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Home My WebLink About194-147MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, October 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2Z-22 KUPARUK RIV UNIT 2Z-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/12/2023 2Z-22 50-029-22524-00-00 194-147-0 W SPT 5814 1941470 1500 2769 2772 2793 2788 180 190 190 190 4YRTST P Sully Sullivan 8/14/2023 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 2Z-22 Inspection Date: Tubing OA Packer Depth 885 1820 1785 1785IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230816125736 BBL Pumped:0.9 BBL Returned:0.8 Thursday, October 12, 2023 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2Z-22 KUPARUK RIV UNIT 2Z-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/06/2023 2Z-22 50-029-22524-00-00 194-147-0 W SPT 5814 1941470 1500 2259 2254 2246 2256 570 660 660 660 4YRTST P Brian Bixby 3/10/2023 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 2Z-22 Inspection Date: Tubing OA Packer Depth 1080 3010 2940 2930IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230310160709 BBL Pumped:2 BBL Returned:1.7 Thursday, April 6, 2023 Page 1 of 1           194147 30 92 9 WELL LOG TRANSMITTAL #905626042 To: Alaska Oil and Gas Conservation Comm. June 3, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 JUN 2 7 2019 RE: Plug Setting Record: 2Z-22 AOGCC Run Date: 5/14/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 22-22 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22524-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: (i� �� Signed: Wallace, Chris D (CED) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, June 2, 2019 7:40 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 2Z-22 (PTD 194-147) Update 6.2.19 Attachments: 2Z-22 90 day TIO trend 6.2.19.JPG Chris, KRU WAG injector 2Z-22 (PTD 194-147) is ending the 30 day monitor period during which no signs of TxIA communication were observed. CPAI intends to return the well to its 'normal' status at this time. Attached is a 90 day TO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn CPF1 & 2 Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM canociFNNIps Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, May 3, 2019 11:06 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: KRU 2Z-22 (PTD 194-147) Update and plan forward Attachments: MIT KRU 2Z-22 diagnostic MITIA 4-14-19.xlsx Chris, KRU WAG injector 2Z-22 (PTD 194-147) was originally reported for a failed MITIA and was shut in on 3.10.19. The well was inadvertently BOI for 75 minutes on 3.24.19 (LCA synopsis previously submitted). Subsequent the completed LCA the well was secured with a downhole plug and passed an MITT and MITIA on 4.14.19. The wellbore was then circulated out with fresh wellbore fluids and an additional MITIA passed on 4.29.19. The plan is to bring the well online for a 30 day monitor period and if no signs of annular communication are observed the well will be returned to 'normal' status. The most recent MITIA 10-426 is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn CPF1 & 2 Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM cowl ps Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, March 24, 2019 7:14 PM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: KRU 2Z-22 (PTD 194-147) of failed MITIA update 3-24-19 Chris, After being shut in on the morning of March 111h once freeze protect could be arranged, 2Z-22 was inadvertently returned to water injection earlier this morning for a brief period. It was identified very quickly and the well was shut in after only being online for an hour and 15 minutes. CPAI considers this to be a serious infraction and we are already scheduling a LCA (latent cause analysis) to understand what exactly happened so that we can improve our process to avoid similar occurrences in the future. We will provide you with a summary of our results when the LCA is complete. Please don't hesitate to call if you have any questions and would like to discuss further. Kelly Lyons / Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 From: NSK Well Integrity Supv CPF1 and 2 Sent: Sunday, March 10, 2019 4:47 PM To: Wallace, Chris D (DOA) <chris.waIlace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 2Z-22 (PTD 194-147) Report of failed MITIA Chris, KRU WAG Injector 2Z-22 (PTD 194-147) failed a diagnostic MITIA today. The well is being shut in and freeze protected as soon as possible. The immediate plan is to secure the well and begin diagnostics. Once a path forward has been determined the proper paperwork for continued injection or corrective action will be submitted. A wellbore schematic and TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Qt DATE: Wednesday,August 26,2015 TO: Jim Regg 1131 P.I.Supervisor 15-�� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-22 FROM: Johnnie Hill KUPARUK RIV UNIT 2Z-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry i — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2Z-22 API Well Number 50-029-22524-00-00 Inspector Name: Johnnie Hill Permit Number: 194-147-0 Inspection Date: 8/6/2015 Insp Num: mitJWH150810105631 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 2Z-22 - Type Inj I W TVD 5814 - Tubing 950 - 950 - 955 955 PTD 1941470 . Type Test SPT;Test psi 1500 - IA 1120 1980 - 1890 - 1880 - Interval 4YRTST PAF P ,; OA 780 800 - 800 800 - Notes: Wednesday,August 26,2015 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I C~ Lc -/L/ '7 File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] ... Logs of various kinds [] Other COMMENTS: Scanned bY: Bevedy ~ Vincent Nathan Lowell Date: ~ '"..~ Isl~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 06, 2011 TO: Jim Regg R� i. 1/ ��I1 SUBJECT: Mechanical Integrity Tests P.I. Supervisor 4 isor ' � CONOCOPHILLIPS ALASKA INC 2Z -22 FROM: John Crisp KUPARUK RIV UNIT 2Z -22 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 6 - 81 2 NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2Z - 22 API Well Number: 50 029 - 22524 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCrl10829095347 Permit Number: 194 - 147 - Inspection Date: 8/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well r 2Z -22 • Type Inj. N7 TVD 5814 IA 860 2060 2000. 1980 P.T.DI 1941470 ' I TypeTest SPT Test psi 1500 - OA 80 100 1 100 100 Interval 4YRTST P/F P ' Tubing 2600 2600 2600 2600 Notes: 2.4 bbls pumped for test. " Tuesday, September 06, 2011 Page 1 of 1 • MEMORANDUM To: Jim Re ~ P.I. Supgr~visor ~~~ ~ ~ I© FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-22 KUPARUK RIV iJNIT 2Z-22 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~,"L Comm Well Name: KUPARUK RIV UNIT 2Z-22 Insp Num: mitCS100823062946 Rel Insp Num: API Well Number: 50-029-22524-00-00 Permit Number: 194-147-0 Inspector Name: Chuck Scheve Inspection Date: 8/22/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 22-22' Type Inj. ~'~' TVD ~ s81a IA 9zo zlso ztoo 2100 ' ~ 1941470 ' P.T.Di TypeTest SPT Test psi s] 00 QA 180 300 300 300 Interval axRTST p~F P Tubing 2sso 2sso 2sso 2sso Notes: pre-test pressures were observed for 30+ minutes and found stable. . Wednesday, August 25, 2010 Page 1 of 1 ~ ~ • . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: - ~ ~ ~ ~~:~~, r t~ '~ ?~~~ ~~:~~".~~~~ J ~ ~ ~~ ~~~~ ~~ ;~UV :t ~ ~~~~' ,~~~s~~: ~~~~ ~ ~~~s €~~a~~~ ~~~~maxs~~~ Anchorag~ I ~-i`~~ L~ ~~ ~ ~~ Enclosed please find a spreadsheef with a list of wells from the Kuparuk field (KRLn. 