FNL, 2377' FEL, SEC.17, T13N, R9E, UM At top of productive interval 1565' FSL, 1527' FWL, SEC.8, T13N, R9E, UM At effective depth 1638' FSL, 1500' FWL, SEC.8, T13N, R9E, UM At total depth 1700' FNL, 1476' FWL~ SEC.8, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 63' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-01 8020' feet Plugs (measured) 6733' feet 9. Permit number/approval number 91-125 / 92-290 10. APl number 50-029-::)222000 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7902' feet Junk (measured) true vertical 6 6 3 8' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' I 6" 1875~ POLESET 122' 122' Surface 4507' 9-5/8" 1100 SX PF E & 4548' 391 1' Intermediate 430 SX CLASS G Production 7 9 5 0' 7" 330 SX CLASS G 7 9 91 ' 6 7 0 9' Liner Perforation depth: measured 7770'-7825' 13. true vertical 6527'-6573' 3-1/2" 9.2# J-55 @ 7687' Packers and SSSV (type and measured depth) Baker HB Retr. @ 7658', Camco TRDP-4A Mod. @ 1812' Stimulation or cement squeeze summary CONVERTED FROM PRODUCING WELL TO WA~R INJECTION WELL Intervals treated (~neasured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1212 787 25 1022 0 0 342 Tubing Pressure 213 26O0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations _~_ 16. Status of well classification as: Water Injector _X .. Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title Petroleum Engineer SUBMIT IN DUPLICATE MORNING WELL REPORT INPuT FOR PRODUCTION DATE 02/17/93 PAGE ~***********'******' INdEcTiONWELL STATUS '**~**~****'**~*-***** ~*~ S/I'?'"~*'* S T · i A T U S I A1 C C IV IV ANP CNP D C S AP AP MR NO NOM Z LdR TdR TE HB EISR ISR'ED dLB dLM T C 0 LEEP UEEP EG OE VNIE TNIE TI EUB EUS I 0 N OCSS ACSS M KA ECNS ECNS EN CML CMC M D E WTSI LTSI PF EN NHGS NHGS RQ TES TEF E E ~860 24.87 57 60 ?00 ~ SWT A 2800 2656 " 175 56 104. 575 240 - ~ ~'- 1821 O SWI A ..2800 2635 57 104 500 150 .. 0 1791 8 SWI A 2800 2678 56 104 520 250 0 1263 ~2 SWI A ~800 2673 56 104 610 240 0 2961 [3 SWI A ~800 ~670 57 104 300 80 0 3589 ~5 S/I A ~800 180~ 04. 104 800 54.0 0 745 16 SWI A 2800 2663 56 104 430 50' 0 2266 0 **~ * 0 ~ ~ [OTALS' 0 5209.~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0 0 ..,0 . 0 0 0 , ~0 ....... 0 .... 0.000 0 0 0 0 0 0 0 0 0.000 (SWI' 19645 + PWI' O) = 1964.'5 0.0000 1330 55 · **~********** HEADERS ************** .~ROD H~O INd GAS INd * DRAIN * 'gAS LIFT ' 1-8" 9-i& 'LEVEL 3 P D P D P D P E S E S E S E S -~F I GF I GF I QF I 90 140 58 2650' 0 0 106 1440 ** METHANOL TANK P P S S F I I I T N 10 4. O0 · 320 1900 TEMP F PU D CL E TL QF 0 45 COMMENTS' 38-15 S/I FOR 36 HOUR S.P.F.O STARTED AT 10'30 2/17/93 FUNCTION KEYS HELP PRINT DISPLAY FWD/BACK' PAgE 1 PAQE FWD/BACK' OTHtER INdECTION WELLS (IF ANY> SHIFTS' 1) RETOTAL 2) UPDATE 3) PRINT D/S 4) REDO S/I, ETC. 5) NEW DS (DS# TOP) 6) PRINT S/S 7) S/S MULTIPRINT (CPF~ TOP) 8) D/S MULTIPRINT 9) WA~ t OR II ~AS 1. Operations Performed: Pull tubing 0 R 1 G IN A ~ OIL AND GAS ~RVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate X Plugging Perforate Alter casing Repair well Ot h · r ~ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic ._ Service 4. Location of well at surface 2199' FNL, 2377' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 1565' FSL, 1527' FWL, Sec. 8, T13N, R9E, UM At effective depth 1638' FSL, 1500' FWL, Sec. 8 , T13N, R9E, UM At total depth 1700' FNL~ 1476' FWLr Sec. 8~ T13N~ R9E~ UM 12. Present well condition summary Total Depth: measured 8 0 2 0' feet true vertical 6 733 feet Plugs (measured) 6. Datum elevation (DF or KB) 63' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-01 9. Permit number/approval number 91-125 10. APl number 50-029-2222000 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 9 0 2' feet true vertical 6 636' feet Junk (measured) Casing Length Size Structural 80' 1 6" Conductor 4 5 0 7 9-5/8" Surface Intermediate Production 7 9 5 0' 7" Uner Perforation depth: measured 7770'-7825' true vertical 6527'-6573' Tubing (size, grade, and measured depth) 3-1/2" 9.2# J-55 @ 7687' Packers and SSSV (type and measured depth) BAKER HP RETR PKR 13. Stimulation or cement squeeze summary W SAND FRACTURE TREATMENT Intervals treated (measured) 7770'-7825' 14. 1875 SX POLE SET 1100 SX PF E & 430 SX CLASS G 27O SX CLASS G Tubing Pressure Measured depth 122' 4548 7991' True vertical depth 122' 3911' 6709' RE( E VE CAMCO TRDP-4A MOD DEC 1 6 3992 Alaska 0il & Gas Cons. Anchorage Treatment description including volumes used and final pressure SEE ATTACHED WELL SERVICE REPORT SUMMARY Representative Daily Averaae Production or Iniection Dat~ _ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 910 160 1160 15O 201 69 1 2341 ~1510 48 16. Status of well classification as: Water Injector ~.. Oil X Gas ,,, Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. Form 10-404 Rev 09/12/90 Title Petroleum Engineer Oa. SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 07/31/92 TO 07/31/92 CPF-3 DS-3Q 3Q-0~ 07/31/92 FRACTURE TREATMENT WITH DS YF140D. PUMPED 150 BBL BREAKDOWN @ 25 BPM. LAST WHTP=4300 PSI, ISIP=1675 PSI, FG=0.695 PSI/FT, EXCESS FRICTION=611 PSI. PUMPED 67 BBL PAD WHEN ACTIVATOR PUMP PLUGGED. SD AND REPLACED W/STANDBY PUMP. RESET VOLUMES. PUMPED 250 BBL PAD~ PUMPED 7.7 MLBS 16/20 CARBOLITE IN 2 PPA STAGE & 114.1MLBS 12/18 CARBOLITE IN 4 TO 12 PPA STAGES. FLUSHED TO COMPLETION W/67 BBL XL GW, NON-XL GW AND DSL. TOT PROPPANT: DESIGNED 124.8 MLBS., IN FORMATION 121.8 MLBS W/12.0 PPA @ PERFS. TOT FLUIDS: WATER 943 BBL$, DIESEL 28 BBLS (FLA) a 17 BBLS (FLUSH). ALL FLUIDS LOOKED EXCELLENT. (SHULTZ/BEAL/WALKER) E ZE VED DEC 1 5 !99; Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. Post Office b..,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 10, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Application for Sundry Approvals on the following Kuparuk wells. Well Action Arltici.oated Start Date 3R-15 Conv. to Wtr. Inj. December 1992 3R-22 Conv. to Wtr. Inj. November 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering Attachments cc: V.L. Ferguson ~,TO-1370 (w/o attachments) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany REC£ V£D DEC 1 4 997- Alaska 0il & Gas Cons. Coram'~ss'~o~ Anchorage STATE Of ALASKA AI. Aor~ OIL AND G/~ CONSERVATION COMMI~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: AbandOn ~ .... Suspend__ Operation Shutdown __ Re-enter suspended well __ Alter casing_ Repair well _ Plugging_ Time extension _ Stimulate__ Change approved program X Pull tubing __ Variance _ Perforate __ Other .____ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service __ 4. Location of well at surface 2199' FNL, 2377' FEL, SEC. 17, T13N, RgE, UM At top of productive interval 1565' FSL, 1527' FWL, SEC. 8, T13N, R9E, UM At effective depth 1638' FSL, 1500' FWL, SEC. 8, T13N, R9E, UM At total depth 1700' FNL~ 1476' FWL~ SEC. 8~ T13N~ R9E~ UM 12. Present well condition summary Total Depth: measured 8 0 2 0' true vertical 6 73 3' feet Plugs (measured) feet None 6. Datum elevation (DF or KB) RKB 63 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-01 9. Permit number 91-125 10. APl number so-029-2222000 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7902' feet Junk (measured) 6 6 3 6' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 4507' Size 16" 9 5/8" 7950' 7" measured 7770'-7825' true vertical 6527'-6573 Cemented Measured depth True vertical depth 122' 122' 4548' 391 1' 7991 ' 6709' REEEIVED DEC 1 4 992 Alaska 0il & Gas Cons. 6ommtssto~' 1875# POLESET 1100 SX PF E & 430 SX CLASS G 330 SX CLASS G & Tubing (size, grade, and measured depth) 3-1/2" 9.2# J-55 @ 7687' Anchorage Packers and SSSV (type and measured depth) BAKER HP RETR PKR ~ 7658'~ CAMCO TRDP-4A MOD ~ 1812' 13. Attachments Description summary of proposal_ Detailed operation program _X BOP sketch CONVERT WEll FROM OIL PRODUCER TO WATER INJECTOR. (WELLBORE SCHEMATIC ATTACHED). 14. Estimated date for commencing operation ~ 15. Status of well classification as: DECEMBER. 1992 J Oil _L, Gas ~ Suspended ~ 16. If proposal was verbally approved Name of approver Date approved Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test ~ Subsequent form require 10-y.