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&) # (+ - ('% + - ( % 1 1 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϵϯϬϲϴϬ Ͳ^Ğƚ͗ϯϲϭϰϲJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 iP )13tef3i Regg, James B (DOA) From: NSK Fieldwide Operations Supt <n2072@conocophillips.com> Sent: Wednesday, November 23, 2016 10:19 AM To: Bixby, Brian D (DOA); Regg,James B (DOA) R� I il'Zc'!s., Cc: NSK Prod Engr Specialist I Subject: RE: Kuparuk 11Y-Pad Deficiency Report follow-up Attachments: 20161123103221.pdf; 20161123103153.pdf Brian, Jim, Attached is the completed deficiency report and supporting follow up information noting the following: • 1Y-17: No active leak could be identified after cleaning the area and checking the torques. ✓ • 1Y-29 and 1Y-30: Signs have been installed. Please let us know if there are any questions. Thanks Scott Fahrney/Larry Baker SCANNED JUN 17 2017 NSK Fieldwide Operations Superintendent (907) 659-7042 From: NSK Prod Engr Specialist Sent: Friday, November 18, 2016 1:44 PM To: Bixby, Brian D (DOA)<brian.bixby@alaska.gov> Cc: NSK Fieldwide Operations Supt<n2072@conocophillips.com> Subject: Kuparuk I 1Y-Pad Deficiency Report follow-up Brian, Thank you for taking the time to stop in on Wednesday, it was a pleasure meeting you. The items you identified on 1Y- Pad are currently being addressed and we'll let you know when they're resolved. In the meantime don't hesitate to contact us if you have questions or need anything additional from us. Enjoy your time off! Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist ConocoPhillips Alaska Ph:907.659.7535 I Pg:924 I Mail: NSK 69 1 • • Deficiency Report (Wellhead Leak)—KRU 1Y-17 (PTD 1930680) Photos by AOGCC Inspector B. Bixby 11/16/2016 igark- lid '` 'Xis Iv,,, if Nth. Ilk iiiii,i I fn., y a .. & W\ai ' - Ilik:1,1111116 AIM p Milli" ?tilltrreala / .77// 4,-,..110,4 ,..--at.71 --- liar Jul/• 1f/� r r ` " //�r /.// �i x, 11 rrrr ' : ' - -': iiiii , ,, nu// f iHHiiFiLi%?jtt t 2016-1116_Deficiencyj,hotos_KRU_1 Y-17_bb.docx Page 1 of 1 • V1-1,ttV— /7 • Pry iq'3 7,6 State of Alaska Oil and Gas Conservation Commission Deficiency Report • Location: .. 14421.) 6 Date: i 1 PTD: Operator: 6411M4) ea' 44e_, Type Inspection: r ��//Jaga)Operator Rep: lnspector d ,4`, Position: Dd4cG77, r r 04 4Ge1`< `� � ,`1 Op.Phone: (qp7) bay..... 753 5 Correct by(date): i 'l'C Op.Email: /13? c €cvp(!?fr c0•b Follow Up Req'd: .YES Detailed Description of Deficiencies Date Corrected W Ect 1 bJ-1'. e Px oma+ •w eew Akeas f j o�!��` (1`z6l/6` STS \Jett. 11-29 dzebr Ulster Q,r,rCS r oft) vice,i5 f 1L rate Y-0 9.) !'(23[14° 5K \J614. '»30 /J4td 1 iktoio xc Cievi It(03(1 40 51Cr Attachments: Operator Rep Signatures: /.�.1 - ` 11146 AOGCC Inspector *After signing,a py of this form is to be left • o• . •r. r Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date . Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a fofiow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. • Revised 2/2016 • ConocoPhillips Alaska AOGCC EXCEPTION REPORT Location: lY FAp Date: \S/jto J16, AOGCC Inspects Y3 It Instructions:All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered into the'Action Taken'section below. Note-Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: W 'C. l \ 11_ Fia, i.v04 t(‘ie ad &t.eJ5 Ixe.c) (SID h. o n tde-k) c) #kie U Y- 21 N Pis \,1\;01,\Abuses t3 v tt s rtY r-o ji- Wel{ jY-30 N ei-C1 s 11\) \Ikhk.5g. Action Taken to Correct Problem: /7 NOD5,,e6 cl w F(44 .. tNsperCf - co�rc! F�•+DNcsici-ocr toW-- Date:a20Joi((, Initials: <-yc)k-- !Je(f f`.1" / 7 26.49vg. DHD tCto40,.._4tcw7 AU o rL Siynl Qc•-• - kt 126 er(eD Date: D Nb