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 September 20~` and October 13~' 2009. The corrosion inhibitor/sealant was pumped October 15~' and 31St + November lst and 2nd 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ~incerely, 1~ Perry Klei~ ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 ~r. ~n ~~ tt ~K pa~ Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31 /2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 1~l15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/1/2009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 1111/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11/2/2009 2Z-03 50029209640000 18$0850 24" NA 24" NA 5.5 11/2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11/1/2009 2Z-74 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1/2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 7 6" NA 16" NA 5.95 11 /1 /2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11l2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor J1 Cl(' Vif b 1"- /C7 DATE: Wednesday, August 15, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-22 KUPARUK RIV UNIT 2Z-22 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv (]6?!2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2Z-22 API Well Number: 50-029-22524-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ070814104501 Permit Number: 194-147-0 Inspection Date: 8/13/2007 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ¡Type Inj. i N iTVD ! '1IA i ~ r I Well I 12-22 I 5814 i 1670 I 2320 ! 2270 I 2265 ¡ I I Y i i I I í ì P.T. ! 1941470 ¡TypeTest I SPT i Test psi I 1500 ',OA I 300 I 300 I 300 i 300 I I I I I , / P/F Tubing I i , i I : Interval 4YRTST P J 2850 2850 i 2850 2850 I Notes: 1.3 BBLS diesel pumped. I well house inspected; no exceptions noted. 5~SD AVE 2 3 2007 Wednesday, August 15,2007 Page 1 of I MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor IT' . ,._(;" r-, G'¢; ~,I '? vv { ( DATE: Wednesday, May 31, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA mc 2Z-22 KlJPARUK RIV UNIT 2Z-22 v( v\ 1 \~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: '7t>--, P.I. Suprv '- j.iX,- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2Z-22 API Well Number 50-029-22524-00-00 Inspector Name: Jeff Jones Insp Num: miDJ060530I64356 Permit Number: 194-147-0 Inspection Date: 5/30/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well : 2Z-22 ,Type Inj. I G i TVD i IA : 2440 I 3010 3000 2980 i 2970 i 5814 I I I : 1941470 : I I I i ! I P.T. TypeTest I SPT i Test psi 1500 OA 500 500 500 500 500 I : I -¡-- i -- Interval 4YRTST P/F P Tubing I 3800 I 3800 ! 3800 3800 3800 I I Notes 1.2 bbls diesel pumped. 1 well house inspected; no exceptions noted. t¡~\ \ J\.,-It'll. c.:.V (' ,t. :0«:- / vÙ g (\ /ìpe' h . C.[f'YH,Vl: SS~~... reU::..e<'-'-""\''';'T: ,,~ ,,/>";01" ' LI !7!"...,\ .J p,.eSSL~~¿ ! G ¿Jl,~·{Qt¡"<2 e"";1Z,,\)"I. S/'i2b ,'l\.6{'1c- Ci ¿ ¿t·~",hi L .77 H~ f- " presS V0 €. 3¿ÙJf~:';': ,--.--/,>'" l" ké~ .£15(C0 { , . "N¡:;;:f {~Ç:r\N .:.~"': 1 B 2C\l!r.:J Wednesday, May 31,2006 Page 1 of 1 (: f Mike Mooney ( Wells Group Team Leader . Drilling & Wells P. O. Box 100360 ~ Anchorage, AK 99510-0360 ConocoPh ill i pS Phone: 907-263-4574 December 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2Z-22 (APD # 194-147) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2Z-22. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Ij. d ~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 5 2004 Alaska Oil & Gas C C A ons. omm;ss;on ncharage SCÁ~NE[) JA~ 2 @ 2004 0 RIG I NA L ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. D Alter Casing D Repair Well D Plug Perforations D Stimulate 0 Time Extension D Other D Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 194-147/ 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22524-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 111' 2Z-22 8. Property Designation: 10. Field/Pool(s): ADL 25646, ALK 2577 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8340' feet true vertical 6276' feet Plugs (measured) Effective Depth measured 8114' feet Junk (measured) true vertical 6109' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 4325' 9-5/8" 4436' 3517' PROD. CASING 8219' 7" 8330' 6269' Perforation depth: Measured depth: 7784'-7814',7844'-7886',8047'-8057',8066'-8104' true vertical depth: 5870'-5892',5913'-5944',6060'-6068',6074'-6102' RE CE '\/E 0 . . JAN 0 5 2004 Tubing (size, grade, and measured depth) 3.5" /2-7/8", L-80 1 J-55, 7988' MD. Alaska Oil & Gas Cons Com' . Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; TIW'SS' pkr= 7706'; 7961' A h . miSSion sssv= NIP SSSV= 519' nc orage 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7977' Treatment descriptions including volumes used and final pressure: 720 bbls seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation n/a -- Subsequent to operation nla 9668 - - 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJ0 WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader Signature J J J A --' Phone Date I z¡ '2 2:-/0 3 ¡VI. IV! /.,v,- "\ Preoared bv Sharon AI/suo-Drake 263-4612 \ r \"Î""". \, i. " (J ',:\\\~;!.. .1 ':";",; I Form 10-404 Revised 2/2003 . 0 R ~ tltL suJÀNNijuPL8 ( ( ~PHILLIPS Alaska, Inc. KRlJ 2Z-22 ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY 2Z-22 NIP (519-520 API: 500292252400 Well Tvpe: INJ Anqle @. TS: 44 dea @. 7785 OD:3.500) SSSV Type: Cam?o 'D~' Orig Compltn: 2/5/95 Angle @ TD: 42 deg @ 8340 Landlna Nioole TUBING (0-7958, Annular Fluid: Last W/O: Rev Reason: Taq update. OD:3.500, ID:2.992) Reference Ref Log Date: Last Update: 10/17/00 Loa: Last Taa: 8114 TD: 8330 ftKB Gas Lift Last Tag 10/5/00 Max Hole 48 deg @ 2598 Mandrel/Dummy Date: Anqle: Valve 1 (7639-7640, Casing Strings- All OD:5.750) Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 SUR. CASING 9.625 0 4436 3517 40.00 L-80 NIP (7684-7685, PROD. CASING 7.000 0 8330 8330 26.00 L-80 OD:3.500) TubinaStrinas-AIi ....... .... ................... ...... ... ....... ...... ....... Description Size Top Bottom TVD Wt Grade Thread TUBING 3.500 0 7958 5996 9.30 L-80 EUE ABM TUBING 2.875 7958 7988 6018 6.50 J-55 EUE ABM : Perforations Summary I . PBR (7692-7693, Interval TVD Zone. Status, Ft :SPF Date Type Comment OD:3.500) 7784 - 7814 5870 - 5892 C-4 30 12 4/1/95 IPERF SWS 41/2" HSD HJ II, Spiral Phasina 7844 - 7886 5913 - 5944 C-2,C-1 42 12 4/1/95 IPERF SWS 4 1/2" HSD HJ II, Spiral Phasinq 8047 - 8057 6060 - 6068 A-5 10 4 4/1/95 IPERF SWS 41/2" HSD PKR (7706-7707 Ultrapac, 180 deg. . ' ohaslna OD.6.151) 8066-8104 6074-6102 A-4 38 4 4/1/95 IPERF SWS41/2"HSD Ultrapac, 180 deg. phasina Gas~Lift MandrelsNalves. St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv Injection Mfr Tvpe Run Cmnt valv~a~~;;~~~~~l 1. 7~39. 5766 Cameo MMG-2 DMY 1.5 RK 0.000 0 5/6/95 OD'6 018) Injection Mandrels/Valves .. . . St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv Perf (7784-7814) Mfr Type Run Cmnt 2 7751 5847 Camco MMM DMY 1.5 RK 0.000 0 4/3/95 Other (plugs, equip., etcJ -JEWELRY .. .. Depth TVD Type Description ID Perf (7844-7886) 519 519 NIP Camco 'DS' Landinq 2.812 - 7684 5799 NIP Camco 'W-1' Selective 2.812 - - 7692 5804 PBR Baker 3.000 7706 5814 PKR Baker 'FHL' 3.000 7943 5985 SLEEVE Cameo 'CB-1' Slidina (No Go Profile); Opened 12/4/99 2.750 SLEEVE (7943-7944 7961 5998 PKR TIW'SS' 3.250 OD:3.500) 7977 6010 NIP Otis 'XN' Nioole NO GO 2.250 798L~-JOS Bake!