~./ Approved by order of the Commission Form 10-403 Rev 09/12/90 IApprovaJ. No. David W. johnston Commissioner Date SUBMIT IN TRIPLICATE Well 3Q-01 Conversion to Water Injection ARCO Alaska requests approval to convert Well 3Q-01 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 7699' and 7848'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. REEEIVED DEC 1 4 199~. A~aska Oil & Gas Cons. Anchorage KUPARUK WELL 3Q-01 APl #: 500292222000 SPUD DATE: 12/28/91 ORIGINAL RKB: ADL LEASE: 25512 COMPLETION DATE: 02/18/92 PERMIT #: 91-125 WORKOVER DATE: 07/14/92 SURFACE LOCATION: 2199'FNL,2377'FEL, SEC17,T13N,R9E TOP OF KUPARUK: 1495'FSL,1555'FWL,SEC8,T13N,R9E TD LOCATION: 1683'FSL,1487'FWL,SEC8,T13N,R9E All depths are MD-RKB to top of equipment unless otherwise noted 63 PAD ELEVATION: CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5# H-40 121 9.625" 36# L-80 4548 7" 26# J-55 7990 3.5" 9.2# J-55 ABA 7687 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING SPOOL: 38 WELLTYPE: PRODUCER TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-4A MOD 2.812" 1812 SBR BAKER PBR 3" & 4" SEALS7644 PKR BAKER HB 2.890" 7658 NOGO CAMCO D'NIPPLE 2.75" 7675 SHROUT BAKER 7686 MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 400 MAX HOLE ANGLE: 38 deg 2300 HOLE ANGLETHRU KUP: 35 deg LAST TAG DATE: 05/04/92 7889 RATHOLE: 64 ft FISH/OBSTRUCTION: PBTD: 7902 PBTDSS: 6575 22 GAS LIFT and FLOW INFORMATION VALVE STN DEPTH 1 3049 2 5053 3 6221 4 6792 5 7172 6 7592 PORT MANDREL SIZE SIZE MACCO 'SPM-1A' 1" .DV MACCO 'SPM-1A' 1" .DV MACCO 'SPM-1A' 1" .DV MACCO 'SPM-1A' 1" .DV MACCO 'SPM-1A' 1" .DV CAMCO 'MMG-2' 1.5' .DV INTERVAL 7770-7778 7778-7783 7783-7825 PERFORATION DATA ZONE FT SPF PHASE COMMENTS C4 8 4 180 4.5" BIG HOLE A2. 5 4 180 4.5" BIG HOLE A1 42 4 180 4.5" BIG HOLE RE(EIVED DEO 1 4 t992 Alaska 0il & Gas Cons, Commission' Anchorage REVISION DATE: 07/15/92 REASON: WORKOVER STATE OFALASKA 0 ~ I 6 IN ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing x Alter casing Stimulate Repair well Plugging __ Perforate _ Other Pull 3-1/2" tbg/Re-run 3-1/2" 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratig raphic Service 4. Location of well at surface 2199' FNL,2377' FEL, SEC 17, T13N, R9E, UM At top of productive interval 1565' FSL, 1527' FWL, SEC 8 , T13N, R9E, UM At effective depth 1638' FSL, 1500' FWL, SEC 8, T13N, RgE, UM At total depth 1700' FSL, 1476' FWL, SEC 8 T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8020' feet Plugs (measured) 6733' feet 6. Datum elevation (DF or KB) RKB 63', PAD 22' 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-01 9. Permit number/approval number 91-125 /Conserv Order lO. APl number 50-029-22220 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7902' 'feet Junk (measured) true vertical 6636' feet Casing Length Size Cemented Structural 80' 1 6" 1875 SX POLE SET Conductor Surface 4507' 9-5/8" 1100 SX PF E Intermediate & 430 SX CLASS G Production 7950' 7" 270 SX CLASS G Measured depth 122' 4548' 7991 ' True vertical depth 122 3911' 6709' Liner Perforation depth: measured 7770'-7825' MD true vertical 6527'-6573' TVD Tubing (size, grade, and measured depth) 3-1/2"9.3# J-55 @ 7687' Packers and SSSV (type and measured depth) BAKER HB RETR PKR @ 7658',CAMCO TRDP-4A SSSV @ 1813' MD RECEIVED #261_ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure A!aska 0it & Gas O0ilS. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 R~v 05/17/8~ Title Area Drilling Engineer Date SUBMIT IR DUPLICATE DAILY OPERATIONI PAGE: 1 ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3Q-01 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-029-22220 91-125 ACCEPT: 07/12/92 SPUD: RELEASE: 07/15/92 08:07 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 07/12/92 (17) TD: 8020 PB: 7902 MOVING RIG "@ 7990' MW:10.2 NaCl/Br INSTALL KILL AND CHOKE LINES. MOVE RIG OVER WELL. RU LUBRICAATOR, CAN'T PULL VR PLUG. PULL BPV. RU PUMP LINES TO PROD FLOWLINE. FILL PITS WITH SEA WATER. PULL VR PLUG. RU CIRC LINES. PRESS UP AND OPEN SSSV. BLEED GAS HEAD OFF ANNULUS. FLUSH CSG PERFS W/ SEAWATER. CIRC BRINE TO SURF. BLEED OFF, WELL DEAD. PUMP DIESEL DOWN FLOWLINE. SET BPV. ND WKM TREE. NU 7-1/16 BOPE. PULL BPV. SET TEST 07/13/92 (18) TD: 8020 PB: 7902 07/14/92 (19) TD: 8020 PB: 7902 07/15/92 (20) TD: 8020 PB: 7902 CBU "@ 7990' MW:10.2 NaCl/Br NU FLOW RISER. CHANGE TO 3.5" RAMS. TEST BOPE, OK. MU LJ. LD HANGER. MU HEAD PIN. CBU. POH. RU TO TUN DP. SET WEAR BUSHING. MU FTA #1. RIH PU DC AND DP. TAG PKR AT 7707. SET DOWN AND LATCH PACKER. WORK FREE AND PU 1 SINGLE. CBU. POH-LDDP "@ 7990' MW:10.2 NaCl/Br CIRCULATE BOTTOMS UP 3.5 BPM, 1000 PSI. POH W/ PACKER INTERMITENT DRAG. RECOVERED ALL OF PBR/HRP-i-SP PACKER AND TAIL PIPE. RECOVERED +-5 SS BANDS (+-6 STILL MISSING). TWO BOTTOM "SLIP KEEPERS" GONE OFF PACKER FROM OPPOSITE SIDES OF BODY (OUT OF 4). MU 6 1/8" BIT 1RR. RIH 115 STDS AND PU 8 SINGLES TO 7875' (7890 PACKER RKB). NO BUMPS ON RIH. CIRCULATE BOTTOMS UP. 3 BPM, 650 PSI. REVERSE 1 DP VOLUME, 3 BPM, 800 PSI. POH LD 15 JTS. SLIP AND CUT 50' OF DRILLING LINE. POH-LDDP. RIG RELEASE "@ 7990' MW:10.2 NaC1/Br CONTINUE TO POH AND LDDP. M/U TAIL PIPE W/ 505, 10' PUP, BAKER HB PKR & PBR, ECT. AS REQUIRED. (TESTED C-LINE TO 5000 PSI) M/U WKM GEN4 TBG HANGER AND TESTED TO 5000 PSI. LANDED HANGER, PRESSURED TUBING TO 2500 PSI, PACKER SET @ 900 PSI, BLED OFF PRESSURE, BOLDS, PRESSURED TUBING TO 1000 PSI, SHEARED OUT PBR W/ ll0K, STRING WT=66K. RELANDED TUBING, RILDS, PRESSURED TUBING TO 1000 PSI, CLOSED SSSV & TESTED. TESTED ANNULUS TO 2500 PSI. PRESSURED UP AND SHEARED SOS @ 3700 PSI. SET BPV, N/D STACK, NU X-MAS TREE. PULLED BPV, SET TEST PLUG, TESTED PACKOFF TO 5000 PSI, TESTED TREE TO 250 PSI & 5000 PSI, PULLED TEST PLUG, OPENED SSSV @1900 HRS, SITP= 0 PSI, SI 7" =0 PSI, SI 9 5/8":200 PSI, CONNECTED HARD LINE. P/U PIT LINER & CLEANED UP AROUND CELLAR. RIG RELEASE @ 2030 HRS 7-15-92. MOVE TO 3R-18 NEXT. SIGNATURE: DATE: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [-~ GAS [~] SUSPENDED [] ABANDONED [~] SERVICE ~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-125 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22220 4 Location of well at surface 9 Unit or Lease Name 2199' FNL, 2377' FEL, SEC 17, T13N, R9E, UM !~ ~;~ ~'~:~ ~¥ ~i~;"~ .................... KUPARUK RIVER At Top Producing Interval ~ ~i~.~ ~ ~ ~ i/~?~'~0~1~ 10 Well Nurrber 1565' FSL, 1527' FWL, SEC 8, T13N, R9E, UM ~ -~;;;~{-".~-~;~ ~ ~ 3Q-01 1700' FSL 1476' FWL, SEC 8, T 13N, R9E, UM .......... ~.~ ~ ~:'' !-!.~_..~..E~ KUPARUK RIVER FIELD Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 63', PAD 22' GL ADL 373301, ALK 4162 12 Date Spudded 12/28/91. 13 Date T.D. Reached 01/04/92. 14 Date Comp. , Susp. or Aband. 02/18/92. I15 Water Depth' it offshOre NA feet MSL ]16 NO, of Completions 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 8020' MD, 6733' 'I'VD 7902' MD, 6636' TVD YES [~] NO O 1876' fee~ MD 1700' APPROX 22 Type Electric or Other Logs Run CDR/CDN/GR/CET/CBT/GCT 23 CASING, MNER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5# H-40 SURF 122' 24' 1875 SX POLE SET(foam b/pa) 1986 conductor 9-5/8" 36# J-55 SURF 4548' 12-1/4' 1100 sx PF E, 430 SX CLASS G 7" 26# J-55 SURF 7991' 8' 270 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 (MDI PACKER SET/MD) 3-1/2' 9.3# 7739' 7717' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7770'-7825' W/ 4-1/2' CSG GUN @ 4 SPF MD 6527'-6573' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Operatio~ (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 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (con') Press. 24-HOUR RATE 28 CORE DATA ~=~ ~i~ ~ r I ~, J~ ~ Brief description of lithoiogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit eom chips. K ~ ~ r.. t v ~ Alaska 0ii & G~s cons. C0mmt~o,0° Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GECL~ ~ FORMATION TESTS , , NAME Include interval tested, pressure dala, all fluids reco, verd and gray#y, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. NA KUPARUK C TOP 7766' 6524' KUPARUK C BO'I-rOM 7778' 6534' KUPARUK A TOP 7778' 6534' KUPARUK A BOTTOM 7848' 6591' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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: 3Q-01 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 373301 ALK 4162 50-029-22220 91-125 ACCEPT: 12/25/91 SPUD: 12/28/91 RELEASE: 01/06/92 OPERATION: DRILLING RIG: PARKER 245 AFE: AK6209 WI: 55.252072 12/26/91 ( 1) TD: 0'( SUPV:CTD o) 12/27/91 ( 2) TD: 122'( 122) SUPV:CTD o) 12/28/91 ( 3) TD: 122'( SUPV:CTD 12/29/91 ( 4) TD: 1700'(1578) SUPV:CTD 12/30/91 ( 5) TD: 3265'(1565) SUPV:CTD 12/31/91 ( 6) TD: 4568'(1303) SUPV:CTD o) 01/01/92 (7) TD: 4548'( SUPV:JRR o) 01/02/92 ( 8) TD: 4548'( SUPV:JRR WORK ON DP MACHINE 7"~ 7990' MW: 8.5 VIS: 86 ACCEPT RIG ON 12/25/91 AT 1800 HRS. FUNCTION TEST DIVERTER. SAFETY MTG WITH BOTH CREWS AND ALL SERVICE PERSONNEL. PU 6 STNDS DP. WORK ON PIPE HANDLING MACHINE. DAILY:S34,538 CUM:$34,538 ETD:SO EFC:$1,354,538 REPAIR DIVERTER VALVE 7"~ 7990' MW: 0.0 VIS: 0 REPAIR DP SLIDE MACHINE. CONTINUE TO PU HWDP. PU AND MU BHA. FUNCTION TEST DIVERTER. DIVERTER VALVE LEAKING. WORK ON DIVERTER (21.5 HRS DOWNTIME). DAILY:S61,521 CUM:$96,059 ETD:SO EFC:$1,416,059 DRILLING ICE F/CONDUCTOR 7"~ 7990' MW: 9.0 VIS: 90 CONTINUE WORKING ON DIVERTER. INSTALLED NEW VALVE AND FUNCTION TESTED OK. RIH AND DRILL ICE FROM CONDUCTER FROM 48' TO 95' DAILY:$67,~95 CUM:$163,954 ETD:SO EFC:$1,483,954 DRILLING 7'~ 7990' MW: 9.0 VIS: 62 DRILL ICE FROM CONDUCTOR FROM 95' TO 122' DRILL NEW HOLE TO 219'. POOH AND PU AND MU MUD MOTOR. DRILL FROM 219' TO 1117'. REPAIR TOP DRIVE_ DRILL FROM 1117' TO 1210'. POOH 3 STNDS AND REAM OUT 6 DEGREE DOG LEG.DRILL FROM 1210' TO 1700'. '~ DAILY $56,517 CUM:$220,471 