_____._---- 2.441 7988 6018 TTL 2.441 GeneralNotes . ...... ... Date Note PKR (7961-7962 10/5/00 Taaqed@8114' RKB. OD:6.151) 10/17/00 Schematic updated bv J.Peirce. TUBING (7958-7988, OD:2.875, ID:2.441) NIP (7977-7978, OD:2.875) SOS (7987-7988, OD:2.875) TTL (7988-7989, OD:2.875) Perf (8047-8057) . Perf (8066-8104) . - (' ( 2Z-22 Event History Date Comment 11/21/03 PUMP HPBD TO INCREASE INJECTION RATE INTO THE A SAND. PUMPED 720 BBLS OF 50 DEG SEAWATER @ MAX RATE POSSIBLE (6.8 BPM AVERAGE) @ 4000 PSI. PUMP 4 STAGES WITH 15 MIN SHUT DOWNS IN BETWEEN STAGES. [HPBD] Page 1 of 1 12/12/2003 MEMORANDUM TO: Randy Reudrich Commissioner THRU: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON- CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission ~/~/o:~ ~,~'r~: u~ ~4, 200~ SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 27 Pad 27-22, 27-23 KRU Kuparuk RiYer Field Packer Depth Pretest Initial 15 Min. 30 Min. I vv~"l ~-~ I~'~.1 ~ I*.''.~- I~ I*~1 ~°° I~°° I~°° I~°° I'~'~rv~'l ~ I P.T.D.I 1941470 Type testI P I TestpsiI 1500 I CasingI 1075I 2950I 2870I 2825I P/F I P I Notes: Test fluid: 3.5 bbls diesel. I Packer Depth Pretest Initial 15 Min, 30 Min. We,I 2Z-23 ITypelnj. P.T.D.I 195010 Type test N°tes: Test fluid: 2 bbls diesel. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details May 14, 2003: I'traveled to ConocoPhillips Alaska's Inc.'s (CPM) Kupamk River Field injection wells 2Z-22 and 2Z- 23, to' witness 4 year MIT's. Jared Break was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with both wells passing their MIT's. I inspected both well houses and no exceptions were noted. Summary: I witnessed successful MIT's on CPAI's water injection wells 2Z-22 and 2Z-23 in the Kuparuk River Field. Two well house inspections conducted. ,/// M.I.T.'s Performed: _2 Number of Failures' _0 Total Time during tests: _2 Attachments: Wellbore schematics (2) ~ cc: MIT report form 5/12/00 L.G. MIT KRU 2Z-22, 2Z-23 5-14-03 JJ.xls 5/20/2003 JUN t 9 2DD3 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 2Z-22 NIP (519-520, OD:3.500) TUBING (0-7958, OD:3.500, ID:2.992) Gas Lift Mandrel/Dummy Valve 1 (7639-7640, OD:5.750) NIP (7684-7685, OD:3.500) PBR (7692-7693, ~ OD:3.500) PKR (7706-7707, OD:6.151) KRU 2Z-22 APl:! SSSV Type: Annular Fluid: Reference Log: Last Tag: Last Tag Date: )NDUCTOR SUR. CASING PROD. CASING s JBING 500292252400 Camco 'DS' Landing Nipple 8114 10/5/00 All All TUBING ~erforations Interval TVD 7784- 7814 5870- 5892 7844- 7886 5913- 5944 - 8057 6060- 6068 8066 - 8104 6074- 6102 Well Type: Orig Compltn: Last W/O: Ref Log Date: TD: Max Hole Angle: INJ 2/5/95 8330 ftKB 48 deg @ 2598 7958' 7988 Angle @ TD: 42 deg @ 8340 Rev Reason: Last Update: 10/17/00 Thread Thread EUE ABM EUE ABM Comment SWS 4 1/2" HSD HJ II, Phasinq SWS 4'1/2" HSD HJ II, SWS 4 1/2" HSD Ultrapac, 180 deg. SWS 4 1/2" HSD Ultrapac, 180 deg. Injection Mandrel/Dummy Valve 2 (7751-7752, OD:6.018) Perf (7784-7814) ---- Perf (7844-7886) -- SLEEVE (7943-7944, OD:3.500) Gas :Lift MandrelsNalveS: ection MandrelSNalves , :;,jEWELRY DescriPtion NIP Camco 'DS' Landing NIP Camco 'W-I' Selective PBR Baker PKR Baker 'FHL' Camco 'CB-I' Sliding (No Go Profile); Opened 12/4/99 'SS' Otis 'XN' Nipple NO GO Baker PKR (7961-7962, OD:6.151) TUBING (7958-7988, OD:2.875, ID:2.441) Note 8114' RKB. Schematic updated by J.Peirce. NIP (7977-7978, OD:2.875) SOS (7987-7988, OD:2.875) TTL (7988-7989, OD:2.875) Perf (8047-8057) Perf (8066-8104) ARCO Alaska, Inc./ NIP (493-494, -- 0D:3.500) NIF (7289-7290, 0D:3.500) PBR (7299-7300, OD:3.500) PKR (7313-7314, OD:6.151) Ped (7400-7418) Ped (7445-7495) SLEEVE (7553-7554, OD:3.500) PKR (7571-7572, OD:6.151) GKA 2Z-23 2Z-23 APl: SSSV Type: Annular Fluid: Reference Log: Last Tag: Size 16.000 Size 9.625 500292254400 Well Type: I INJ I Camco 'DS' LandingI Odg Completion: 2/12/95 Ref Log Date:I 17716 I Max Hole An;IDel 7972 ffKB 43 deg (~ 6372 13/25/00 CONDUCTOR Top I Bottom TVD 0 121 121 - SURFACE Top I Bottom I TVD 0 4242 3465 PRODUCTION Size Top Bottom 'FVD 7.000 0 7960 6232 Size 3.500 2.875 - TUBING Top BOttom TVD 0 7568 5933 7568 7597 5955 :SUmmary Angle ~ TS: 142 de~ @ 7401 Angle @ TD: 40 deg @ 7972 Rev Reason: Tag fill, close CB-1 by ImO Last Update: 3/26/00 Wt Grade Thread 62.58 H-40 Wt Grade Thread 40.00 L-80 Wt Grade Thread 26.00 L-80 Wt GradeI Thread 9.30 L-80 EUE ABM 6.50 J-55 EUE ABM Interval TVD Zone Status Feet SPF Date Type Comment 7400 - 7418 5807 - 5821 UNIT 18 12 3/30/95 IPERF 30 deg. phasing, SWS 4 1/2" HSD HJ 7445- 7495 5841 - 5879 -3,C-2,C- 50 12 3/30/95 IPERF 30 deg. phasing, SWS 4 112" HSD HJ II 7678-7688 6017-6025 !A-5 ~ I 101 413/30/95 IPERF 180 deg. phasing, SWS 4 1/2" Ultrapac 7696- 7726 6031 -6054 !A-4 ~ I 301 413/30/95 IPERF 180 deg. phasing, SWS 4 1/2" Ultrapac 7750- 7770 6072-6087 !A-3 ~ I 201 4 3/30/95 IPERF 180 deg. phasing, SWS 4 1/2" Ultra[ac 7804- 7809 6113 - 6117 !A-3 ! I 51 4 3/30/95 PERF 180 deg. phasing~ SWS 4 1/2' U trapac GaSLiff.!Mand:telSNal~e~ ~: : :: : .; . 'V~v Comment -2 '" ~;~" 577~ '~'rn~o ................. MMM b-I~l~; ......1':5 ..... R'K"' ~):~)-0-~.'--~ :~'~)[ ...... N~t~ NIP NIP ~.).: J.E. WELRY Description Camco 'DS' Landing Camco 'W-I' Selective 2.812 2.812 PBR Baker 3.000 PKR Baker 'FHL' 3.000 SLEEVE Camco'CB-l' Sliding SLeeve (No Go Profile); CLOSED 3/25/2000 TIW 'SS' Otis 'XN' Nipple Baker PKR NOGO 2.750 3.250 2.250 SOS 2.441 TTL 2.441 Partial obstruction see 2/1 NO GO (7587-7588, 0D:2.875) TUBING (7568-7597, OD:2.875, ID:2.441) Perf (7678-7688) Perf (7696-7726) Ped (7750-7770) Ped (7804-7809) 9 a. ,,- 'i a. 7 C i.!!, L 9 a. --- t ~.~- ? C D N ./'D S ~--f:~ 6200~-8 'i 66 ~-'~'~400 .... 830 (..') 94 ,,~ 14 '? C, D R / D S ~ 4 400 ~ 8 ?~ 00 94 ..~ 14 ? U S l T ~ 6200 ..-- 8 "i 90 i Date" i 2,/'{) 'i ,/96 A r' eci r' y ci 'i' 't: c h ss a m p I e s t' e q u '~' r' e d ? y e s EiZ~__.~ d r" e c e "i v e d 2 v e Was the we'l'l cor'ed? yes I(~_____&na'i ys'i's & descr'i'is't-i'on r'ece-'l vet!',' y~ A r' e we i i We i i :' s C 0 k'l k~i E N T S ,alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 7, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2Z-22(Permit No. 94-147) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent 22. operations on KRU 2Z- Sincerely, M. Zanghi Kuparuk Drillsite Development Supervisor MZ/skad RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~v, iSSION WELL COMPLETION OR RECOMPLETION REPORT; N.D LOG 1 Status of Well Class#loalJo'¢n Of ,De~ic~e Well - /' i b~' '~ '"' . OIL [~ GAS ~] SUSPENDED r'-'] ABANDONED [] SERVICE r~ Classification chanc,:jod t0'WA~Ihk,fECT.,OR ' ? -.,. 2 Name of Operator 7 Permit Number ~' ?~ :-.~.... ARCO Alaska. Inc 94-147 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 50-029-22524 4 Location of well at surface 9 Unit or Lease Name 1444' FSL, 1' FEI., SEC. 11, TllN, ROE, UM i Kuparuk River Unit At Top Producing Interval ! ~~;, 10 Well Number 2Z-22 i.i .. [ 2404' Flqk, 392' Fl::k, 8o¢. 12, T11lq, R9E, UM KUPARUK RIVER § Elevation in foot {indicate KB, DF, etc.} 6 Lease Designation and 8~dal I~. RKB 111' Pad 70.4' ADL 25646 ALK2577 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions Jan. 29, 1995 Feb. 3, 1995 03-Apr-95I NA feet MSL 1 8340' MD & 6277' TVD 8241' MD 6203' TVD YES r'~ NO ~ NA feet MD 1370' ss APPROX 22 Type Electric or Other Logs Run GR, CDR, CDN, CCL, USIT, CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE ~ PECORD 16" 62.5# H-40 Surf 121' 24" +_200 sx ASI 9-5/8" 40~ L-80 Surf 4436' 12.25" 930 sx ASIII Lead, 490 sx Class G Tail 7" 26# L-80 Surf 8330' 8.5" 310 sx Class G Tail 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD intervaJ, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.3#, J-55 7989' 7693' & 7961' 12 SPF 7784'- 7814' MD 5870' - 5892' TVD 12 SPF 7844' - 7886' M D 5913' - 5944' TV D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 SPF 8047' - 8057' MD 6060' - 6068' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 SPF 8066'- 8104' MD 6074' - 6102' TVD 27 PROOUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tasted PROOUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FlowTub~ng Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL OILGRAVITY-API (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fTacturas, apparent dips and presence of oil, gas or water. Submit core chips. EC£1VED d U N - 9 1995 Atgs,'ka 0ii & Gas Cons. Commission ^nchor~ -' Form 10-407 Submit in duplicate Rev. 7-1-80 ~ON REVERSE SIDE 30. GEOLOGIC MARKER FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7785' 5871' Base Kuparuk C 7886' 5944' Top Kuparuk A 8036' 6052' Base Kuparuk A 8180' 6158' REC[IV D ,/UN -9 1995 31. LIST OF AI-DACHMENTS AlaSka 0ii & GaS Cons. C0mmissi0rl Anchor:., 32. I hOr~by certify that the foregoing is true and correct to the best of my knowlege. Signed I~. C,~,~ Titlo""~ ~"~"&' ~ S~ATE ~:~/~I~j/~S'~'''' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date:06/01/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2Z-22 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8071 AFE: AK8071 TYPE:DEV AFE EST:$ 1200M/ 700M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-029-22524 FIELD: KUPARUKRIVER FIELD SPUD:01/29/95 START COMP: FINAL: 01/27/95 (1) TD: 0'( 0) SUPV:JT 01/28/95 (2) TD: 0'( 0) SUPV: JT 01/29/95 (3) TD: 0' ( 0) SUPV: JT 01/30/95 (4) TD: 2131' (2131) SUPV: JT 01/31/95 (5) TD: 4450'(2319) SUPV:JT 02/01/95 (6) TD: 4450'( 0) SUPV:RLM 02/02/95 ( 7) TD: 6034' (1584) SUPV: RLM MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG DOWN PAD Phase 3 weather conditions until 08:00 hrs 1/26/95. Roads & pads completed cleaning pad. Released rig from non-standard move rate. DAILY:S89,864 CUM:$89,864 ETD:SO EFC:$1,289,864 MW: 0.0 RIG MOVE Turnkey move in progress. DAILY:S122,251 CUM:$212,115 PV/YP: 0/ 0 ETD:SO APIWL: O. 0 EFC:$1,412,115 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREPARING TO SPUD Rig accepted 1/18/95 @ 1700 hrs. Start mixing mud and PUDP. DAILY:S53,045 CUM:$265,160 ETD:SO EFC:$1,465,160 MW: 10.0 PV/YP: 18/20 APIWL: 8.6 DRLG SURFACE HOLE Spud well & drld 12.25" hole f/121' t/464'. Drld t/2131'. DAILY:S87,641 CUM:$352,801 ETD:SO EFC:$1,552,801 MW: 10.0 PV/YP: 18/16 APIWL: 8.2 POOH TO RUN CASING Drld f/2131' t/4443'. Hole tight coming out of hole. Reamed bridge and tight spots. Drill t/4450'. POOH. DAILY:S112,487 CUM:$465,288 ETD:SO EFC:$1,665,288 MW: 10.0 PV/YP: 14/ 7 APIWL: 7.2 NIPPLE UP Rig up to run 9.625" casing. Ran casing to 4435'. Cement casing, CIP ar 2123 hfs 1/31/95. Rig up to do top job. Flushed annulus with 37 bbls water, topped off with 31 bbls. AS3 with 12.1 ppg returns to surface. CIP @ 0037 hrs. 2/1/95. Nipple up 13-5/8" BOPE. DAILY:S196,430 CUM:$661,718 ETD:SO EFC:$1,861,718 MW: 8.7 PV/YP: 6/ 6 APIWL: 18.6 DRILLING Test all BOP equipment. Pick up BHA and RIH to 4300'. Test casing to 2000 psi. No bleed off. Drill float collar at 4348', cement, float shoe at 4435' and 10 new hole to 4460'. Circ. hole clean. Directional drill 8.5" hole from 4460' to 6034'. DAILY:S92,053 CUM:$753,771 ETD:SO REf~V~D3'771 Date: 06/01/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT 02/03/95 (8) TD: 7980' (1946) SUPV:RLM MW: 11.3 ?V/YP: 26/14 APIWL: 4.7 DRILLING Directional drill 8.5" hole from 6034' to 7980' DAILY:S115,665 CUM:$869,436 ETD:SO EFC:$2,069,436 02/04/95 (9) TD: 8340'(360) SUPV:RLM MW: 11.3 PV/YP: 23/12 APIWL: 4.5 POOH TO RUN 7" CASING Directional drill 8.5" hole from 7980' to 8340'. DAILY:S77,067 CUM:$946,503 ETD:SO EFC:$2,146,503 02/05/95 (10) TD: 8340'( 0) SUPV:RLM MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 CLEAN MUD TANKS Run 7" casing to 8330'. Cement casing. CIP at 2247 hrs. 2/4/95. Set packoff and nippled up tubing spool. Freeze protect 9.625" x 7" annulus. DAILY:S218,842 CUM:$1,165,345 ETD:SO EFC:$2,365,345 02/06/95 (11) TD: 8340'( 0) SUPV:RLM MW: 0.0 PV/YP: 0/ 0 RIG RELEASED 930 HRS 2/5/95 Rig released at 0930 hrs. 2/5/95 DAILY:S76,456 CUM:$1,241,801 ETD:SO APIWL: 0.0 EFC: $2,441,801 REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8071 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8071* TYPE:DEV AFE EST:$ OM/ OM STATE: API NUMBER: START COMP: FINAL: 04/01/95 (12) TD: 8340' PB: 8241' SUPV:DEB PERFORATING MW:ll.4 NACL/NABR Accept rig @ 2130 hrs, 3/31/95. Test 7" casing, OK. Perforate 'A' sand. DAILY:S23,473 CUM:$23,473 ETD:SO EFC: $23,473 04/02/95 (13) TD: 8340' PB: 8241' SUPV:DEB 04/03/95 (14) TD: 8340' PB: 8241' SUPV:DEB 04/04/95 (15) TD: 8340' PB: 8241' SUPV:DEB RUNNING 3-1/2" COMPLETION ASSEMBLY MW:ll.4 NACL/NABR Continue perforating 'A' and 'C' sands. Set packer/ tailpipe assembly. Run 3-1/2" selective single completion assembly. DAILY:S92,703 CUM:$116,176 ETD:SO EFC:$23,473 POH with 3-1/2" COMPLETION ASSEMBLY MW:ll.4 NACL/NABR Finish running 3-1/2" selective single completion assembly. Problem with pressure testing. DAILY: $36,220 CUM: $152,396 ETD:SO EFC: $23,473 RIG RELEASED MW:ll.4 NACL/NABR Re-run 3-1/2" selective single completion assembly with new PBR/'FHL' Packer assembly. Set packer. Freeze protect ann- ulus. Test packoffs. Test tree. Secure well. Release well @ 2000 hrs, 4/3/95. DAILY:S101,464 CUM:$253,860 ETD:SO End of WellSummary for Well:AK8071 ' "0 A!g. sk~, Oil & Gas Cons. Cc:remission PAGE . ~*,******** SUR~£Y PROGRAM DDMPANY ARCO ALASI<A WELL NAME 2Z-22 LCCATION I I(UPAR~i LOCATION 2 ALASRA MAGNETIC DECLINATION 28~68 GRID CONVERGENCE ANGLE 0,00 ~T~: 03-FEB-?5 W£~ NUMBER 0 ,H ICROFILMED W~LL HEAl) LOCATION: LAT(N/-S) 0,~ DEP(E/-W) 0,00 AZIMLrJ'H ~3M E~TARY TABLE TO TARGET IS 73,f? TIE IN F~]INT(TIP) : MEASURED D~.PTH 121.00 ~UE V~E'I' D~PTH i21,00 INCLINATION 0,00 AZIM~]TH 0.00 ' LATITU~E(N/-S) DP-PARTU~(E/-W) 0.00 ORI®INAL PAG£ NO, M~4SUR~D INTERVAL V~E~ICAL ~PTH ~EP~ ft ft ft 121,00 0,0 121,00 347.00 226,0 347,00. 466,89 119,9 466,88 555,89 90.0 556,72 646,74 8%? 646,09, 7.~,24 829,01 920.85 1011.01 1101,21 1197,60 1291,31 1386,33 1478,~ 1573,99 1667.18 1761.80 1854,94 1949,76 2135,75 2322,69 25?7.58 2878,89 3159.66 3440,14 3721,30 4{)03,21 4354.44 4607.19 4791,93 5352,34 5634.02 590q,74 6193,83 6472,23 6753.03 7034,59 7313.91 7595.04 92,5 737.98 89,6 826,95 91.8 917.45 90,2 . 1C05.83 90,2 109'3,15 96,4 1184.42 93,7 1271,05 95,0 1356,48 91,9 1435,49 ~.6 1517,53 ?3,2 1594,36 94,6 1669,64 93,1 1740,97 94,8 1811,04 186,0 1941,70 186,? 281.3 2444.03 280,8 2634,35 280,~ 2826,82 281.2 3021,45 281.9 3217,34 3~1,2 3460.04 252.7 ~35.26 184,7 3764,00 280.7 3960.41 279,7 41~7,53 281,7 4~55,69 275,7 4547,85 284+1 4744,86 278.4 4938.78 280,6 5136,12 281,6 5335~81 279,3 .5534.48 281.1 5734,74 ************* ANAl)RILL aRVEY CALCULATIONS ************* CIRCULAR ARC TARGET STATION AZtMU~H S~C?ION INCIJi. N/-S ft deg deg ft 0,00 0,00 0,00 O,OC 0.6i 0,50 22.00 0,~1 2,00 1.14 99.94 1,19 6,46 5,17 99,78 0.35 15.11 6,67 90,2? 