ETD:SO EFC:$1,540,471 REPAIR SCR 7"~ 7990' MW: 9.2 VIS: 46 DRILL FROM 1700' TO 2710'. SERVICE RIG. DRILL FROM 2710' TO 3265'. POOH TO REPAIR SCR UNIT. DAILY:S59,005 CUM:$279,476 ETD:SO EFC:$1,599,476 SHORT TRIP 7"~ 7990' MW: 9.3 VIS: 51 CONT WORK ON SCR. TIH. WASH THRU BRIDGE AT 1900' DRLD 3265'-4568' CSG PT. CIRC. SHORT TRIP. DAILY:S69,682 CUM:$349,158 ETD:SO EFC:$1,669,158 CIRC POH. RAN 9-5/8" CSG. CIRC. 7990' MW: 9.2 VIS: 42 DAILY:S142,210 CUM:$491,368 ETD:SO EFC:$1,811,368 TEST BOPE 7"~ 7990' MW: 0.0 VIS: 0 CMTD 9-5/8" CSG. ND DIVERTER. INSTALL CSG HEAD. NU BOP. DAILY:S128,736 CUM:$620,104 ETD:SO EFC:$1,940,104 RECEJVED APR - 1 11992 Alaska Oil & Gas Cons. C;ommissio~ Anchorage WELL: 3Q- 01 OPERATION: DRILLING RIG: PARKER 245 PAGE: 2 01/03/92 ( 9) TD: 4496'( SUPV:JRR o) 01/04/92 (10) TD: 6791'(2295) SUPV:JRR 01/05/92 (11) TD: 8020'(1229) SUPV:JRR 01/06/92 (12) TD: 8020'( SUPV:JRR o) 01/07/92 (13) TD: 8020'( SUPV:JRR o) DRLG FLT EQPT AND CMT 7"~ 7990' MW: 8.6 VIS: 32 NU BOPE AND TEST (WITNESSED BY STATE). WORK ON TOP DRIVE. PU BHA AND RIH. DRILL CMT AND FLOAT EQUIPMENT. DAILY:S56,219 CUM:$676,323 ETD:SO EFC:$1,996,323 DRILLING 7'~ 7990' MW: 9.1 VIS: 35 DRILL FLOAT EQPT AND PERFORM LOT. DRILL FROM 4583' TO 4783' PULL UP TO SHOE TO WORK ON SCR. DRILL FROM 4783' TO 6791' DAILY:S82,723 CUM:$759,046 ETD:SO EFC:$2,079,046 TOH FOR CSG 7'~ 7990' MW:10.5 VIS: 36 DRILL FROM 6791' TO 7500'. SHORT TRIP 15 STNDS. DRILL FROM 7500' TO 8020'. CBU. SHORT TRIP 10 STNDS. CBU, SPOT DIESEL PILL AND TRIP OUT OF HOLE. DAILY:S77,171 CUM:$836,217 ETD:SO EFC:$2,156,217 CMT 7" CSG 7'~ 7990' MW:10.4 VIS: 42 TOH AND LD BHA. RUN 7' CASING. CEMENT 7" CASING. DAILY:S129,719 CUM:$965,936 ETD:SO EFC:$2,285,936 RIG RELEASED 7'~ 7990' MW: 0.0 VIS: 0 ND BOPE AND NU TREE. INJECT 70 BBLS DOWN ANNULUS FOR FREEZE PROTECTION. RELEASE RIG. DAILY:S145,377 CUM:$1,111,313 ETD:SO EFC:$2,431,313 SIGNATURE: ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 3Q-01 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 373301 ALK 4162 50-029-22220 91-125 ACCEPT: 02/16/92 SPUD: RELEASE: 02/18/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK6209 02/17/92 (14) TD: 8020 PB: 7902 SUPV:GB/SB RIH W/3-1/2" SINGLE COMP 7"~ 7990' MW:ll.7 NaC1/Br MOVE RIG F/3Q-03 TO 3Q-01,ACCEPT RIG AT 0930 HRS 2/16/92,ND TREE, NU BOPE,TEST SAME TO 3000 PSI,OK,RU SWS, PERF F/7770-7825',4 SPF, 180 DEG,ORIENTED,WELL FLOWING,GAINED 4 BBLS,MONITOR WELL,SI PRESS=iT5 PSI,RU FLOW RISER/FLOOR EQUIP BULLHEAD 150 BBLS 11.7 PPG BRINE DN CSG, INITIAL PUMP PRESS 1100 PSI,FINAL PUMP PRESS 950 PSI,SI PRESS=875 PSI BLEED PRESS, 10 BBLS RETURNED,WELL STILL FLOWING SLIGHTLY, RIH W/3-1/2" COMP AS PER PROC,AT 20 JTS IN, PUMP 12.0 PPG BRINE DN TBG CONT RIH/COMP,AFTER 20 ADDITIONAL JTS, PUMP 12 PPG BRINE,CONT RIH,TOTAL FLUID GAIN WHILE RUNNING COMP=2 BBLS PLUS DISPLACEMENT DAILY:S64,373 CUM:$1,175,686 ETD:SO EFC:$2,495,686 02/18/92 (15) TD: 8020 PB: 7902 SUPV:GB/SB CIRC 11.0 PPG BRINE 7"~ 7990' MW:ll.0 NaCl/Br SERVICE RIG,CONT RIH W/COMP, BOP DRILL,MONITOR WELL F/15 MIN NO FLOW, MU SSSV & C-LINE, TEST SAME TO 5K, OK,CONT RIH,MU HGR AND C-LINE,TEST SAME TO 5K, OK, LAND TBG, RILDS,SET PKR W/2500 PSI ON TBG, PRESS ANN TO 1000 PSI TO CHECK SEALS,BLEED PRESS BOLDS, PU TO SHEAR PBR, PBR ALREADY SHEARED, RELAND TBG, RILDS PRESS TEST SSSV W/500 PSI DIFF,OK, BLEED OFF PRESS,ATTEMPT TO PRESS ANN TO 2500 PSI,AT 1500 PSI HAD SUDDEN PRESS LOSS,ANN AND TBG COMMUNICATION, PRESS UP TBG TO SEE IF SOS SHEARED, SOS NOT SHEARED, RETEST SSSV, OK, PRESS TBG AND ANN TO 2500 PSI,OK PRESS TBG TO 3500~PSI TO SHEAR SOS,WILL NOT SHEAR, CALL OUT SLICKLINE,LD LAN~. JT, SET BPV, ND BOPE,NU TREE, PULL BPV, SET TEST PLUG, TEST TREE TO 250/5000 PSI,OK TEST 7" PACKOFF TO 5K OK, RU SLICKLINE,RIH AND PULL CV, DISPLACE ANN W/12 BBLS DIESEL, SI ANNULUS,RIH W/SLICKLINE AND SET DV, POH, PRESS TBG ANN PRESS UP W/TBG, RIH W/LIB,UNABLE TO SET DN ON GLM ~4 OR #5,POH,RIH W/STOP COLLAR TEST PLUG, SET BELOW 1-1/2"GLM (ABOVE PBR),TEST TBG TO 500 PSI,OK, POH W/SLICKLINE,ASSUME PKR SLID DNHOLE, SET BPV, ND TREE,NU BOPE, PULL BPV, SET TEST PLUG, TEST BOPE TO 3000# OK, PULL TEST PLUG, RIH AND TAG PKR W/TBG, PKR SLID DNHOLE 65',PKR AT 7740', UNLOAD AND CLEAN PITS,LOAD PITS W/100 BBLS 11.0 PPG BRINE, PUMP 11.0 PPG BRINE DN TBG TAKING RETURNS UP ANNULUS DAILY:S34,484 CUM:$1,210,170 ETD:SO EFC:$2,530,170 02/19/92 (16) TD: 8020 PB: 7902 SUPV:DB/TB SIGNATURE: RIG RELEASED 7~ 7990' MW:ll.0 NaCl/Br PULL HGR TO FLOOR, LD HGR & LDG JT, SPLICE CONTROL LINE,MU XO RIH W/3 JTS DP, STAB INTO PBR, PKR SLID DN HOLE 64' ,TEST TBG TO 2500 PSI,OK, TEST ANN TO 3K PSI, OK,REPEAT, OK,VERIFY PKR NOT MOVING DN HOLE FURTHER, POH W/DP,STRAP,DRIFT,TALLY ADDITIONAL TBG, SPACE OUT,MU HGR AND C-LINE,TEST SAME TO 5K PSI,OK,LAND HGR, RILDS,UP WT=65K,DN WT=42K, RAN 35 SS C-LINE BANDS, TEST TBG TO 2500 PSI, OK, TEST SSSV W/500 PSI DIFF,OK TEST ANN TO 2500 PSI,OK, PRESS TBG TO 4100 PSI AND SHEAR SOS LD LJ, CLOSE SSSV, SET BPV, ND BOPE,NU TREE,TEST PACKOFF TO 5K OK, TEST TREE TO 250/5000 PSI,OK, PULL TP,OPEN SSSV, RU OTIS SLICKLINE,TEST LUBR TO 500 PSI, RIH AND PULL DV FROM BTM GLM REV CIRC 12 BBL DIESEL DN ANN, RIH W/SLICKLINE AND SET DV IN GLM, BULLHEAD 4 BBLS DIESEL DN TBG, RD SLICKLINE, BLOWDN LINES CLEAN PITS, SECURE WELL,SITP=200,SICP=0,RELEASE RIG AT 2100 HRS 2/18/92,MOVE TO 2U-02 DAILY: $41,144 CUM:S1,251,314 ETD:SO EFC: $2,571,314 DATE:3/~7/~ ~ . SUB - SURFACE DIRECTIONAL SURVEY ~l UIDANCE ~l ONTINUOUS OOL Alaska Oil & 6as Cons. Commissio,', Company ARCO ALASKA, INC. Well Name 3Q-l(2199'FNL,2377'FEL,SEC 17,T13N,R9E) Field/Location KUPARUK RIVER, NORTH SLOPE, ALASKA m Job Reference No. 92112 Logged By: T. WEST Date 31-JAN-1992 Computed By; R. KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3Q - KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 31-JAN-1992 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. ENGINEER: T. WEST Averaged Oeviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF NORTH 2O DEG 3 MIN WEST COMPUTATION DATE: 22-MAR-92 PAGE 1 ARCO ALASKA, INC. 3Q - 1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED 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 0 O0 100 O0 20O O0 300 O0 4OO O0 500 O0 600 O0 70O.0O 800.00 900.00 0.00 99.98 199.98 299.97 399.92 499.62 598.80 697.1-4 794.01 888.99 -63 O0 0 0 36 98 0 30 136 98 0 44 236 97 1 10 336 92 2 38 436 62 5 59 535 80 8 35 634 14 11 52 731 01 17 5 82599 19 9 N 0 0 E N 33 19 W N 43 34 W N 29 35 W N 14 23 W N 15 4 W N 13 36 W N 12 50 W N 13 26 W N 15 3 W 0.00 0.42 t 34 2 74 5 86 13 35 25 97 43 88 68 35 99.49 0 O0 0 66 0 58 1 12 2 35 2 9z~ 3 25 3 15 3 52 2 25 0.00 N 0.39 N 1.11 N 2.27 N 5.19 N 12,55 N 24.85 N 42.42 lq 66.42 N 96.75 N 0.00 E 0.00 N 0 0 E 0.16 W 0.42 N 21 51 W 0.87 W 1.41 N 37 58 W 1 80 w 2.89 N 38 26 W 2 86 W 5.93 N 28 53 W 4 55 W 13.35 N 19 56 W 7 66 W 26.01 N 17 8 W 11 76 W 44.02 N 15 30 W 17 37 W 68.65 N lz; 39 W 25 09 W 99.95 N 14 32 W 1000.00 982.03 919.03 24 18 1100.00 1071.00 1008.00 29 23 1200.00 1157.53 1094.53 30 24 1300.00 1243.96 1180.96 29 51 1400.00 1331.24 1268.24 28 40 1500.00 1418.75 1355.75 29 25 1600.00 1505.14 1442.14 31 15 1700.00 1589.58 1526.58 33 25 1800.00 1672.13 1609.13 34 58 1900,00 1753.99 1690.99 35 2 N 18 54 W 135.94 N 22 40 W 181.50 N 22 58 W 231.56 N 22 2 W 281.80 N 20 54 W 330.59 N 19 29 W 378.98 N 17 57 W 429.32 N 17 7 W 482.83 N 17 36 W 539.20 N 16 33 W 596.57 6 7O 2 67 0 5O 1 12 0 66 1 77 2 75 2 17 0 74 0 76 131.70 N 35.65 W 136.44 N 15 9 W 174.22 N 52.03 W 181.82 N 16 38 W 220.38 N 71.57 W 231.71 N 17 59 W 266.82 N 90.85 W 281.86 N 18 48 W 312.25 N 108.70 W 330.63 N 19 12 W 357.63 N 125.50 W 379.01 N 19 20 W 405.34 N 141.61 W 429,37 N 19 15 W 456.45 N 157.62 W 482.90 N 19 3 W 510.30 N 174.50 W 539.31 N 18 53 W 565.16 N 191.51 W 596.73 N 18 43 W 2000.00 1835.75 1772 75 35 20 2100.00 1916,53 1853 53 37 11 2200.00 1995.55 1932 55 38 3 2300.00 2074.18 2011 18 38 2400.00 2152,94 2089 94 37 31 2500.00 2233,63 2170 63 35 33 2600,00 2315.00 2252 O0 35 34 2700.00 2396.25 2333.25 35 42 2800.00 2477.44 2414.44 35 46 2900.00 2558.61 2495.61 35 41 N 15 24 W 653.99 N 18 53 W 712.80 N 20 2 W 774.08 N 19 5 W 835.86 N 19 8 W 897.46 N 22 34 W 956.50 N 22 2 W 1014.58 N 21 25 W 1072.85 N 21 0 W 1131.22 N 20 7 W 1189.63 0 80 4 42 0 78 0 70 3 47 0 28 0 43 0 4O 0 33 0 55 620.55 N 207 26 W 654 24 N 18 28 W 677.02 h 224 734.62 N 244 792.83 N 265 851.17 N 285 906.21N 306 959.97 N 328 1014.14 N 350 1068.57 N 371 1123.24 N 392 03 W 713 98 W 774 66 W 836 50 W 897 89 W 956 99 W 1014 54 W 1073 65 W 1131 22 W 1189 13 N 18 19 W 39 N 18 27 W 16 N 18 31W 77 N 18 33 W 76 N 18 43 W 78 N 18 55 W 01 N 19 4 W 35 N 19 11W 74 N 19 15 W 3000,00 2639.59 2576.59 36 10 3100.00 2720.25 2657.25 36 11 3200.00 2801.33 2738 33 35 25 3300.00 2883.26 2820 26 34 49 3400.00 2965.60 2902 60 34 27 3500,00 3048.70 2985 70 33 22 3600.00 3131.95 3068 95 33 48 3700.00 3215.25 3152 25 33 32 3800.00 3298.50 3235 50 33 57 3900.00 3380.81 3317 81 35 11 N 19 34 W 1248.29 N 18 55 W 