2Z-22 D£PARII]R~ DISPLACEMENT at ~-W ft ft 0;00 0,00 0,37 0,99 1,74 2,11 6.62 6,62 15.83 !5,83 ' AZIMUTH deg 0,00 22.00 55.52 86,97 91.32 bLS deg/ lOOft 0,00 0.22 0,95 4,48 Io99 25,53 6,58 81.29 0.41 26.44 26.45 89.11 1.13 37,37 8,67 78,76 2,5I 38.I6 36,24 86,24 2.35 52.88 10.84 78,32 5.61 53,41 53,70 84.01 2,37 70,72 t2.04 77.59 9,34 70.90 71,51 82,49 1.33 93,15 16,80 75,14 14.71 92.69 93,85 80.98 5,32 124,07 20.70 78,7? 21,60 159,64 24,10 79,07 28,45 201,03 27,76 78.67 36,47 246,06 31,14 78,65 45,36 2?6,?3 33,23 349,61 35,71 ~,94 67.93 406,89 38,85 75.38 82,1S 466.73 41,17 76,46 96,68 5~,51 43,53 77.~ 111,I4 662,78 47,22 73,19 144.92 7~9.41 46.71 73,12 184.51 1001,56 48.05 77.18 236,26 1210.01 47.76 76.80 283,~ 1416,35 46.93 71,45 33%64 1620.32 46.42 /-"5,33 ~7.97 1823,21 45,97 73,83 451,92 2025.79 46,02 77,60 50!.5~ 2279,42 46,57 75,28 560,71 2461.55: 45.66 73.28 610.04 2594,04 45,9'? 73,03 648,45 122,87 124,76 80.03 157.92 160,46 79.79 198,68 202.00 79,60 242.97 247.17 79.43 292,89 298,16 79,20 3.63 3,85 3,68 2,26 344,22 350,86 78.84 2.85 399,74 408,09 76,39 3,34 457.82 467,92 78,08 2,60 520,03 531,78 77,94 2,57 .H7,94 663,95 77,3? 2,54 776,72 800,28 76,67 0,28 974,18 1002.42 76.37 1.19 I177,56 I211,15 76,47 0.15 1376,05 1417,35 76,14 1,43 1571,51 1621.12 75,79 1,02 1767.11 1823,98 75,65 0,42 1963,61 2026,67 75,67 1,01 2210,51 2'280,51 75./7 0,54 2385.84 2462,59 ~,66 0,66 2512,65 2594,97 75.53 0,21 2704,27 2795.28 75,34 2893,11 29~3,45 75,12 3082,28 3193,13 74,86 3269,11 33?0,40 74,63 3463,87 3594.90 74,48 2794,51 45.20 72.72 707,49 2992,86 45.20 71,44 766,55 31'92,76 45,39 70,37 634,~ 3390,19 46,25 71,42 898.74 3~94,76 45.94 72,74 961,72 3794.47 45.75 72,83 I020.83 3994.16 44,95 72,35 1080,55 4~.2,59 44,~ 72,47 1140,58 4368,79 44,61 71.19 1201,6C 4585.86 44,54 71.~' '"~ ~' 3654,67 3794,56 74,3? 3845.28 3994,22 74.30 4034,50 4192,63 74.21 4221.04 4388,80 74,11 4407,78 4585,86 73,98 0,2? 0,32 0,26 0,42 0,35 0,07 0,31 0,09 0.32 0,03 PA~E NO, 3 **********~** ANADRILL SURVEY C+qLCLP~ATIOHS ************* CIRCULAR ARC MIiASURIE) INTBRVAL '~ER?ICAL T~q~r STATION AZIMUTH D~J~ll4 DI-~'HH SECTION INCLN, N/-S ft ft ft ft deg deg ft 7874,78 27?°.7 5935,37 4780°53 43,81 70,84 132~,05 8061.59 186,8 6070,98 4908,81 43,10 70,81 1371,24 8235,93 174,3 619"Y,2'~' .~26,65 42,12 70,70 1410,14 The final su;~vey is an extrapolation to ~ of last Anadrili MWD survey, 83~,00 104,1 6276,48 5096,33 42,12 70,70 1433.21 2Z-22 D~A~qqJR£ DISPLACt~NT at AZIMUll~ DLS ft ft d~ lOOft 4592;~ 4780,~ 73,~ 0,27 4713,43 490~,84 73.78 0,38 ~24,~ 5026.71 73,71 0,56 4890,74 5096,41 73.67 0,00 ARCO Alaska, Inc. Date: March 24, 1995 Transmittal #: 9216 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. g' gl/-- ,/5~1 R-33 ¢/.q... j' ¢o ~ 1 R-34 ,~d-I.E, 2T-21 ?5--"/,.3' 2T-21 <:/~- l/--/-&l R-32 2Z-23 ~5'-' / O 2Z-23 ,¢~/,./z ,, ,,.~Z-22 ~ CDR Depth Shifted · Acknowledged ,/ ' CDR Final Pdnt CDR Final Pdnt CDR Depth Corrected CDN Depth Corrected Slim GR MWD Depth Corrected CDR Depth Shifted CDN Depth Shifted · 12/28/94 1/13/95 Feb16-21/95 Feb16,21/95 Dec11-14/94 Feb7-'l 0/95 Feb7-10/95 Feb1-4/95 Feb1-4/95 Date' Ref#95009 Ref#95060 Ref#95077 Ref#95077 Ref#95024 Ref#50-029-22544 Ref#50-029-22544 Ref#50-029-22524 Ref#50-029-22524 DISTRIBUTION' Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO-1205 RECEIVED MI~R 3 0 1995 Clifton Posey Ge&l~ 0il & Gas Cons. Con]mis,ion ATO 1251 Anchorage Erickson/Zuspan NSK Central Files NSK 69 -'..~'ljarry Grant (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy Lemke ATO 1336 ARCO Alaska, Inc. Date' March 3, 1995 Transmittal #: 9205 RETURN TO: ARCO Alaska, Inc. ATTN: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items, receipt and return one signed copy of this transmittal. 2Z-23 2Z-23 2Z-22 Kuparuk River Unit 2/20/95 Cement Bond Log CBT Kuparuk River Unit 2/20/95 Ultrasonic Imager Cement Log USIT KuParuk River Unit 2/21/95 Cement Bond Log CBT Kuparuk River Unit 2/21/95 Ultrasonic Imager Cement Log USIT DISTRIBUTION' Sharon Alisup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 5850-7788 5850-7816 6200-8166 6200-8190 RECEIVED MAR 7 1995 Alaska 0ii & Gas Cons. Commiss]0_n Erickso~:~ NSK Central Files NSK-box 69 ALAS~ OIL AND GAS ' CONSERVATION COMMISSION r TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 20, 1995 Michael Zanghi, Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-03 60 Re: Kuparuk River Unit 2Z-22 ARCO Alaska, Inc. Permit No: 94-147 Sur. Loc. 1444'FSL, I'FEL, Sec. 11, T11N, R9E, UM Btmhole Loc. 2433'FNL, 392'FEL, Sec. 12, T11N, R9E, UM Dear Mr. Zanghi: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated November 18, 1994 are in effect for this revision. cDlal;irdmWar~ Johns BY ORDER OF THE COMMISSION dlf/Enclosures Department ofFish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [--] Deepen [] Service E] Development Gas D Single Zone X Multiple Zone E] ~'.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 70.4' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25646, ALK 2577 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25,025) 1444' FSL, 1' FEL, Sec. 11, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2537' FNL, 756' FEL, Sec. 12, T11N, R9E, UM 2Z-22 #U-630610 At total depth 9. Approximate spud date Amount 2433' FNL, 392' FEL, Sec. 12, T11N, R9E, UM 1/23/95 $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 2Z-09 8358' MD 392'~ TD feet 13.6' ~b 525' MD feet 2560 6309' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 46.2° Maximum surface 2086 psig At total depth (TVD) 3350 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' ___200 CF 12.25" 9.625" 40.0# L-80 BTC 4376' 41' 41' 4417' 3523' 850 Sx Arcticset III & HF-ERW 510 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 831 7' 41' 41' 8358' 6309' 290Sx ClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCZ~dacU;TMR E C E IV E D Intermediate ProductionJAN 1 5 199,5 Liner Perforation depth: measured Alaska 0ii & Gas Cons. Commission true vertical Anch0ra~e 20. Attachments Filing fee E] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot I--I Refraction analysis [--I Seabed report El 20 AAC 25.050 requirements X 21. I hereby certify that the forecloing( is true and correct to the best of my knowledge Signed ~.~.,. ~.=~ .,)~ Title Drill Site Develop. Supv. Date /-,' ('~ _ ' Commission Use Only Permit Number ~50q number I Approval date/,.(~ ¢. I See cover letter for 94-147 - 029-22524 //.~- .