1307.39 N 17 50 W 1365.91 N 17 59 W 1423.19 N 19 37 W 1479.92 N 18 58 W 1535.54 N 19 1 W 1590.94 N 18 17 W 1646.25 N 18 30 W 1701.61 N 22 14 W 1758.39 0.45 0.86 1.18 1 .21 0.54 0.69 0.44 0.32 1 .26 1 .32 1178.44 N 412.06 W 1248.40 N 19 16 W 1234.22 N 431.59 W 1307.51 N 19 16 W 1289.79 N 450.04 W 1366.05 N 19 14 W 1344.41 N 467.47 W 1423,36 N 19 10 W 1398.04 N 485.98 W 1480.09 N 19 10 W 1450,53 N 504.37 W 1535.72 N 19 10 W 1502.92 N 522,42 W 1591.13 N 19 10 W 1555.37 N 540.02 W 1646.45 N 19 9 W 1607.97 N 557.40 W 1701,84 N 19 7 W 1661.19 N 577,16 W 1758.60 N 19 10 W COMPUTATION DATE: 22-MAR-92 PAGE 2 ARCO ALASKA, INC. 30 - 1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORD[NATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N FEET DEG/IO0 FEET FEET FEET DEG 4000 O0 3462.25 3399.25 35 39 N 22 9 W 1816 37 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3543,43 3480,43 35 43 N 21 4 W 1874 O0 3624,76 3561,76 35 25 N 20 19 W 1932 O0 3706,81 3643,8t 34 19 N 20 1 W 1990 O0 3789.40 3726,40 34 47 N 20 36 W 2046 O0 3871.28 3808,28 34 54 N 20 49 W 2103 O0 3953.66 3890,66 34 18 N 21 59 W 2160 O0 4036,09 3973,09 34 42 N 22 52 W 2217 O0 4118,07 4055.07 35 17 N 23 45 W 2274 O0 4199,27 4136,27 35 50 N 24 4 ~ 2332 74 92 O8 47 87 54 10 27 50 0 51 1714 87 N 599 20 W 18!6.54 N 19 16 W 1 08 1769 0 67 1823 0 81 1877 1 78 1930 0 42 1983 0 85 2036 0.68 2089 1,34 2141 0.20 2194 14 N 620 60 N 641 27 N 660 19 N 680 86 N 700 69 N 721 02 N 742 60 N 765 96 N 789 76 W 1874,88 N 19 20 W 24 W 1933,06 N 19 22 W 91 W 1990,21 N 19 24 W 37 W 2046,59 N 19 25 W 75 W 2103.98 N 19 27 W 28 W 2160.6~ N 19 30 W 89 W 2217.18 N 19 35 W 56 W 2274,32 N 19 40 W 20 W 2332.53 N 19 47 W 5000.00 4280.38 4217.38 35 49 N 24 13 W 2390.84 5100,00 4361,40 4298.40 36 4 N 23 32 W 2449,32 5200,00 4442,20 4379,20 36 8 N 22 56 W 2508,16 5300,00 4522,92 4459,92 36 tt N 23 41 W 2567,09 5400 O0 4603,53 4540,53 36 25 N 22 53 W 2626,16 5500 O0 4683,89 4620,89 36 39 N 22 34 W 2685,62 5600 O0 4764,11 4701,11 36 39 N 22 40 W 2745,28 5700 O0 4844,58 4781,58 36 10 N 19 49 W 2804,61 5800 O0 4925,23 4862,23 36 17 N 19 21 W 2863,72 5900 O0 5005,86 4942,86 36 17 N 19 33 W 2922,87 0.23 2248,32 N 813.14 W 2390,85 N 19 53 W 1 27 2301,87 N 837,00 W 2449,33 N 19 59 W 0 53 2356,11 N 860,03 W 2508,16 N 20 3 W 0 33 2410,33 N 883,34 W 2567,10 N 20 8 W 1 15 2464,59 N 906,96 W 2626,17 N 20 12 W 0 30 2519,55 N 929,79 W 2685,64 N 20 15 W 0 15 2574,67 N 952,77 W 2745,30 N 20 18 W 1 72 2629,85 N 974,63 W 2~04,65 N 20 20 W 0 01 2685,61 N 994,27 W 2863,75 N 20 19 W 0,21 2741,38 N 1013,97 W 2922,89 N 20 18 W 6000,00 5086.72 5023.72 35 48 N 17 48 W 2981 69 6100.00 5167,85 5104.85 35 44 N 17 47 W 3040 10 6200,00 5249,14 5186.14 35 33 N 17 56 W 3098 31 6300,00 5330.54 5267.54 35 28 N 18 22 W 3156 36 6400,00 5411.98 5348,98 35 35 N 18 51 W .3214 37 6500,00 5493,29 5430,29 35' 29 N 19 1 W 3272 57 6600.00 5574,86 5511,86 35 16 N 19 6 W 3330 41 6700,00 5656,64 5593,64 34 58 N 19 42 W 3387 95 6800,00 5738,49 5675,49 35 17 N 19 42 W 3445.41 6900,00 5820,06 5757,06 35 22 N 19 54 W 3503,24 0,33 2797,11 N 1032.83 W 2981.71 N 20 16 W 0,43 2852,80 N 1050,64 W 3040,11 N 20 13 W 0.37 2908,24 N 1068,50 W 3098,32 N 20 10 W 0.30 2963,44 N 1086,58 W 3156,36 N 20 8 W 0,27 3018.44 N 1105.10 W 3214 38 N 20 7 W 0,86 3073,51 N 1123,95 W 3272 57 N 20 5 W 0.42 3128.22 N 1142.76 W 3330 41 N 20 4 W 0.14 3182.49 N 1161.87 W 3387 95 N 20 3 W 0,27 3236,55 N 1181,33 W 3445 41 N 20 3 W 0,41 3291,00 N 1200,84 W 3503 24 N 20 3 W 7000,00 5901,67 5838,67 35 10 N 20 17 W 3561,03 7100.00 5983,09 5920,09 36 4 N 19 12 W 3619 10 7200.00 6063.85 6000.85 36 6 N 19 20 W 3678 7300.00 6144.78 6081.78 35 51 N 20 5 W 3736 7400.00 6226.00 6163.00 35 26 N 20 26 W 3795 7500.00 6307.48 6244.48 35 42 N 21 11 W 3853 7600.00 6388.63 6325.63 35 41 N 21 6 W 3911 7700.00 6469.99 6406.99 35 16 N 20 42 W 3969 7800.00 6551.89 6488.89 34 56 N 20 58 W 4027 7900,00 6634,02 6571,02 34 45 N 20 53 W 4084 06 80 13 09 52 66 04 09 0.62 3345.28 N 1220.69 W 3561.03 N 20 3 W 1.24 3399.85 N 1240.52 W 3619.10 N 20 3 W 0.32 3455.57 N 1259.83 W 3678.06 N 20 2 W 0 25 3510.88 N 1279.62 W 3736.80 N 20 2 W 0 70 3565.62 N 1299 77 W 3795.13 N 20 2 W 0 71 3619.79 N 1320 39 W 3853.09 N 20 2 W 0 31 3674,28 N 1341 50 W 3911.52 N 20 3 W 0 85 3728,62 N 1362 19 W 3969,66 N 20 4 W 0 24 3782,27 N 1382 57 W 4027.04 N 20 5 W 0 O0 3835,54 N 1403 01 W 4084,09 N 20 6 W COMPUTATION DATE: 22-MAR-92 PAGE 3 ARCO ALASKA, ~'NC. 3Q- 1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 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 8000.00 6716.18 6653.18 34 45 N 20 53 W 4141.09 8020.00 6732.61 6669.61 34 45 N 20 53 W 4152.49 0.00 3888.80 N 1423.31 W 4141.09 N 20 6 W 0.00 3899.46 N 1427.37 W 4152.49 N 20 6 W COMPUTATION DATE: 22-MAR-92 PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 31-JAN-1992 3Q - 1 KELLY BUSHING ELEVATION: 63.00 FT KUPARUK RIVER NORTH SLOPE, ALASKA ENGINEER: T. WEST 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 0.00 0.00 -63.00 0 0 N 0 0 E 0.00 1000.00 982.03 919 03 24 18 N 18 54 W 135.94 2000.00 1835.75 1772 75 35 20 N 15 24 W 653 99 3000.00 2639.59 2576 59 36 10 N 19 34 W 1248 29 4000.00 3462.25 3399 25 35 39 N 22 9 W 1816 37 5000.00 4280.38 4217 38 35 49 N 24 13 W 2390 84 6000.00 5086.72 5023 72 35 48 N 17 48 W 2981 69 7000.00 5901.67 5838 67 35 10 N 20 17 W 3561 03 8000.00 6716,18 6653 18 34 45 N 20 53 W 4141.09 8020.00 6732.61 6669.61 34 45 N 20 53 W 4152.49 0.00 0.00 N 0 O0 E 0.00 N 0 0 E 6.70 131.70 N 35 65 W 136.44 N 15 9 W 0.80 620.55 N 207 26 W 654.24 N 18 28 W 0.45 1178.44 N 412 06 W 1248.40 N 19 16 W 0.51 1714.87 N 599 20 W 1816.54 N 19 16 W 0.23 2248.32 N 813 14 W 2390.85 N 19 53 W 0.33 2797.11 N 1032.83 W 2981.71 N 20 16 W 0.62 3345,28 N 1220.69 W 3561.03 N 20 3 W 0.00 3888.80 N 1423.31 W 4141.09 N 20 6 W 0.00 3899.46 N 1427.37 W 4152.49 N 20 6 W ARCO ALASKA, INC. 3Q - 1 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 22-MAR-92 PAGE 5 DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63,00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA 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 0,00 63,01 63,00 0 163.02 163,00 100 263.03 263 O0 200 363.05 363 O0 300 463.22 463 O0 400 563.84 563 O0 500 665,16 663 O0 600 767.68 763 O0 700 872,53 863 0.00 -63 O0 0 0 N 0 0 E O0 0 18 N 17 50 W O0 0 36 N 46 44 W O0 0 49 N 39 43 W O0 1 53 N 18 54 W O0 4 49 N 12 16 W O0 7 36 N 13 52 W O0 11 2 N 13 I W O0 15 20 N 13 12 W O0 800,00 18 41 N 14 43 W 0,00 0,00 0.00 N O, 15 0,91 O, 15 N 0.97 0,00 0,82 N 2, 13 0,59 1,74 N 4,42 1,48 3.81 N 9,90 3,93 9,18. N 20,92 2.20 19,91 N 37,02 2,64 59,34 7,83 90,63 1,51 979,20 963,00 900,00 22 58 N 17 51 W 127.56 1090,83 1063,00 1000,00 29 8 N 22 30 W 177.02 1206,35 1163,00 1100,00 30 24 N 22 57 W 234,77 1321,92 1263,00 1200,00 29 36 N 21 46 W 292,67 1436,21 1363,00 1300,00 28 46 N 20 35 W 347,99 1551,00 1463,00 1400,00 30 13 N 18 37 W 404,33 1668,28 1563,00 1500,00 32 47 N 17 13 W 465.53 1788,86 1663,00 1600,00 34 53 N 17 36 W 532,82 1911,01 1763,00 1700,00 35 3 N 16 23 W 602,88 2033,47 1863,00 1800,00 35 42 N 15 34 W 673,37 2158,69 1963,00 1900.00 37 57 N 20 19 W 748,65 2285,77 2063,00 2000,00 38 11 N 19 14 W 827 07 2412,65 2163,00 2100,00 37 7 N 19 41 W 905 13 2536,10 2263,00 2200,00 35 32 N 22 27 W 977 46 2659,05 2363.00 2300.00 35 43 N 21 38 W 1048 96 2782,21 2463,00 2400.00 35 45 N 21 5 W t120 83 2905,41 2563,00 2500,00 35 42 N 20 4 W 1192 79 3029,01 2663,00 2600,00 36 15 N 19 28 W 1265 42 3152,85 2763,00 2700,00 35 50 N 18 20 W 1338,45 3275,33 2863,00 2800,00 34 50 N 17 41 W 1409,11 3396.85 2963.00 2900 O0 34 29 N 19 37 W 1478.14 3517,14 3063,00 3000 3637,32 3163,00 3100 3757,29 3263,00 3200 3878,23 3363,00 3300 4000,92 3463,00 3400 4124,09 3563,00 3500 4246,78 3663.00 3600 4367,95 3763,00 3700 4489,90 3863,00 3800 O0 33 28 N 18 58 W 1544.98 O0 33 35 N 18 38 W 1611.64 O0 33 37 N 18 15 W 1677.89 O0 34 58 N 21 42 W 1745.88 O0 35 39 N 22 8 W 1816.91 O0 35 38 N 20 46 W 1888.78 O0 34 54 N 20 8 W 1959,87 O0 34 18 N 20 14 W 2028,29 O0 34 58 N 20 51 W 2098,08 6,81 3.22 0,52 1 ,57 0,79 1 ,80 2,01 0,98 0,86 I ,97 0 61 081 4 74 0 39 0 34 FEET FEET DEG MIN 0.00 E 0.00 N 0 0 E 0 04 W 0.15 N 14 5 W 0 57 W 1.00 N 34 52 W 1 44 W 2.26 N 39 40 W 2 46 W 4.54 N 32 54 W 3 7t W 9,90 N 22 0 W 6 46 W 20,93 N 17 59 W 35,69 N 10 21 W 37,12 N 15 58 W 57,59 N 15,28 ~ 59,58 N 14 52 W 88,15 N 22,81 W 91,06 N 14 31 W 123.75 N 32,99 W 128 07 N 14 55 W 170,08 N 50,31 W 177,37 N 16 29 W 223,34 N 72,82 W 234,91 N 18 4 W 276,91 N 94,91 W 292,72 N 18 55 W 328,52 N 114,86 W 348,02 N 19 16 W 381,60 N 133,76 W 404,36 N 19 19 W 439,90 N 152,52 W 465,59 N 19 7 W 504,22 N 172,57 W 532,93 N 18 54 W 571',23 N 193,29 W 603,05 N 18 42 W 639,28 N 212,43 W 673,65 N 18 23 W 710,74 N 236,19 W 748 96 N 18 23 W 784,52 N 262.78 W 827 36 N 18 31 W 858.40 N 288.04 W 905 44 N 18 33 W 925,59 N 314.92 W 977 70 N 18 47 W 991,90 N 341.78 W 1049 13 N 19 1 W 29 1058,87 N 367,92 W 1120 96 N 19 10 W 60 1126,21 N 393,30 W 1192 91 N 19 15 W 36 