---p other requirements Conditions of approval Samples required [--I Yes [~l No Mud Icg required El Yes ,~ No Hydrogen sulfide measures ,~ Yes I--1 No Directional survey required [] Yes [-] No Required working pressure for BOP• [] 2M [~ 3M [] 5M [] 10M [] 15M Other: Original Signed By David W. Johnston by order of / / Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 S~-bmi{ in triplicate KRU 2Z-22 Attachment to Form 10-401 Changed KRU Target Location ARCO Alaska, Inc., submitted a Permit to Drill for KRU Well 2Z-22 in November 1994 which was approved for a potential spud date of 12/1/94. The well was afterwards delayed until later in the drilling program and is now scheduled for late January 1995. In the time since approval, the Kuparuk target location of this well has been moved approximately 428' to the west to provide better access to oil reserves. Per telephone conversation with Mr. Bob Crandall at the AOGCC (1/6/95), a new Form 10-401 and directional plat are being submitted for substitution into the original Permit to Drill application. While the specific depths, etc., have changed slightly, the basic information provided in the other attachments to the original Permit to Drill is still correct. If you have any questions or comments regarding the attached, or the overall development program for Kuparuk Drill Site 1R, please contact the Drilling Engineer for Parker 245, Denise Petrash at 263-4183; or the Kuparuk Drill Site Development Supervisor, Mike Zanghi at 265-6224. Thank you for your expedient response to this request. Gas Cons. Commisstor~ Anchora.ie iCreated by ' jones For: 1) PETRASHi iDate plotted - 24-Nov-94 i iPIot Reference is 22 Version #7. ¢i iCoordinotes ore in feet reference slot #22.i iTrue Vertical Depths ore reference RKB. Baker Hughes INTEQ ARCO ALASKA, Structure : Pod 2Z Well : 22 Field : Kuparuk River Unit Location : North Slope, Alaska E a s f - - > 350 0 3.50 700 1050 1400 1750 2100 2450 2800 .3150 .3~)O 5850 4200 4550 4900 I I I I J I I I J I J I I I I I I I I I [ t I I I I I I I [ I - 600_ 900_ 1200_ - 1500_ - 1800_ _ 2100_ _ 2400_ - 2700_ _ 3300_ _ 3600_ _ 3900_ _ 4200 _ _ 45O0_ _ 4800_ _ $1O0_ _ 5400_ 57O0 _ _ 6000_ _ 6300_ ESTIMATED SURFACE LOCATION: ES'TI,~C.TED RKB ELEYATION: 113' 1445' FSL, 1' FEL SEC. 11, Tl lN, RgE 12.00 BUIm .3 D£(~ / lOO' 2433' FNL, 392' FEL SEC. 12, T1 1N, RgE J 15.00 \__~[' 21.0024.0030.00 PERMAFROST1VD:1483 TMD=1533 DEP=272 1, TARGET LOCATION: 27.00 25,37' FNL, 7,.56' FEL ~ 33'008/ SEC.12, T11N, RgE X, 39,oo TARGET 'hR 42.00 1VD=5858 TMD=7769 '~0 EOC TVD=IB?9 TMD=2040 DEP=SBB DEP=4707 NORTH 1298 EAST 4525 BS TVD:2163TMD=2451 DEP=885 N 73.99 DEG E 4707' (TO TARGET) x,k,,,,,N28AK SND$ TVD=2865 B,4D=$485 DEP=1615 WSAK SNB8 TVD=3323 1MD=4128 DEP=2095 9 5/8" CS(;; PT 'g/D=5525 1~dD=4417 OEP=2304 K-lO 1VD=5688 -fMD=4655 DEP=2476 MAXIMUM ANGLE 46.21 DEC K-5 WD=4938 TMD=6462 DEP=3780 RECEIVED BEGIN ANGLE DROP '1WD=5556 TMD=7554 DEP=4424 DROP 1.5 DEC / 100' TARGET - T/ ZONE C (EOD) TVD=5858 TMD=7769 T/ ZONE A TFD=6048 TMD=8017 DEP=4867 B/ KUP SNDS TVD=6156 TMD=8158 TD / ?" CSG PT TVI)=630g TMI)=8358 DEP=5086 JAN 1 3 1995 Aiaska Oil & Gas Cons. Commission Anchora._e 66OO I I I I I I I I I J I t t I I I I I I I I I I I I I I I I I I I 300 0 300 600 900 12100 1500 1800 2100 24100 2700 3000 .3300 .3600 3900 4200 ¢500 4800 Scale 1 : 150.00 Verfical Section on 7.3.99 azimufh with reference 0.00 N, 0.00 E from slot #22 45.00 425.50 42,00 I I I 5100 5400 5250 f1750 1400 1050 550 TARGET ANGLE 40 DEC A I November 18, 1994 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Kuparuk River Unit 2Z-22 ARCO Alaska, Inc. Permit No: 94-147 Sur. Loc. 1445'FSL, i'FEL, Sec. 11, TllN, R9E, UM Btmhole Loc. 2424'FNL, 38'FWL, Sec. 7, TllN, R10E, UM Dear Mr. Zanghi: EnClosed is the approved application for permit to drill the above referenced well. The permit to drill dOes not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf/Enclosureg cc; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. r.~ printed on recycled paper STATE OF ALASKA -' ~ AL,-,dKA OIL AND GAS CONSERVATION COMMi,... ON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill D lb Type of Well Exploratory [] Stratigraphic Test [] Development oil X Re-Entry r~ Deepen [~] 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 41', Pad 72' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25646, ALK 2577 4. Location of well at surface 7. Unit or property Name I 1. Type Bond (see 20 AAC 25.025) 1445' FSL, 1' FEL, Sec. 11, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2521' FNL, 328' FEL, Sec. 12, T11N, RSE, UM 2Z-22 #U-630610 At total depth 9. Approximate spud date Amount 2424' FNL, 38' FWL, Sec. 7, T11N, R10E, UM 1 2/1/94 $200,000 1 2. Distance to nearest 13, Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rvD) property line 2Z-09 8664' MD 38'@ TD feet 13.6' ~ 525' MD feet 2560 6306' TVD feet t6. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 49.3° Maximum surface 2086 psig At total depth (TVD) 3350 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD 'TVD MD '[¥D {include sta(~e dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 40.0# L-80 BTC 4516' 41' 41' 4557' 3523' 850 Sx Arcticset III & HF-ERW 510 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 8623' 41' 41' 8664' 6306' 290 Sx ClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth cS~nU;:~rt~lr R E C ElY E b Surface Intermediate Production I'k]0v 'I ¢O '!99 Liner Perforation depth: measured ¢,,~ ¢;o~,~, - -. & 6~,s C0nq. true vertical Ar~ch0rc 20. Attachments Rling fee X Property plat E~ BoP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r~ Refraction analysis r-] Seabed report r~ 20 AAC 25.050 requirements X 21. I hereby certi[y thatt~ for~oingi~ue and correct to the best of my knowledge Signed ~r~J~/~ / CommissionTitteuse Only Drill Site Develop. Supv. Date/~/~, 7x-l?? I~0-o2--7-- 22"~"2"~2 [/ / ~f~ '- (~Z;~'/~' - -" other re(~uirements Conditions of approval Samples required E] Yes [] No - Mud log required r-] Yes [] No Hydrogen sulfide measures [~ Yes E] No Directional survey required ~ Yes E] No Required working pressure for BOPE [] 2M ~ 3M [] 5M E] 1OM E] 15M Other: ORl(~llt, lAt- SIGNED 8Y RUSSELL A. DOUGLASS by order of// Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2Z-22 . , . 10 11 12 13 14 15 16 17 18 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,557')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test caSing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8,664') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 2Z-22 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,086 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2Z-22 is 2Z-9. As designed, the minimum distance between the two wells would be 13.6'@ 525' MD. 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 hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping. /~iisks in the 2Z-22 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost c rculation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.3 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED Casing Design/Cement Calculations 14-Nov-94 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, A3 Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2Z-22F 4,557 ft 3,523 ft 8,664 ft 6,3O6 ft 3,546 ft 8,075 ft 5,855 ft 3350 psi 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe = {(13.5'0.052)-0.11}*TVDshoe =[ 3,523 ft 2,086 psiJ Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 3,350.0 ppg 5,855 ft 100 psi 11.3 pp__~ Surface lead: Top West Sak, TMD = 3,546 ft Design lead bottom 500 ft above the Top of West Sak = 3,046 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,004 cf Excess factor = 65% Cement volume required = 1,656 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 850 sxJ Surface tail: TMD shoe = 4,557 ft (surface TD- 500' above West Sak) * (Annulus area)= 473 cf Length of cmt inside csg - 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 507 cf Excess factor = 15% Cement volume required: 583 cf Yield for Class G cmt = 1.15 Cement volume required =[ 510 sxI Casing Design / Cement Calculations Production tail. 14-Nov-94 TMD = 8,664 ft Top of Target, TMD = 8,075 ft Want TOC 500' above top of target = 7,575 ft 5" casing tail top (100' above C sand) =[ 8,664 ftJ 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 190 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.0997 