1194,59 N 417,78 W 1265 53 N 19 17 W 06 1263,67 N 441,52 W 1338 58 N 19 16 W 57 1330,99 N 463,15 W 1409,27 N 19 11 W 0.44 1396.36 N 485.38 W 1478.31 N 19 10 W 0.68 1459.46 N 507.44 W 1545.16 N 19 10 W 1,18 1522.51 N 529.10 W 1611.83 N 19 10 W 0.64 1585.43 N 549.93 W 1678.10 N 19 8 W 2.39 1649.59 N 572.48 W 1746.10 N 19 8 W 0.53 1715.37 N 599.40 W 1817.08 N 19 16 W 0.51 1782.26 N 625.77 W 1888.92 N 19 21 W 1.54 1848.89 N 650.55 W 1960,00 N 19 23 W 1.39 1913.15 N 674.02 W 2028.41 N 19 24 W 0.55 1978.45 N 698.69 W 2098.19 N 19 27 W COMPUTATION DATE: 22-MAR-92 PAGE 6 ARCO ALASKA, INC. 3Q - 1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST 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 4611,31 3963,00 3900,00 34 20 4732,76 4063,00 4000 O0 34 50 4855.25 4163,00 4100 O0 35 50 4978.56 4263,00 4200 O0 35 48 5101.98 4363,00 4300 O0 36 4 5225.76 4463,00 4400 O0 36 10 5349,68 4563.00 4500 O0 36 16 5473,97 4663,00 4600 O0 36 35 5598,62 4763,00 4700 O0 36 39 5722.82 4863.00 4800,00 36 12 N 22 7 W 2166,91 N 23 10 W 2235,76 N 23 55 W 2306,36 N 24 12 W 2378,33 N 23 30 W 2450 49 N 23 4 W 2523 34 N 23 43 W 2596 39 N 22 30 W 2670 N 22 40 W 2744 45 N 19 23 W 2818 09 081 0 69 0 69 0 28 1 28 0 48 0 29 0 40 012 0 45 2042.60 N 723.66 W 2167.01 N 19 31 W 2i06.21 N 750.19 W 2235.82 N 19 36 W 2171.02 N 778.55 W 2306.39 N 19 44 W 2236.89 N BO8.00 W 2378.35 N 19 52 W 2302.94 N 837.47 W 2450.49 N 19 59 W 2370,10 N 865,96 W 2523,34 N 20 4 W 2437,21 N 895.15 W 2596,40 N 20 10 W 2505',21 N 923,84 W 2670,13 N 20 15 W 2573,91 N 952,45 W 2744,48 N 20 18 W 2642,55 N 979.t5 W 2818,12 N 20 20 W 5846,84 4963,00 4900,00 36 15 5970.73 5063,00 5000,00 35 55 6094,02 5163,00 5100,0'0 35 44 6217,04 5263,00 5200,00 35 31 6339,84 5363,00 5300,00 35 24 6462,76 5463,00 5400,00 35 40 6585,48 5563,00 5500,00 35 17 6707,76 5663,00 5600,00 34 58 6830,04 5763,00 5700,00 35 19 6952.66 5863,00 5800.00 35 20 N 19 28 W 2891.43 N 18 12 W 2964.56 N 17 47 W 3036.61 N 17 59 W 3108 20 N 18 36 W 3179 45 N 18 54 W 3250 91 N 19 1W 3322 O2 N '19 44 W 3392 40 N 19 39 W 3462 76 N 2O 7 W 3533 72 0,28 1 ,47 0,34 0 32 0 37 0 37 0 40 0 22 0 19 0 61 2711.75 N 1003.47 W 2891.46 N 20 18 W 2780.81 N 1027.54 W 2964.58 N 20 17 W 2849.47 N 1049.58 W 3036.63 N 20 13 W 2917.66 N 1071.55 W 3108 21 N 20 10 W 2985.35 N 1093.89 W 3179 45 N 20 7 W 3053,02 N 1116,92 W 3250 91 N 20 6 W 3120,29 N 1140,02 W 3322 02 N 20 4 W 3186,68 N 1163,37 W 3392 40 N 20 3 W 3252,90 N 1187,17 W 3462 76 N 20 3 W 3319,64 N 1211,26 W 3533 72 N 20 3 W 7075,20 5963.00 5900,00 35 44 7198,95 6063,00 6000 O0 36 6 7322,48 6163,00 6100 O0 35 48 7445,36 6263,00 6200 O0 35 19 7568,43 6363,00 6300 O0 35 45 7691,43 6463,00 6400 O0 35 20 7813,55 6563,00 6500 O0 34 54 7935,27 6663,00~ 6600 O0 34 45 8020,00 6732,61 6669 61 34 45 N 19 39 W 3604 56 N 19 2O W 3677 N 20 9 W 3749 N 2O 49 W 3821 N 21 11W 3893 N 20 41W 3964 N 21 1W 4034 N 20 53 W 4104 N 20 53 W 4152 44 96 37 09 70 79 19 49 2.16 0,33 0.21 0 78 0 3O 0 86 0 35 0 O0 0 O0 3386,14 N 1235,69 W 3604 56 N 20 3 W 3454.99 N 1259.62 W 3677 3523.23 N 1284.14 W 3749 3590,18 N 1309,01 W 3821 3.657,09 N 1334,86 W 3893 3723.98 N 1360.44 W 3964 3789,50 N 1385.35 W 4034 3854,33 N 1410,17 W 4104 3899,46 N 1427,37 W 4152 44 N 20 2 W 96 N 20 2 W 37 N 20 2 W 09 N 20 3 W 70 N 20 4 W 79 N 20 5 W 19 N 20 6 W 49 N 20 6 W COMPUTATION DATE: 22-MAR-92 PAGE 7 ARCO ALASKA, INC. 3Q - 1 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2199' FNL & 2377' FEL, SEC17 T13N RgE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4548.00 3910.72 3847.72 7766.00 6524.01 6461.01 7778.00 6533.85 6470.85 7778.00 6533.85 6470.85 7848.00 6591.27 6528.27 7883.14 6620.16 6557.16 7902.00 6635.66 6572.66 7991.00 6708.79 6645,79 8020.00 6732.61 6669.61 2009 41N 3764 08 N 3770 50 N 3770 50 N 3807 88 N 3826 56 N 3836.60 N 3884.01N 3899.46 N 710.50 1375.63 1378.07 1378.07 1392.42 ~399.59 1403.4~ 1421.48 1427.37 COMPUTATION DATE: 22-MAR-92 PAGE 8 ARCO ALASKA, INC. 3Q - 1 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD DATE OF SURVEY: 31-JAN-1992 KELLY BUSHING ELEVATION: 63.00 FT ENGINEER: T. WEST SURFACE LOCATION = 2199' FNL & 2377' FEL, SEC17 T13N RgE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4548.00 3910.72 3847.72 7766.00 6524.01 6461.01 7778.00 6533.85 6470.85 7778.00 6533.85 6470.85 7848.00 6591.27 6528.27 7883.14 6620.16 6557.16 7902.00 6635.66 6572.66 7991.00 6708.79 6645.79 8020.00 6732.61 6669.61 2009.41N 3764.08 N 3770.50 N 3770 50 N 3807 88 N 3826 56 N 3836 60 N 3884 01N 3899 46 N 710.50 1375.63 1378.07 1378.07 1392.42 1399.59 1403.41 1421.48 1427.37 FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8020.00 6732.61 6669.61 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4152.49 N 20 6 W ~.lE LL' 3Q- 1 (2199'FNL,2377'FEL,SEC 17,T13N,R9E) HORIZONTAL PROJECTION IOO0 rTq i"i ...... r'T'T"r" '"..'"'r':."i'"m"'r"m,~ ...... r"F'!"'r"l'"r'..'":"T"-r",-r".:"'"'r"r"r".."-'r":--'r-!-"i ......-,.-?i"i''4. ......,,,,Pi"i"i .......,,,i"'Pi"'! .....,,,?"F"i ............,,,i"i"~ ......,,P'i ...... j ...... i"i"t"i'" .... 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T?" -.+-~--:-.~ ..... i--.}--.}-.-} ...... i"i"i"i ..... ?i'-!"i ...... ~...~.-i..i ...... i..i--i--i ...... i-i.--i--i ...... !..i..-i.-i ..... i--i-..i---~ ...... }...}.-}..-} ....... !.-i.-.~...~ ...... !.--i.-.!..-i ...... i.-.~..i-..i ....... i..-i...i...i ...... r'?"r":' ..... i"-!'-'!-'?'- 'i'i"f'! ..... ?:'i"]"i ...... r-r"r"~ ...... r'~'"r"~ ..... ~ ...... i"]--,-i'-i ...... i-'i'"hl ...... i'"!-'?"i ..... ?i"i"'i ...... hi'-Y'i .... h'i"'i"'i ...... i'"i?"i ..... i'-!'"?i ...... i"?i'-'i ...... hi"i'"i ..... i"i"i"i"' ADG¢C GEOLOGICAL M^TEFIIALS INVENI'ORY LIST ~.: form .... received ' received d"ie ' Commenla' ' ' 40?~ n~ ( F/////~''~''--. complctl°n reP°" ii ' I f 403 yes no sund~ application ,, "404 yea ne report of sund~ application II°l~ !~9 h°le ~9g Io~ ~.~, ~ , , , D'i~SFL ' cNL. PnOO ,, · .~ ,.,. ~.. .... ~ ' BHCiSL ........ CET ~' '~ .... SPiHHE~ HE C ~~ ... ............ SSS PACKER Digilal Dala Foe_ FDC ' ' ' ~WD ~equi~ed'' ~eCeivcd SAMPLES tequi, ed ~eceived MWD , , , , LDT~CHL ' ' ~DR ~ ~ d,y ......................... ,, CYBER core LOOK ~ , ~n~lysi~ .. F~S .............. , NGT ~ ...... .... , ,, ARCO Alaska, inc. Date' March 27, 1992 Transmittal #: 8392 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ,¢/"" //¢// 2M-03 ¢/'-/> '("' 3Q-O 1 ~/ {...1~/¢" 3Q-04 ~/~¢'->' O/3Q,03 Sub-Surface Directional 1 - 2 7 - 9 2 9 21 01 Survey Sub-Surface Directional 1; 3 1 - 9 2 921 1 2 Survey Sub-Surface Directional 2 - 1 - 9 2 921 1 3 Survey Sub-Surface Directional 1 - 3 1 - 9 2 Survey Receipt Acknowledged: D&M 92114 RECEIVED Date: M A.R..-5.--L--19 9 2 State of Alaska (2 copies) Alaska Oil & 6as Cons. Commission Anchorage ARCO Alaska, Inc. Date: February 13, 1992 Transmittal #: 8361 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of lhis transmitt~ ~/.. / > 5'"I 3Q.01 3Q-01 0-04 q/.-/>'~ O-03 Cement Bond L~ ~ Cement Evaluation Log Cement Evaluationog ,--'" Cement Bond Log L,.~ Cement Bond Log J Cement Evaluation Log Please acknowledge receipt and I -31 -92 2-01 -92 2-01 -92 1 -31 -92 1 -31 -92 6395-7905 1-31-92 6690-7628 6690-7610 8585-9592 8585-9512 Receipt Drilling Acknowledge' State of Alaska(+sepia) Date' NSK 6395 RECEIVED FEB 1 4 199?- Alaska 011 & Gas Cons. Commission Anchorage -- / ARCO Alaska, Inc. Date: January 24, 1992 Transmittal #: 8342 RE'~RN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 3Q-01 2M-15 Receipt Please acknowledge receipt and return ,~LisSTapo and Usting ~ ~i(~ ~' 1 -5-92 92017 Tape and Usting 1 - 1 3 - 92 75339 Acknowledged-~-i --~--~-- .... Date- .R...~. ~..E. ! V E D JAN 2 7 1992 DISTRIBUTION: Lynn Goettinger Alaska 0il & (~as Cons. Commission Anchorage s ~~T~ s k~~'' ARCO Alaska, Inc. Date: January 17, 1992 Transmittal #: 8335 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. 