Cmt required in casing = 8 cf Total cmt = 198 cf Excess factor = 75% Cement volume required = 347 cf Yield for Class G cmt = 1.19 Cement volume required =1 290 sxI TENSION - Minimum Design Factors are' T(.Db)=I.5 and Tfjs)=1.8 Surface (Pipe Body)' Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud _ - Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 916000 lb 4,557 ft 40.00 Ib/ft 18228O.0 lb 30722.4 lb 151557.6 lb 6.0J 979000 lb 4,557 ft 40.00 Ib/ft 182280.0 lb 30722.4 lb 151557.6 lb 604000 lb 8,664 ft 26.00 Ib/ft 225264.0 lb 38498.3 lb 186765.7 lb 3.21 667000 lb 8,664 ft 26.00 Ib/ft 225264.0 lb 38498.3 lb 186765.7 lb Casing Design/Cement Calculations BURST- Minimu.m...Design Factor = 1,1 Surface Casing- Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =l COLLAPSE- Minimum Design Factor =..1,0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9,0 # Mud 2, Ext, Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 14-Nov-94 5750 psi 2085.6 psi 2.81 7240 psi 7216 psi 2918 psi 4297 psi 3090 psi 0.589 Ib/ft 1140 psi 2.7J 5410 psi 0.589 Ib/ft 3716 psi 1.51 Casing Design / Cement Calculations 14-Nov-94 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burst 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 .L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi !Created by ' jones For: D PETRASH] !Date plotted : lO-Nov-94, iPtot Reference is 22 Version #6. i !Coordinates ore in feet reference slot #22.i !True Vertical Depths ore reference RKB. Baker Hughes INTEO --- i 55o I I Y o 1500_ _ 1800_ _ 2100_ . 2400_ - 2700_ - 3000_ - 5300_ -- 5600 3900_ -- 4200-- - 5400~ 6000_ 62,00 300 0 300 Scale 1 : 150.00 ARCO ALASKA Structure : Pod 2Z Field : Kuporuk River Unit , Inc. Well: 22 Location : North Slope, Alaska ~oo.~,: ,~.oo E a s t - - > ES'BI,IA'rED RK8 ELEVATION: 113' KOP TVD=500 TMD=500DEP=O 3.00 6.00 9.00 12.00 15.00 8U~I.D 3, BEG / ~' 18.00 21.00 24.00 2'AO0 30;30~00 B/ PERMAFROST TVD=148~ TMD=1553 DEP=272 56.00 59.00 4-2.oo 48.00 EOC TVDI1947 TMD-2142 DEP-665 0 550 700 1050 1400 1750 2100 2450 2800 5150 3500 5850 4200 4550 4900 5250 5600 r I i i I II II II II II Ii I I I I I I II Ii iI Ii i 11750 ! 14.45'FSL. 1' FEL ~ h) SEC11 TllN RgE ~ I TO LOCATION'I ' ~ ~ 2424' FNL- '8' rWL I ~-7c° Z ~.~-~ i SEC. 7. T liN, R t0E J h ~.,,,~ T,ad2OET LOCATION: I o 252I' FNL. 528' rFm I m T,~qGET "W0~5855 TMD=8075 OEP=5124 NORTH 1514 E./~ ~'T 4955 T/ UGNU SNDS Tv'0=2163 TMD--2475 DEPi914 B/ w S~K SNDS TVD=5325 TMD=4250 DEP=2281 T/ w ~ SNDS TVD-2865 TM0-3546 0EP-1727 9 5/8" CSG PT WD=3525 TMD=4557 OEP=2493 K--5 'IVD=4958 TMD=6725 DEP=4136 N 75.14 DEG E 5124' (V0 TARGET) MAXIMUM ANGLE 49.36 DEG ',~.~ ~ !.. ECr 'vrEl ,.-, K-lO TVD=3688 TMO=4810 OEP=2685 BEGIN ANGLE DROP TVD-5416 TMD-7458 OEP-4691 48.00 46.50 45.00 DROP 1.5 OEG / 100' 43.50 ~2 .O0 TARGET - T/ ZONE C (EOB) TVl)=5855 TMD=80?5 DEP=51~4__ T/ ZONE A 'f~--6045 f~0-8323 OB°-528tR B/ KUP SNOS 1¥D=6153 TMD=8464 0[P=$374 TD / 7" C~G l~r TVD=6306 TMD=8~64 DEP=5503 TARGET ANGLE 4O DEG Vertical Section on 75.14 azimuth with reference 0.00 N, 0.00 E from slot #22 600 900 1200 1800 2100 2400 27 3 0 5.~ 56 0 3g 4.2004.5 0 4800 5100 5400 5700 ARCO ALASKA, [12.(2. Structure : Pad 2Z Field : Kuparuk River Unit Location : North Slope, Alaska ~ ~ ~ Wesf scale 1 : 20.00 600 5~0 520 480 440 400 560 320 280 240 200 160 120 80 40 0 443 80 120 160 200 240 13~0 1300 164.0. ..~ 1280. -,I,-- ~_ - - 1160 1120 92~ % · i i i i i i i i i i i i I i i 560 520 4~0 440 400 360 320 280 240 200 160 120 80 40 0 40 80 120 160 20{3 240 % - - W e s t sco,~ ,: ~o.oo 176o 1720 1640 18~O 1560 .1520 .1320 I1G0 1120 1080 1040 920 ARCO ALASKA, Inc. Structure : Pad 2Z Field : Kuparuk River Unit Location : North Slope, Alaska Scale 1 : 20.00 E a s f - - > 1 SO 200 240 280 320 .3EO 4~0 440 4~0 520 5&O ~X) 640 600 720 760 800 840 880 920 9~0 1000 1920. . 18~0_ t840 1720. 1700 . 16~0_ _ I I 1680 6,o A _1320 1240_ .. ~ 1120 (./3 160 200 240 280 320 360 400 440 4,BO 520 560 600 640 680 720 760 8~X) 840 880 920 960 1000 ~o,~,: ~o.oo E a st -- > IZ40 1200 I. UPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC L I 5 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"-2000 PSI ANNULAR PREVENTER. R. E C E IV E D DKP 11/9/94 Anchor: 7 , 6 13 5/8" 5000 PSi JOP STACK A(;;CUMULATOR CAPACITY T~$T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THATTEST 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 ~PONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, lINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM 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 RAMS AND 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 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/'8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR WELL PERMIT CHECKLIST FIELD & POOL ~N~T c~ss ~., /_~= ? GEOL ~ ~y~ UN~# ///~ oN/OFF S.O~E ~ ADMINISTRATION 1. 3. 4. 5. 6. ~ 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease numbe~ appropriate ............... Unique well n~e and n~ber ............... Well located in a defined pool ............. Well located proper distance fro~ drlg unit bo~da~. Well located proper distance from other wells. Sufficient acreage available in drilling unit. If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Pe~it can be issued without conservation order P~mi~ can Be ~s~u~d ~hou~ a~minis~ra~vo approval. Can pe~it be approved before 15-day wait .... ENGINEERING 23. 24. 25. APPR DATE, /-'~26. 28. 2~. 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... Drilling fluid program schematic & equip list adequate BOPEs adequate ..................... BO~E press rating adequate; test to ~6~ psig.~ Choke manifold complies w/API RP-53 (May 84) ....... Work will occur without operation shutdown ....... Is presence of H2S gas probable ............. GEOLOGY i APPR D TE 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... ~ N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Z HOW/jo - A:%CORMS\cheklist rev 03/94 WELL PERMIT CHECKLIST oo,. COMPANY INIT c~.ss WELL NAME GEOL AREA ~~ ~-~----~ PROGRAM: exp [] dev~ redrll [] serv [] UNIT# ON/O S.O , ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... Y N 3. Unique well name and number .............. Y N 4. Well located in a defined pool .............. Y N 5. Well located proper distance from drlg unit boundary... N 6. Well located proper distance from other wells ..... N '7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ .~Y I N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B'& permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~O~i~ psiS. 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdow~ ....... 29. Is presence of ,2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis 9f shallow gas zones .......... / N 33. Seabed condition survey (if off-shore) ........ / Y N 34. Contact name/phone for weekly progress reports . . . / . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ TAB ~ Comments/Instructions: HOW/jo - A:~FORMS\cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * A~ASKA COMPUTING CENTER * * , ~m~mmmmmmmmm~mmmMm~Mmmmm.~Nmm~ * ..... -- SCNLUMOKRGER ****************************** RECEIVED MAY 03 1995 Naska Oil & Gas Cons. Commissio. CDMPANY NAME : ARCO ALASKA, INC, WELL NAAE : 2Z-22 FIELD NAME : KUPARUK RIVER [)NIT BOROUGH I NORTH SLOPE STATE : ADASKA AP! NUMBER : 50-029-22524-00 REFERENCE NO I 9504] .IS WaDe ver~.f,icati, on Listlnq ,chlumherqar AlasKa Cor, put.