3Q-01 CDN 1 -2-5-92 3Q 01 ~ CDR 1-2-5-92 Receipt Acknowledged: Please acknowledge receipt 4548-8020 4548-8020 RECEIVED ..... Date' - ......... JAN 2 1 1992 DISTRIBUTION: Alaska 0il & Gas Cons. Commission Anchorage D&M Drilling Vendor Package(Johnston) NSK TO: THRU: FROM: MEMORANUUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C· · Sm,. ~ / DATE: January 3 1992 Commissioner ~) ' FILE NO: LG13-3. DOC Blair Wondzell Sr Petr Eng Louis R Grim~l~di Petr InspectOr TELEPHONE NO: SUBJECT: Rig BOP Test ARCO 3Q-1 Permit 91-125 Kuparuk River Field Thursday,, January 2, 1992 I traveled to ARCO's 3Q Pad in the Kuparuk River Field to witness the initial BOP test of Parker's Rig #245. This rig is the largest land-based that I have encountered thus far. It is complex in design and has been compartmentalized to inhibit the spread of gas or fire in case of emergency. This makes a visual inspection very difficult in that following lines to determine proper hookup and connection type is often interrupted by bulkheads. I spent approximately five hours attempting to familiarize myself with the layout of this rig and twice had to exit the rig and start at the beginning due to becoming lost. I will make a return visit to this rig before I leave. I found minor noncompliances that are required to be fixed before the rig continues drilling. These being: A) all electrical junction boxes and panels to be closed and sealed: B) the air tight doors between the SCR and generator rooms be kept closed during drilling operations and anytime there is a possibility of gas. I was informed that in the future, automatic door closure upon gas alarm will be installed. I feel that this will be a system that will have to be proven and inspected regularly due to the high volume of air drawn to the motor room from throughout the rig. Once the BOP test was underway I found minor leaks that were repaired immediately. All equipment functioned properly and held pressure satisfactorily. Even though this is a new rig and there were unfamiliar hands, the test was concluded in three hours. I ~eel that special attention should be paid to this rig due to, the complexity of its systems. This should not reflect on th~ attitude of the drilling hands towards safe drilling operations which I found to be excellent. The gas alarms which w~re off-line during the test were repaired and working before the rig proceeded with the program. 02-00lA (Rev. 6/89) 20/1UMEMO1.PM3 In summary~ Parker's Rig #245 passed its initial BOP test~ once the gas detectors were recalibrated, and seems to be in good shape for drilling ARCO~s 3Q-1 in the Kuparuk River Field. I recommend a visit in the near future by the other inspectors to familiarize ourselves with its layout and to determine any noncompliances that may have escaped my l~nitial inspection. Attachment 11:59 OPERATION: Drlg )~. Wkvr ~P~RL~ Reserve pit V~ Audio MUD 5Y5 i ~M~: Trtp tank Pi t gauge Flow mont tot (;as detectors BOPE STACK: Test Pressure Annular preventer __ ~ ~0_ Pi per ams ~,~ ~ 0 ~ 8lind rams ~ ~ ~ ~ Choke ~ne valve~ .... ~ ~ ~ HCR Va ~ ve ~ 0 .~ Kill tlne valve~ ~-~ ~~ P.O~; RECEIVED STATE OF ALASKA ..lAN 3 1997. ALASKA Ol L AND GAS CONSERVAT ION COM~/~.~Noii & Gas Cons. Commission Bop Test Report Anchorage TEST: I ni ti a I_Z~____ Weekly__ Other .. , Permit ~ g/ %7~ ,. ACCUMU~TOR SYSTEM Full charge pressure _~ ~ ~~ p~g Press after closure / ~ ~ ~ psis Pump tncr clos pres~ 200 ps~g ~ min ~sec ~ull charge pres~ attained ~ ,~1n ~ sec Controls:Master Remote KELLY AND ~OOE 5~Y VALVES~ Upper Kelly Lower Kelly Ball type Inside BOP ~ Test pressure Choke manifold Tes~ pressure Number valves Number flanges . Adjustable chokes TEST RESULTS: Failures Test time hrs Repair or replacement of failed equipment to be made within days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Di stri buti on: orig - AOGCC c - Operator e - Suoervisor ,. Type ~)f Request: 2. Name of Operator ALA ~ OILAND GAS CONSERVATION COMMI;. .)N APPLICATION FOR SUNDRY APPROVALS OillGl# t Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate _ Change approved program .~ Pull tubing _ Variance _ Perforate _ Other _ 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 6. Datum elevation (DF or KB) RKB 63' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-01 9. Permit number 91-125 10. APl number 5o-029-22220 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 4. Location of well at surface 2199' FNL, 2377' FEL, Sec. 17, T13N, R9E, UM At top of productive interval 1495' FSL, 1555' FWL, Sec. 8, T13N, R9E, UM (proposed) At effective depth At total depth 1683' FSL, 1487' FWL, Sec. 8, T13N, R9E, UM (proposed) 12, Present well condition summary Total Depth: measured 8009' (proposed) Plugs (measured) true vertical 6708' (proposed) Effective depth: measured true vertical 4514' 7929' (proposed) Junk (measured) 6643' (proposed) Length Size 8O' 16" (proposed) 9 5/8" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Cemented Measured depth True vertical depth 1875# Poleset 1 21 ' 1 21 ' 655 sx Perm. E 45 5 5' 3 91 3' (proposed) w/430 sx Alaska Oil & 6as Cons. Commiss'~o~ Anchorage measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal ~ Reduce 9-5/8" lead cement volume from 1185 sx to 655 Detailed operation program_ BOP sketch_ sx Permafrost Type E. 15. Status of well classification as: Oil .,X (DrODOSed) Gas_ Suspended .. Service 14. Estimated date for commencing operation December 16. If proposal was verbally approved Name of approver Mike Minder Date approved 12/23/91 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~/~~~-- Title: Area Drilling Engineer / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No Plug integrity_ BOP Test_ Location clearance__ , ~.,.~.~[.~¥~. /'~/ - 7-~::~(_.,, Mechanical Integrity Test Subsequent form require 10-~_~ ,,o~.,.~o'~]';~'::- '-'7 -- Original Signed By Approved b~ the order of the Commission David W. johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KUPARUK WELL 3Q-01 9-5/8" LEAD CEMENT VOLUME REDUCTION The lead cement volume for Well 3Q-01 was permitted for 1185 sacks of cement which is 125% over the calculated hole volume from 500' above the West Sak interval to the surface. In an attempt to minimize operational problems of handling excess cement returns at the surface, ARCO Alaska, Inc. requests approval to decrease the lead cement volume on Well 3Q-01 to 25% over the calculated hole volume (655 sacks). If cement does not reach the surface, ARCO will perform a top cement job to ensure a cement plug from the surface to a depth of 100'. 0il ~, (~as G0r~s, ALASKA OIL AND GAS CONSERVATION COMMISSION October 23, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3Q-01 ARCO Alaska, Inc. Permit No.91-125 Sur. Loc. 2199'FNL, 2377'FEL, Sec. 17, T13N, R9E, UM Btmhole Loc. 1683'FSL, 1487'FWL, Sec. 8, T13N, R9E, 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 Commission will advise you of those BOPE test that it wishes to witness. David W. Johnston, Chairman Alaska OlX~,~_~Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ..... OIL AND GAS CONSERVATION COMi 31ON PERMIT TO DRILL 20 AAC 25.OO5 la. Type of Work Drill X Redrill ~ I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas ~ Single Zone X Multiple Zone . 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc, RKB 63'. Pad Elev.: 22' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 373301 ALK 4162 4. Location of well at surface 7. Unit .or property Name 11. Type Bond (see 20 AAC 25.025) 2199' FNL, 2377' FEL, Sec. 17, T13N, RgE, UM t(uDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1495' FSL, 1555' FWL, Sec. 8, T13N, RgE, UM 3Q-01 #U630610 At total depth 9. Approximate spud date Amount 1683' FSL, 1487' FWL, Sec 8, T13N, R9E, UM 01-Nov-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3Q-02 8009' MD 1487' ~ TD feet 17' at 550' MD feel 677 6708' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400' feet Maximum hole anc~le 36° Maximum surface 2316 p~ At total depth (TVD) 3500psicj @ 6708 18. Casing program Setting Depth size specification Top Bottom Quantity of cement Hole Casing Weight Grade Couplincj Lenc~th IVD TVD IV~ TVD linclude stage datat 24 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' :1:200 CF 12.25 9.625 36.0# J-55 BTC 4514' 41' 41' 4555' 3913' 1185Sx. PF E& HF-ERW 430 Sx. Class G 8.5 7" 26.0# IJ-55 BTC 7968' 41' 41' 8009' 6708' 165SxClassG HF-ERW Top 500' above Kuparuk 19. TO be completed for Redrill, Re-entry, and Deepen Operations.r [EEiVED Present well condition summary~,~ Total depth: measured feet Plugs (measured) true vertical feet ' true vertical feet Alaska Oil & Gas Cons, .C~mmissi0r~ Casing Structural Length Size Cemented Measured depth True Vertical Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ' Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~ned ~//'~' ~1_ ~~~ ~ CommissionTitle Area Drillincj En~ineeruse Only' Conditions of approval Samples required __Y e s 3<' N o Mud log required__ Y e s ~ N o Hydrogen sulfide measures ~ Yes ~ N o Directional survey required ..~ Yes ~ N o Required working pressure for BOPE ~2M; ~ 3 M; ~ 5 M; ~ 1 0 M' ~ 1 5 M Other:~,~~___,._~%~ ' ' ~-- by order of Approved'~'"l~.~ ~ ~,,)~ Commissioner the commission Date t/ /. Form 10-401 Rev. 7-24-89 in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 23, 1991 Mr. L. C. Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' SUBJECT: Isolation of Significant Hydrocarbon Zones Kuparuk River Field Revisions to Permits to Drill for 3Q-1,3Q-3, 3Q-4, 2M-21 This letter is to clarify the Permits to Drill for Kuparuk River Unit Wells 3Q-1, 3Q-3, 3Q-4 and 2M-21. The previously submitted General Procedures for the above referenced wells did not include any mention of the possibility .of encountering significant hydrocarbon zones at shallower depths than the Kuparuk. If such zones are encountered, a sufficient volume of cement will be used to provide annular fill- up to a minimum of 500' above ali significant hydrocarbon zones in accordance with Rule 20 AAC 25.030. Subsequent applications for Permits to Drill will include a statement in the General Procedure referencing the isolation of any significant hydrocarbon zones above the Kuparuk. Thank you for your consideration on this matter. If ARCO can furnish any further information, contact me at 265-6575. Sincerely, T.A. Senior Drilling Engineer TAB/mac A. W. McBride~¢4/,~/'¢¢ S. D. Bradley E. D. Fitzpatrick 3Q Pad General Weilfile RECEIVED 0 CT 2 ,~ 1991 Alaska 0JJ & Gas C011s. Commission Anchorage DRILLING FLUID PROGRAM WELL 3Q-01 Spud to 9-5/8" Drill out to surface casino weioht UD -- -- Density 9.0-10.0 9.0-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4-8 APl Filtrate 10-12 8-10 pH 9-10 8.5-9 % Solids 10 +/- 4-7 Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <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 ir 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 2316 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3Q-01 will be 3Q-02. As designed, the minimum distance between the two wells would be 17' at 550' TVD. 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 (>4 hrs) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 sec/qt to drill gravel beds. ARCO ALASKA, Structure' Pad 30 Well- 1 Field · Kuporuk River Unit Location ' North Slope, Alaska Created by : jones For: T BILLINGSLEY Dote plotted : 1 6-Sep-91 Plot Reference is 1 Version ~5. Coordinates ere in feet reference slot fl. True VerUcol Depths ore reference wellhead. i'-7]]/]~ E A S T M A N I/_//_/Ltll C H R I ST E N S E N TD LOCATION: 1683' FSL, 1487' FWL SEC. 8~ T13N, RBE ~ ~ 16.00 1400 1200 1000 800 I I I I I I I I I West 600 4,00 200 0 I I I I I I I N 20.05 DEO W 3932' (TO TARGET) TARGET LOCATION: 1495' FSL, 1555' FWL SEC. 8, T13N, RgE T~d~GEI' TVD=6433 TUD=7670 DEP=3932 NORTH 3694 WEST 1348 o cq · · 400 _ ~-~ 800- 1200- _ 16O0- - ("")2000- _ ~ 24O0- 3600- - 4000- _ 4400- - 4800- _ 5200- 5600-- 6400- KOP TVD=400 TUB=400 DEP=O 3.00 9.00 15.00 BUILD 3 DEG / 1OO' 21 27.00 33.00 EOC ~VD=1523 TMD=1600 DEP=365 B/ PERMAFROST WD=1593 TMD=1687 DEP=416 T/ UGNU SNDS TVD=2613 TMD=2948 DEP=1157 K-lO ~WD=3863 TMD=4495 DEP=2065 T/ W SAK SNDS TVD=3303 TMD3801 DEP=1658 B/ W SAK SNDS 'PVD=3713 TMD=4307 DEP=1956 9 5/8"CSG PT TVD=3913 TMD=4555 DEP=2101 AVERAGE ANGLE 56 DEG TARGET TVD:64.33 TMD=7670 DEP=3932 T/ ZONE A 'fVD=6485 TMD=7734 DEP=3970 \ B/ KUP SNDS' TVD=6546 TMD=7809 DEP=4014- TD / LOGGING PT TVD=6708 DEP=8009 DEP=4132 I I i i i i i t i i i i i i i i i i i i i i I O 44)0 800 1200 1600 2000 2400 2800 3200 3600 40(]04400 Scale 1 : 200.00 Vertical Section on 539.95 azimuth with reference 0.00 N, 0.00 E from slot SURFACE LOCATION: 2199' FNL. 2377' FEL SEC. 17, T13N~ R9E - -3400 - -3200 - - 3000 _ -2800 - -2000 - -2400 -2200 - - 20IX) - -1800 _ ~14o0 1200 lOOO 80o 60o 400 200 200 Strut' '~ : Pad 3Q Field · Kuparuk River Unit Location : North Slope, Alaska Wesf Scale 1 ' 50.00 2550 I 2500 2450 .. 2400 2350 I I I I I I I I 1300 1300 300 11oo 1100 900 2300 2250 2200 I I I I I 4100 1100 900 50O 1300 2150 I I 1700 2100 1 750 1800 1850 1900 1950 37OO 20O0 2050 2100 2150 o o o 0 I ~,530& 1300 700 ~ 300 700 3OO 500 2200 2250 2300 GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD Well 3Q-01 . . , , . . . , , 10 11 12 13 14 15 16 17. Move in and rig up Parker 245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4555') 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. Drill 8-1/2" hole logging while drilling to total depth (8009') according to directional plan. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. 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. R'ECEIVED 7 i 13 5/8" 5000 , SI BOP STACK ACCUMULATOR CAPACITy TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 15(X) 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 STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLE~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. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3(X)O PSI AS IN STEP 4. 7. 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 CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE Bo3-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. 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 195/8" - 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. 1:~5/8" - 5000 PSI ANNULAR SRE ~2~89 ~ :UPARUK RIVER UN~. 20" DIVERTER SCHEMATIC 5 6 4 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 . 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., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) R'EEE,.IVED OCT _1 ~. l~l · as~.j)jj & I~as Cons. commissio~ ~choraffa 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ITEM (1) .Fee (2) Loc (3) Admin ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ,e,o,,-. [2 thru 8] [8] .,~ru 13] [10 & 13] [14 thru 22] (5) BOPE ~.~r~, /~'/~- ~/ [23 thru 28] [29 thru 3'i] (6) Other (6) Add1 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 ............................ Lease & Well ~, ,/q,~/- ~'Z~[; YES NO REMARKS e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & n~nber ................................ T Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is 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 ~Oo~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & 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... Additional requirements ............................................. / O 'TZ "-~O geology' DWJ~ RPCZ~ eng i neer i ng,: :. MTM ~ LCS -'-"',, rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE 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 APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. CO~,~PAi~Y ~A~E : ARC~ ~bASK~, INC, FIELD r,.~.~E : KUPARUK RIVER RE)ROUGH : .(~ORTN SLOPE STATE : AL, AS~A API ~JU~'~BER : 50-0~9-22220 ~EF~:R~]~tCE ND : Q20~7 RECEIVED JAN 2 7 1992 Alaska 011 & {~as Cons. Commi~lo~1 LI6 Taoe veriflcat, ion Listin~ Schlumber(~er :l!.as~a Comput. i. na Center PAGE~ SE~VtCE ?.!r~iE : EDIT R~EI, ~A?~E : 92017 PREVIOUS CO~E~T : ~aCO AI,ASKA I~C,, 30-0~, KUPARUK RlVg~, 50-029-2222O-00 **** TaPE NEADER **** SERVICE ~aaE : DATE : 921C)1,1,1.5 0~I~I~ TAPE MA.~I.!] : 92017 pREVIOUS TAPE CO~Eb~T : ARCU ALASKA I~'~C,, 30-0!, KUP~RIJK RIVER, 50-029-22220-00 **** FILE gEADER **** FILE NA~E : EDIT ,901 SERVICE : FLIC VER~IO~ : O0iA06 DATE MAX REC SIZE : 10~4 FILE TYPE : LO ****************************************************************************** FILE A~C~) ALASKA I~C, F, ~.~P A RI. IK RIVFR 50-029-22220 PASS !,~'!D LOG DATA DF~'~Sl,m¥ ,!~ATA PRFSF, i'~'rED O~; THiS I, iBRARY TAPE IS FROM 'RNOB MAX' ~)ATA SANP[,~.?.i) F:VMRY -.5000 FEET L(]GG!~G ?,;~ILE DR1LLr~G RES!~STIVITY/GR 4548' TO 7957' 'P'~" _,b RO~,:/DE SITY 45~8 TO 7889' LIS Tape Yerification ListIn~ $Chlumberqer AlasKa Computina Center 15-jAN-1992 08:02 PAGE: 2 TABI~E TYPM : CONS TUtti VAt.,!] DEFI TYPE CN A.CO aI.,A~A,RINC. Comoan~ Name KUFARUK .VE.L Field ame 3Q-OI well Name 50-029-22220 AP1 Serial Number 2~g9' F~L & 2377' FEL Field Location FT FT ~T FT FT FT FT G/C3 WN FL SECT TOWN COUP? NATI LAT! LONG WlTW PDAT L~;F APD EKB EDF EG b TDD TDL TLI DFT DFD DFPM DFV DFL R~'S MST R~C~ ~CST STET~ BWT 17 9g bliORTH St, OPE ALASKA US A 594004 0, DF 63. 63. a020. ~020. ~020. 4548. LSND 10.3 9.5 37. 4.7 2 5 2.064 75. -999.25 Section Township Range Count~ State or Province Nation hatitude hongitude Witness' Name Service Order Number Permanent datum Elevation o~ Perm. Da bog ~easured From ABOVE PERMANENT DATU~ Elevation of Kelly Bu Elevation of Derrick Elevation of Ground L Total DePth - Driller Total Depth - Log~er Bottom Log Interval Top Lo~ Interval Drilling Fluid Tvoe Drilling Fluid Densit Drilling FlUid Ph Drlllin~ Fluid Viscos Drillin~ Fluid Loss Resistivity of Mud Sa ~ud Sample Temperatur Resistivity of mud fi ~ud Filtrate Sample T Resistivity of M~d Ca ZONE ~ud Cake Sample Tempe ZONE Surface Temmerature Bottom Hole Temperatu ~iS Ta~e Yer~flcation Listl~o BchlumberQer AlasKa Computi~ Center 15-jA~-1992 PAG~ 3 TABLE TYPE : CU~V RHOR PEF DCAL DPOP TNPH ATR DER ROPM DEFI '''''''''''''''''''''''''''~ ~ hah elt b ...... * ..... ..-...w.... ......... th n Name ~0S2 ~,S e 0 Dens~ V ' bT [~] 1 k Density Delta RHO P~otoelectr~c Factor Differential CslIper Density Porosity Density Porosity' OutPut from an APpllcatlon Proqram Thermal Neutron Porosity ~amma Ray ** DATA FF)RMAT SPECIFICATIOn; RECORD ** ** SET TYPE - 64ER ** TYPE REPP CODE VAbUE 1 66 0 2 66 0 3 73 56 5 66 7 65 8 68 0,5 9 65 FT 1~ 66 0 t4 65 Pt 15 66 68 16 66 1 0 66 o LIS Tame Yerlflcatlon blstin~ SChlumberger AlasKa Com~utlnO Center 15-JaN-1992 08:02 PAGE: ** SET TYPE - CNA~ ** ROS2 LwD G/C3 5940o~ 00 n00 O0 0 G/C3 594004 00 000 00 0 G/C3 594004 0O 000 00 59490~ 00 goo 00 0 IN 594004 O0 000 OO 0 PU 594004 00 000 00 0 PU 594004 00 000 00 0 PU 5940(!4 00 000 00 0 ONMM 594004 O0 O0O O0 0 OH~ 594004 Q~ 594004 O0 000 O0 0 r/HR 59400t O0 OOO O0 0 GAPI 594004 O0 OOO O0 0 AP1 APl FILE N..,M REPR PROCESS CL.a.S$ MOD MI.JMB S~MP EbEM CODE (FLEX) :"3o ..... o ;" ........ , " .... , "",'"",,"",'""'""ooooooooo 1 I 1 4 68 0000000000 i I 1 4 68 0000000000 ! 1 1 4 68 0000000000 1 1 1 4 68 0000000000 1 1 I 4 68 0000000000 1 1 I 4 68 0000000000 1 1 ! 4 68 0000000000 1 ! 1 4 68 0000000000 I ~, 1 4 68 0000000000 1 l 1 4 68 0000000000 i 1, 1 4 68 0000000000 1 1 1 4 68 0000000000 1 1 1 4 68 0000000000 ** DATA DEPT. PEF,B~P TNPN.LWD ROPE.LWO DEPT. PEW.LWD ROPF,BWT~ DFPT, TMPW,I,~D ROPF.L~D DEPT. T~P~.I, WD ROP~.[.,~? D~PT, DWpT. PEF.L~D ROPP'.Lw9 ~021,500 ROS2 LWD '999,250 999,250 DCAL:LWD '999.250 -99q,250 ATR.LWD '999,250 51,~30 ~R,LWD -999,250 8OO0.000 ROS2.LWn -999,250 -999.259 DCAL,LWD -999,250 -999,250 ATR,LWD -099,250 60.4a3 GR,hWD -999,250 7900.000 ROS2,LWD -999.250 -999.250 DCAL,bWD -999,250 -999.250 ATR,LW~ ~ 791 53.411 GR.LWD 77~008 78O0.900 ROS2.LMD 2.235 3,13~ hCAL.LWD ~ 34,o0¢~ ATR.LWO 2.:746- 853 67,fi95 GR.LWD 42.455 7706,000 ROS2.LW~ 2.397 3,364 !nCAb. LW[> 0.4S2 33,70n ATR.LWD 15.3.57~ CR,LW9 117.121 7600. OhO q?)S2. L, WD 2.36)9 3.521 9CA~.. B'?D 0.432' 4b. (;ag ATR. Lt.~P 1. 638 9~, 356 GR, L~:D 92,371 RMOB,BWD -999,250 DRHO,LWD DPHI,bWD -999,250 DPOR,LWD PS~,bwO -999,250 DER,LWD .~999,250 999'250 '999.:250 RNOB.LWD 999i250 O~MO!LWD ~999,250 DPHI,LWD ~999 250 DPOR LWD .999.250 PS~,LWD -999 250 DER LWD 999,250 RHC)B,LWD -999,250 DRHO,LWD DPHI,LWD -g99,250 DPOR,LWD PSR,LWD 1,907 DER,LWD RHOB,LWO 2.235 DRHO.LWD i)P,I,bWg 0.251 DPOR,LWD PSR.LWD 45.162 DER,LWD RNOB.LWD 2.397 DRHO.LWD DPHI.bW~ 0.153 DPOR.LwD PSR.LWD 2.028 DER,LWD RH.O~.BWD 2.369 DRHO,LWD DP~T,LND 0,170 OPOR.LWD PSR.L~D 1.666 DER.b~D '999,250 '999,250 1,858 0,022 44, 0,008 09~ 0,000 0,170 1,655 ~I$ Tape verfficatlon Li, stin~ 15-JAt~!-lgg2 0@:02 PAGE: 5 ~cl%lumberg~r AlasKa Computin<~ Center' DEPT. 750~i).000 R!i]S2. LWO 2.338 RHOB. L~0 2.338 DRHO.LWD -0.019 PEF. I,~D 3.755 DCAL. I.,~,~D 0.515 DPHI.LWD 0.~89 DPOR.LWD 0,.~89 TNP~.L~D 47.100 ATR.L~[,') 2.141 PSR.bwD 2.141 DER.LWD 2~ 141 ROP~. LWD ! 55. 609 GR. L~'D 1 O0. 633 DEPT 740o.000 ~$2.LwD 2.3~9 R~O~{. hwD 2 369 DRHO.LWD -0.005 PEF~ Lwn, 3.5~9 DC~5,L'~0 0.218 DPHI. [~O 0~170 'OPOR.LWD 0.~70 TNPN~.~ . I,~D 4~. 40~. ATR. Lwr~,,,~, 2. S24 PSR,LWD. 2,724 DER.LWD. ~.758 ROP~".. LWD 156. 535 GR. LWD 154.70~ DEPT. 7300.000 ROS2.LWD 2.412 RHOB.LW0 2 412 DRHO.LND -0,010 PEFI,, ~ D 3.a!.8 9CAS.LWO 0,3U3 DPHI,LWD 0~144 DPOR.LWD 0,144 T~,PN~L~'O 46.000 A~R.L~D 2.622 PSR.h~D 2. 514 DER.LWD 2,552 P~. L~r~ lg7,821 GR. LWO 151.571 DEPT. 7200.000 RI)S2. L~O 2,456 RHO[%. L',{ D 2 456 DRBO.LWD 0,007 PEP, L~D 3.75,,] DCAL.LWD 0.255 DPH!,LwO 0:118 DPOR.LWD TNP~.L, WD 40.~00 ~T~. [,WD 2.697 PSR.LWO 2.578 DER.LWD ROPF, L~D 152. 384 GR. LWD 107,003 PEF.[,,?4t? 3.~i DCAL,LWD 0,213 DPHI.5 O 0 t20 DPOR hWD ~0 T~P~. I,~f) 35.800 gW~. L~D 3,144 PSR.bNO 2 959 DER~LWD 19 ROPE. T,,:~9 1,71,42! GR, LW[) 89. 823 DEPT. 7000.o00 ROS2.LWD 2.54] RHOB, L~/D 2 543 DRHO.LWD 0.006 .. .20o ATR, I,~D 3. 34 PSR,LWO 3 28 DER.LWD 330 ROPS~. LWD 180. 209 (;R. LWD 83.653 D~PT. 6900.00~) ROS2.LWD 2.~26 RHO?~.LWO 2.426 DRHO.LWD 0.,003 PEF. L%*~D 3.959 DCAL.LwD 0.~15 DP~I.bWD 0.136 DPOR LWD T~P~. L~qD 38.000 ATR. b~.~D 2.387 PSR.I~WD 2.330 DER~LWD 2,350 R~PW. I,~9 ~8,239 GR. I~WD 97,499 DEPT. ~ @ (~O. 00~) ROS2 . LwD 2,470 RHOB. LWO 2 .470 DRHO. LWD 0,020 DEfY. 1, ~.~ ,D 4.0.18 DCAt~.LWD 0.199 DPHI.L~D 0.109 DPOR.LWD TNPN.LWD 41.3n~) ATk. LwD ~.g69 PSR. 5~VO 2.707 DER.LWD ROPE. [,wn 75.3~5 GR.L~9 81 .417 DEPT. 6700.n00 Rf]$2.LWD 2.314 RI. tOB.SWD 2.314 DRHO.LWD 0,002 Pg~.I,~[> 3.322 ~CAL.L~D 0 2~6 DPHI.LWD 0.204 DPOR LWD 0.204 TwPN.L~P 42.700 ATR.L~D 1[1~ ~ PSR.B~O 1,240 DER:LWD X.193 ROpF.L~D 172.493 G~.I,~;9 lO6.740 DEPT. 66 o 0. ',') (],~ R{~$2. LwD 2.3S5 RF, OE.L%~O 2.385 DRHO.LWD 0.005 "EF. [,~:D 3.~;61 RCAL.LYD A.341 DPHI.. b~D 0.161 DPOR.~WD 0.161 T ~! P N. L ~ l) 32..'~ 0~) A T a. [, W t?. 2.324 PS R. L w D 2.227 DE R. L W D 2;2 62 ROPE. Lt~;9 ! 09.755 GR. LwD 74. Rb~ DEpw. 65o0.0ou ~ t.~$ ?. {~'~ ~ 2.4u2 RHOF. Iu~:~ D 2.402 DRHO.L~D -0.014 PF:F. L;~D 2.t~4b DCAB.L, wD O. 3(;,~ 9PHI.L,qD 0.150 DPOR.LWD 0,150 TNpu. [.,~n 34. ~'~0(; ATR. LWF~ 2.000 PSR.LW~ 1.909 DER.LWD 1.942 ROPW. I.,~,D ~60. OOr; C~. L~F, 72.8,17 ~I$ Waoe Yerification Listlnq ~chlu~berger AlasKa Computino Center tS-JA~-1992 08:02 PEF. L~'F;' 2,924 DCAL.LWD 0.276 DPHI.b~D 5 O~ ATR.t~W[) 2,745 PSR,bWD 35'O17 (~R be~r': 100 9~6 ROPF.L?~9 231, _.. D M ? T. 630 n. 000 R 0 S 2, b W D 2.37 ,q R H [) ~, b i,~ D PEF.LMD .... 2.917 DCAL.LW~.. ~ 0,216~ DP~I..bWD TMpH, [.W[~ 33.50~) qTR,bWD 3,010 PSR,LWD ROPE. LW9 32g. 53~ GR. LV~[) 93.68~ D~.P 62o0.voo ROS2 LWD 2.4.20 RHO~.bwO PEF, L'~D 2,5?o CAb. L~D 0.491 DPHI,LWD T~P~4. bWD ~7,90"~ ATR.bWD 3.450 PSR,L~D ROPE. Lw{) ! 86,809 GR,LWD 77.150 DEPT. 6100,000 ROS2.LW{> 2,374 RBO~,LWD PE~.L~D 2,850 DCAL.LWD 0,!46 D~}~I.UWD TNPN, L%~D 36.000 t%TR.LWO 2.506 ~8R,LWD ROPE. b~D 386,487 (;R, LWD 83,573 DEPT, 6000,000 RO$2.L~[) 2,388 RHOB.BMO PEF,LWD 2.954 DCAB,LW'O 0,118 DPHI LWD TNpN,t. Wo 45,400 ATR.LwD 2'721 PSR:LWQ ROP~.L!~D 326,470 GR,LWO 98.247 DEPT. 5900.000 ROS2.bWD 2.378 RHOB bWD PEF.LwD 2,904 DCAb,LWD 0.199 DPHI:LWD TNP}I.LWD 33,100 ATR.LwD 3.186 PSR~ bWO ROPE.LWD 266.870 GR.LWD 85,879 DEPT. 5800,000 R(~$2.b~O 2.346 RHOB.L~D PEF.L~D 2,762 DCA[j.I..WD 0.057 DPHI,b~D TNP~.t, WD 38.000 ATR,L~D 2.731 PSR,LWD ROPE,LwD 390,179 GR.LWD 81,102 DEPT. 5700.000 RO$2.LW~ 2.312 RHOO,L~D PEF.LWD 2,91~ DCAL.LWO 0.0o0 DPHI.LWO TNPN.LWD 37,600 ATR.L~D 2.506 PSR,LWD ROPM.LwD 295.O~9 GR.LWD 81.877 DEPT. 5600,009 RflS2.LWD 2.298 RHO~%.UWD W PEF.L~D 2 ~72 OC~L.LWD o.071 DPH!.L D TNPN.LWD 38,6~0 ~TR.L~D 2.747 PSR.LWO ROPR.L~[> 310.236 G~.LW9 81.499 DEPT. 5500.F)O0 Ri)$2.l, WO 2.321 RHO~.bWD DEF.LWD ?,~42 9CAL.LWD 0.140 DPHI,L~D TMPH.I, WP 36.400 ATR.LWD ?.7!3 PSR.b'~D 2.400 0.152 2.656 2 378 2.912 2 420 0i140 3 450 2 374 0!167 2 515 :388 159 2,654 :378 !65 3.039 2 346 0!184 2 7~4 2 312 0:205 2.472 2.298 213 ~.'679 2.321 0.199 2.659 2.310 0.206 ?.644 DRHO.LWD DPOR.LWD DER.LED DRHO,LWD DPOR,LWD DER,LWD DPOR WD DER. DRHO,LWD DPOR,bWD DER,LWD DRHO,LWD DPOR bWD DER:LWD DRHO LWD DPORiLWD DER.LWD DRHO.LWD DPOR,LWD DER.LWD DRHO,LWD DPOR,LWD DER,LWD DRHO,L~D DPOR.LWD DER.LWD DRHO.LWD DPOR,LWD DER.LWD DRHO.bWD DPOR,b~D DER.bWD -0,001 0,152 2,607 -0.027 0,000 0,i67 2,511 0'0~40 "'0,001 018 2,720 -0 022 0i205 2 484 '0,014 678 -0.008 0,206 2,676 I$ Tape Verification Llstinq chlumberqer A~aska Computin¢~ Center 15-JAN-1992 08:02 PAGEI 7 DEPT. 5300.000 Rc~S2.LWD 2.431 RHOB.bWD 2.431 DRNO.LWD 0.055 DE~ L~vD 3.147 [)CAb. LWD 0.438 DP~I,LWD 0 ~33 DPOR.bWD 0.1]~ TN~N: [,%'~'D 37.8Ofl ATR. L~D 3' 106 PSR. bwD 2:903 DER.L~D 2.969 ROP~.LWD 438.98~ GR.GwD 77.486 ~" LwP 2.3~7 DR~O LWD 0,:00? DEPT. 5200.0()£.~ R{)S2.LWD 2.317 RHOt~.LWr~ 0202 DPOR[t,,,~D ~ VEF. L~D 2.850 OCAL.LwD 0. I31 OPEI, ..... 012 TNP~, bW[) 36,70,0 ATR.LWD 3.074 PSR. 5W~) 21980 DER LwD 1202 ROP~.L D 315.135 GR LwD 74 917 ROP~.LWD 298.28~ GR.LWD 90.184 DEPT. 5000.00o R[]S2,LWD ~.244 RNOB.bWD 2.244 DRHO bWD -0009 PEF.L~D 2,8~.4 DCAL,I, WD 0,000 DPHI,LWD 0.~46 DPOR:LWD 0:246 TNP~,LWD 38,300 ATR.LWt) 2.13~ PSR.LWD 2.149 DER.LWD 2,~42 ROP~,t,w[) 248.563 GR.t, WD 76.127 D~PT, 4900.()00 RO$2.LWP 2.226 RHOB,LwD 2 ~26 DRHO bWD -0.009 PEF . I,~O 2 .81,~ DC~L .~Lwt', 0 .000 DPHI.bWD. 0:z 57 DPOR:LWD 0,257 T~PH. LWD 39. 100 ATR. LWD 3. 306 PSR, bWD 3' 226 DER, bwD 3.253 ROP~. Lw[} 336.135 GR. hWD 80.321 PE~':L',~P 2.91.8 OCAb.bwO 0.087 DPHI.bWD 0.220 DPOR:LWD TNP~I LwD 45 GOO ATR.L~D 2463 PSR.bWD 2.348 DER.LWD 2.388 ROD~. L%~P ~Q6. 559 GR. LWD 75 ~ 243 DgPm. 4700.000 RO$2.LWD 2233 RHD0.LWD 2.233 DRHO.LWD 0.005 ' PEF.Lw[) 2.50:] DCAL.LWD 0~352 DPHI.LWD 0.253 DPOR.LWD TNP~.L~,,D 49.g~)(.~ ATR.LWD 3.018 PSR.LWD 2.872 DER.LWD 2'921 R~P~. L:~n 260. 773 GR. LWD 85. 237 D~PT. 4bO (). GOO., ROS2 LWP, 1.989 RNOB.LWD 1.989 DRHO.LWD -0,045 PEF" L~vO i 972 OCAb~L~I') 2 lgg DPHI.L~D 0 401 DPOR I,~D 0.401 TNp~ [, ~,~ !3 57.20{, ATR.LWD 0.90~ [-'SR. L,~i, 1.675 DER.LWD 1,128 ~Opv, L~:~ -Q~9. 250 eR. LWD 56. 553 DFPT. 4500.o0~ R()S2.LWD 2.606 R}~OB.Lwo 2.666 DRHO.LWD -0,556 PEF.L~D loO.~0t~ !~C~[.,.LWD 0.97~ DPHI.~WDWr~ -99~'0'010250 DPOR.LWDDER.LWD -999.250'0'0~0 T~)PN.LW[3 -99g.~5[; ATR.LW~ -g99.~50 PSR.b ~. .. RPP~.LWD -9q9.25{) GR.LWD -990.~50 DEpT 446() (~P~, R[.']S2 LWD -g9925n RHO[% bWO -999250 DRHO LWD -999.250 PE~.[,~!D qg~ 25(1 DCAL LW", . . . - . . ~. -909.250 PPHI.LWD -g99.~50 DPOR.LWD -999, 50 2 TNP~.L~.~D -gq9.25~ ATR.LWD -999.250 PSR.LWL) -99g.~50 DER.LWD -999.250 R~p~,[./WD -9q9.~50 QR.LWD -999.250 ** END (~W ~ATA ** ~I$ Tape Verification Listing ~chlumberGer AlasKa Computing Center 15-JA~!-lgg2 oB:02 PAGE: FIL~ NA~E : EDIT ,00~ S~RVICE ~ERSION DAT~ : 021ol/15 ~X REC SiZE : i024 FILE TYP~'~ : LAST FILE **** TAPE TRAILER $~RVtCE ~AF~E : DAT~ : 92/()t/~.5 ORIGIN : FDIC TAP~ NA~E : 9201.7 CONTINUATISL! ~ : 1 PREVIOUS TAPE : CO~ENT : ~CO ALASK~ I~C., 3(~-01, KUPARUK RIVER, 50-029-22220-00 **** P~EL TRAILKR SERVICE ~AMR : EDIT DAT~ : 92/01/~5 REEL ~AN~ : q2017 CO~TINUATIOM # : PREVIOUS REEL : COig~MT : ARCO ALASKA INC., 30-01, KUPARUK RIVER, 50-029-22220-00