~nq Center 17-AP~-lgg5 16:00 D~TF : g5/03/16 OPl,~I~~ : F~IC CO~T!~UATIO~'; ~ : CO~t.g~iT : ~RCO ALASKA, .I~'.;C.,KI~P.AROK RIVER UNIT, ~Z-22, 50-02g-22524-00 KI.1PSPllK ~!VFR hWD/~{[D bOGS ODEPfiTORg LOGG!MG T~Pf~ CREATInN DATE: dO~ OPERATOR fiUR~ACE 50CATIO~ SECTION: g"OWNS~IP: FSh ~ F~EL ~ FWL: ELEVATION(FT FROi~ ~ELbY BUSHING: DERRICK FLOOR: GROUND bEVFL: CASIMG RECORD BIT RI1N I 9. O.,2 ~ ST STR I NG 2Z-22 50o292252400 ~ ARCO AbASKA, INC SCHLU~,~,BEPGER WEL~ SERVICES 16-~AR-95 BIT RON ~ BIT RUN 3 11 I445 TOPDRiVE i~1,~0 70.40 SIZE (I~) S!ZE (IN) DEPTH (FT) 5{])0 9,625 4310.0 PAGE: 1 .,IS Teoe Verification l~istin.~ ;chlumhercler AlasKa Cor~putinq Center i7-APR-19q5 16:f)0 R~,:,~S: Df~]'Lt~IC[~ ]~TERV~I,: 4~64' - 8330' L~5 FO~AT DATA bis KQ~,~AT DATA FIt,~ HFADER EDI"'~ED aE~GMD DeDth shifted a~d cllPDed cilrvesI all bit runs merged. # ..... ... $ B~SFLINE CURVE FOR SHIFTS: GRCH,CBT CURVE SHIFT DATA (~8U~ED DEPT~) [~ASELINE DEPTH t~Sf~8~. 0 0 0,5 7.920,0 7768,0 7703'5 7664.5 7522~5 74~4.5 7362.0 7~02.5 167,0 ~25,0 707 ~, 5 STOP DEPTM 8 . · 0 8199,0 ----------EOUIVALE~T UNS~IFTED OflPT{,{---------- §8880,0 809~.5 8O52'0 791!,0 7759.0 7694.0 7654.5 7512~5 7474.0 735~.5 7315.5 7191,0 7156.5 7~,13.5 7062.5 WaDe Verlflcat!on I,istlnn ;cblu,,berqer AlasKa Computl, Dq Center 17-APR-!995 16:011) 7010 6735.0 6684.5 663!,0 6540.0 6490 5 0~60 . I1 0 6~00:0 ~iERCED DATA SOtI~CE LDWG TOOL CODE 6099,5 6g80.0 6724.0 6675,0 653n.0 6480,5 6~66.5 6250,0 ~200.5 Ba,5 4424.0 44~4,0 ~ERGE BASE 826~,0 8199.0 ]'HE DEPTH ADdflST~E[4TS SHOWN ABOVE REFLECT THE HWD GR TO THE CBT/GR (PDC ~AN WITH MAGNETIC MARKED LINE) DATED 21-FE~-95. ALL OTHER CURVES WERE CARRIED WITH THE GR SHIFT. ~HIS FILE CONTAINS THE VERY E~},!ANC~D ORO P~OCESSED RESIS~!IVITY DATA WITB 2' AVERAGE THE GRCH,CBT lis INCiLUDED IN THIS FILE, $ LTS FOR)iAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64MB ** ';;;' ..... '""[5;['""'"'" E EEP~ V~LIIE 2 66 0 3 73 60 4 66 ! 5 66 6 7 65 8 6B 0,5 9 65 11 66 17 68 13 66 0 la. 65 15 66 68 16 66 0 66 0 IS TaLe Yerification LiStinq chlumberqer Alaska Computino Center 17-APP-1995 1.6:00 PAGE: '~.'';'';[~''~;;'~i~[''XPI ~P? ;¢~''~PI FILE ~,~ ~,.,~B SI~[''~;~''';~~;''' ........................... .............. .............. ........... ........ .---;-- I.)FP~ F? 000 O0 . 1 1 4 00000000 0 O0 ~00 O0 ~ 1 ~ 1 a 68 0000000000 RWOP ~"D G/C3 DPMO uWP G/CB PEF CaL~ ~D I~' DER VPP ~O OHM~ YPA ROP ~WD FPHR GP ~WO G~PI FFT ~D HP GPC~ C~T G~P! O0 OoO O0 o 1 1 I 4 68 0000000000 O0 000 O0 0 I ! 1 4 68 0000000000 OD ~00 O0 o I ! 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 OOO O0 0 1 1 1 4 65 0000000000 (')0 000 O0 0 1 1 I 4 68 0000000000 O~ 000 O0 O 1, 1, 1, 4 68 0000000000 O0 000 O0 O 1 1 1 4 68 0000000000 O0 ('00 OD 0 1 1 1 4 68 0000000000 DO 000 O0 0 1 1 1 a 68 0000000000 O0 000 O0 0 1 I I 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 O0 000 O0 0 I ! 1 4 68 0000000000 mmmmmmmmmmmmmmmm#mmmmm~mmmm~mmmmmmm~-mmmmmmmm~mmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm . . D~PT ~331 5 0 PHOB,MWD -999.~50 DRHO..MWD -999 250 PEF.MWD C~L~) , M~;D -999 250 MP~I.MWD -999.~50 RA,MWD -999:250 RP,~WD DE~ ~D -999~250 VRP,MWD 1999.250 VR.A.. MWD -999.250 ROP.MWD Gp[~W~D -999.250 FET. ~wD 999.250 GRCti,CBT -999.~50 DEPT. 43n!,000 RHOB.MWD -999.250 DR~O.MWD -999 250 PE~.MWD CALN,~WD -999.250 NPBI.~WD 52,100 ~A.MWD -999:~50 RP,MWD PEP MW9 -999.250 VPP,~WD -999,~50 'V~A,MWD -999:~50 ~OP.~WD G~:~WD -999,250 FET,MWD -999,250 G~ .H,CBT -999 250 ** END OF DATA ** '999,.250 '999.250 46.996 999~ 250 -999 ';250 **** FILM TRAILER **** FIL~ MA~E : EDIT ,001 SERVICE : FLIC OAT? : 95/0]/!6 MAX REC SIZE : 10~4 F!L~ TYPE : LO LASm FILE : ,IS Tam. e Veri~ication Listi~.~ ichl.mheru...r AlasKa ComF~utlnq Center 17-APR-~995 16:00 PAGE: FILF HEADER FIL~ ~!U~BER 2 R~w MAD Curves and loq header data for each bit run in separate files. BlT R!!i~ MUSBER: 1 DFPTH iNCPSi"E~T: 0.5000 FILW SU~RY [~iJ%~G TOOL COPE ST~R'r DE~T~ CDN 4364,0 $ LOG H~AD~R DATA DATE L[~GGED: SOFTWARE: SIIRWACE $OF~ARE VERSION: DOWNHOLE SOFTWARE VERSIOn: DATA TYP~ (MEMORY or ~EAL-TI~E): TI) DRILLER TOP LOG INTERVAL ~[]TTO~ bOG INTERVAL (FT): BIT ROTATING SPSED W(]LE INCLINATION (DEG) ~!NIMUM ANGLE: MAXIMU~ ANGLE: TOO[, STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOl, TYPE CD~ NEUTRON/POROSItY $ B£]PEHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS C~SI~G DEPTH (MT): BOREHOLE CONDITIONS MUD DENSITY (LB/G): ~UD VISCOSITY STOP DEPTH 8330.0 ~330,0 4-FEB-g5 FAST 2,5 ~EMORY 8330.0 ~36~ 0 8330~0 TOOL GS022 NDS052 8.500 4436.0 !1,30 IS Tare Verififcatlon l, istinc~ Chlt. tmber(j(.~r .~}asKa Comp,]t]n~q Center I 7-AP~-!995 16:00 ~aU[) CgbOR!DF, S (PPt?): FI, IJTL) [~055 (C3}: RFSISTIVITY (OH~-'!~'~) ~T ~Ur) AT ~,~AX CIRCULATING '-~UD FII.,TR~TE AT (MT): UUD CAKE AT (~.:T): TOOL MaTrIX: ~"~ATgI× DE~.!SYTY: CORRFCTIOa (IN}: 155.0 2.0gO 1.680 SANDSTONE 2.65 STANDOFF 1.000 ****.*** RI!N i DRILLFD INTeRVAl, 4450' - R ~ISTIViTY aEASiiUEgENT 55.59 FRO~ BIT G.A~4~A gAY ~,~EASU~E~ENT 7~ 0~' FRO~i BIT D~h~SITY i'qEASU~EME~T 132 ~g FR{'3~ BiT ~, 1- ~, ~ · . ,.~,JrkON ~ASU~E'~,~ENT 1.39,67' FPO~ BIT LIS FORt~AT DATA 84.0 a4.0 PAGE: ** DATA FORMAT SPEC!FICATIOM RECORD ** ** SET TYPE - ~4EB ** 1 66 0 2 66 0 3 73 64 4 66 6 73 7 65 8 66 0,5 9 65 1.1. 66 16 i2 68 13 66 0 14 65 i. 5 66 68 i6 66 t 0 66 1 ~IS Tane Veri, f!cation Llstino 'chlumberqer Alaska Comput!nq Center 17-APR-1995 16:00 ...........NAMF ~ ~l~ ~iC~ AP1 ~''~I API ~ ........ NUmB ~:B .......... SIZE ,~;; .... P~~''' ~0 OgDEP ~ bOG TYPF CLASS MOD NUmB SA~P ELEM CODE (HEX) DFPT FT . .o 0 2 I 4 6~ 00000 poS2 l,Wl G/C3 00 000 00 0 2 ~, 1 4 68 0000000000 DPOP [,,W~ pu 00 000 O0 0 2 ! ! 4 68 0000000000 DPHo bW~ G/C3 00 CO0 00 0 2 ! 1 4 68 0000000000 PFF LWl BN/E O0 000 O0 0 2 ~ 1 4 68 0000000000 DCAI. Lwl IN O0 O00 On O 2 1 ! 4 68 0000000000 ~pH 1,~[ pl! O0 000 O0 O 2 1 1 4 68 0000000000 A~R 1,~1 OH~ O0 OOO O0 0 2 1 1 4 68 0000000000 PSR Lwl ()~ O0 000 O0 0 2 I 1 4 68 0000000000 DER Lw! Ohiq~ 00 000 00 O 2 1 1 4, 68 0000000000 ROP T..~I FPH~ O0 000 O0 0 2 t 1 4 68 0000000000 GR LW! G~PT 00 000 00 0 2 1 1 4 68 0000000000 CAL~ bw!. IN O0 000 0O 0 2 I 1 4 68 0000000000 SN l,~l OHN~ O0 000 O0 0 2 I 1 4 68 0000000000 T~B Lwl HR O0 000 O0 0 2 ! 1 4 68 0000000000 T~BD I, Wl HR O0 OOn O0 0 2 1. ~ 4 68 0000000000 m#mmm~m~mmmmm-mmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm-mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm DATA ** DEPT. 8339.500 ROS2,LWl -999.~50 DPOR.LW1 PEF.L~I -999.250 DCA~,LW1 -999.250 TNPH,LW1 PSP LW! -gaq '~ ' ,... ' .~,. . ., . _.~.~5g D~R,bWl -o99.250 ROP.LW1 CALN.I,W1 -999.250 SN.LW1 -999.250 TA0.LWI DFPT. 4311.500 ROS2.LW1 -999.250 PPOR.bWl PEF.L~I -999.250 DCAL.LWl -g90.250 TNPN,LW! PSP L~I -999 2~0 DER.LW1 -999.250 ROP.LW1 CA ~" ...' '~ ... "' TA L ,[,~1 -9°9.250 SN.LW'I -99g.250 ., B' ** E~D OF DATA ** -g99 250 DRHO.[,W1 -999:~50 ATR,LN! 46 996 GR.LWl -999:250 TABD.LWt .-999,250 -999,250 -999,250 -999,250 -999'250 -999,12.50 -999,250 **** FILE TRA!bER **** FILF NA~4E : EDIT .o02 SFRVICE : FL, IC VFRSiON : 001COI DATF : 05103/16 MAX RFC SIZE : 1024 FILF TYPE LAST FILE : iS Wa~e veri,.fication ~i. sttnq chlumherq~r AlasKa Comput~.n~ Center 17-AP~-~ 9q5 !6;00 PAGE: **** RMET. TNAILEP **** SFRVICE Na~E : EDIT D~TF : C)PIGIN : FL!C R~E[. ~'A~E : q5062 .. CONTINU~TIO~ ~ P~EUlOUS REEL COMmEnT : ~RCO ALASKA, INC.,KUPARU~ RIVER UNIT, 2Z-22, 50-029-22524-00