d i4 Initials:\i' 2.9 AND J0E/N4 sr c�ulerJ to to z IQ n1 t2e-LeArt-tm leE itl t'fJ Date: 2,0 app I(o Initials: DA-- 14 Ct t✓ ! '" 3o ,d der1 +b )5M Y s I f Date: z Nov lG initials: SR'F -3 o 5 t 1 t4s- ((ep Date:z? 000 141nitials: $ 'F Date: Initials: Return completed form to Prod.Engr.Specialist: n1139Aconocophillips.corn Distribution; CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF182 Ops Supt CPF3 Ops& DOT Pipelines Supt NSK Fieldwide Operations Supt 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. I~'~ '-OG(-~ 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: Beverl Vincent Nathan Lowell Date: TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si ConocoP hiflips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ~~1~-Ni~~~ AUG ~ 2(108 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: LJ RECE~ V~C~ AUG 2 5 2008 Al ~~a Gil ~ Gas Con$. C0+?1ri?~~,SIOR Anchcr~ga 1°I~ 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 corrosion inhibitor/sealant was pumped August 2-17, 2008. 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. Sincerely, Perry Kle ..... _ _ ~ ~ 2 ~~~ ~ 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 8/17/2008 Well Name PTD # Initial top o cement ft f VoJ. of cement um ed Finaf top of cement Cement top off Corrosion date inhibitor Corrosion inhibitor/ sealant date bbls ft 2H-05 185-168 SF al 2H-17 200-019 6" N/A SF " N/A 5.10 8/2/2007 2K-27 201-169 10" N/A 6 N/A 1.27 8/2/2007 2M-03 191-141 16" N/A 10" N/A 8.92 8/2/2007 1 B-14 194-030 SF N/A 16" N/A 2.13 8/2/2007 1 B-18 194-061 9" N/A SF N/A 1.70 8/13/2008 1 B-19 194-064 SF N/A 9" N/A 8.07 8/13/2008 1 B-20 203-115 21" N/A SF N/A 5.10 8/13/2008 1 B-101 203-133 3" N/A 21" " N/A 5.95 8/13/2008 1 B-102 203-122 4" N/A 3 " N/A 1.00 8/17/2008 1Y-05 183-087 6" N/A 4 " N/A 1.00 8/17/2008 1Y-07 183-068 6" N/A 6 N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A 6" N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 1.27 8/13/2008 1Y-26a 188-116 SF N!A SF N/A 2.12 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 204-091 14" N/A SF " N/A 3.83 8/13/2008 1 E-119 204-031 14" N/A 14 " N/A 5.95 8/17/2008 1 E-121 204-246 6" N/A 14 " N/A 4.67 8/17/2008 1E-123 204-074 5" N/A 6 " N/A 1.00 8!17/2008 N/A 5 N/A 1.00 8/17/2008 ~l~i~~~m~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 02/12/08 r~~~ FED ~. ~ 2D08 { .y i `T ~~ limp 4 N0.4585 ~ ~ .e~ ~ ~ ~ , ,_ ;`~ - Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1J-136 11964574 INJECTION PROFILE v - 02/02/08 1 2A-04 11964576 INJECTION PROFILE _ 02/04/08 1 1A-01 11970631 PRODUCTION PROFILE ~ - 02/06/08 1 1Y-17 11994613 GLS 02/09/08 1 1A-17 11996600 PRODUCTION PROFILE / - 02!10/08 1 2Z-13A 11996601 SBHP SURVEY (c - 02/11108 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: FROM: John Crisp, SUBJECT' Petroleum Inspector May 17-18, 2001 Safety Valve Tests Kuparuk River Unit 1Y Pad May !,7 & 1..8., .2.0.01: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. ! witnessed one failure, the LPP failed to trip above 50% of primary separator pressure. The pilot was re-tested & passed the re-test. The AOGCC test report is attached for reference. ! conducted 25 well house inspections on 1Y Pad. The majority of the houses were in good shape w/no problems witnessed. Well houses # 30 & 22 were found w/the well house lids resting on the tree cap gauges. The VSM for the flow line on well # 29 looked as if it had shifted up & had the line in a slight bind. I asked Phillips Rep. Pete Nezaticky to inspect this line. Prudhoe Bay Field has had problems w/VSM's shifting up & I wanted to make sure KRU Rep's were aware of this problem. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 16 wells, 32 components tested. 1 failure witnessed. 3.13% failure rate. 25 well house inspections conducted. Attac,_hm,,en~_.' SVS KRU 1Y 5-17 & 18-01jc CC; NO, N-CONFIDENTIA. L SVS KRU 1Y 5-t7 & 18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: 5/17 & 18/01 Field/Unit/Pad: Kupamk Riwr'Unit 1Y Pad Separator psi: LPS 85 HPS i I Well Pe~it Separ Set L~ Test Test Test Date Oil, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCL~ 1Y-01 1830500 1Y-02 1830590 1Y-03 1830610 3750 2~6 1800 P P wAG 1Y-04 1830660 1Y-05 1830870 , 1Y-06A 1971340 85 70 55 P P OIL , , , 1Y-07 1830680 ~ 1Y-08 1830620 lY-09 1830520 lY-10 1830510 3750'2000 1750 P P W~G: 1Y-11 1830410 ~Y-~2 ~830260 lY-13 1830150 1Y-14 1830230 ~Y-~SA ~98~860 85 70 50 ~ ~ Om lY-16 1830420 iyAT~~ ~.:~: ~i930680 85 60 60 p p O~L iY:18 - ~ 1931060 ' 1Y-19 1931070 85 60 65 P P OIL 1Y-21 1931020 85 70 65 P P OIL 1Y-22 19307~ 85 60 55 P P OIL , 1Y-23 1930710 85 70 28 3 P 5/18/01 OIL 1 Y-24 1930720 85 70 78 P P OIL 1 Y-25 1880890 1Y-26A 1881160 85 70 50 P P OIL 1Y-27 1930880 85 70 ~ P P OIL 1Y-28 1930890 , , 1 Y-29 1880910 85 70 60 P P OIL , , . 1Y-30 1880900 85 70 70 P P OIL 1Y-31 1930900 1 Y-32 1880930 85 70 70 P P OIL 1Y-34 1930910 85 70 65 P P OIL Wells: 16 Components: 32 Fa#ures: 1 Failure Rate: 3.13% [3 90 Day Page 1 cf2 qx~q '[,"nTT iv q_1'7 ~ '~ s~_cll;,~ WeB Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCL~ , , RJF 1/16/01 Page 2 of 2 SVS KRU 1Y 5-17 & 18-01jc Ph "LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 April27,2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1Y-17 (93-68) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the KRU well 1Y-17. A squeeze and subsequent fracture and perforation jobs were performed on this well. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad ORIGINAL RECEIVED MAY 0 Alaska 0~t & Gas Cons. Commission Ar~'~e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 105 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 206' FNL, 4053' FEL, Sec. 1, T11N, R9E, UM (asp'sSS0892, 5975115) 1Y-17 At top of productive interval 9. Permit number / approval number 2336' FSL, 1906' FEL, Sec. 35, T12N, R9E, UM o 193-068 / At effective depth 10. APl number 50-029-22368 At total depth 11. Field / Pool 2818' FNL, 2045' FEL, Sec. 35, T12N, R9E, UM (asp's 527609, 5977771) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8050 feet Plugs (measured) true vertical 6482 feet Effective depth: measured 7950 feet Junk (measured) true vertical 6388 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 230 sx PFC 121' 121' 790 Sx PF E cmt, 480 Sx Class 4400' 3573' SURFACE 4400' 9-5/8" G, top job 170 sx PFC PRODUCTION 8035' 7" 300 sx Class G 8035' 6468' Perforation depth: measured 7519'-7585', 7708'-7718', 7730'-7-/48' true vertical 5985'-6046', 6161'-6170', 6181'-6198' Tubing (size, grade, and measured depth) 4", 11#, J-55 Tbg @ 5156' MD; 3-1/2", 9.3#, J-55 Tbg @ 7637' MD; 2-7/8",6.5#, L-80, Tbg @ 7667' MD. Packers & SSSV (type & measured depth) CAMCO HRP-4SP @ 7431' MD; BAKER 'D' PERM W/5' SBE @ 7639' MD. OTIS 4" 'FEX' SERIES 10' @ 1798' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water~Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation 289 1022 1153 - 141 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . Signed Title Staff Engineer ate / ~' Michael Mooney · ~ '" Prepared by Sharon Al/sup-Drake 263-4612 ~. MAY 0 g ?off! Form 10-404 Rev 06/15/88 · ORIGINAL Alaska Oil & Gas Cons. CommissiO~uBMiT IN DUPLICATE Anchm'age 1Y-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 2/22/2°°1' i DUMP BALLED 10 GAL CEMENT SLURRY @ 7715' WLM. (-6.25') [Cement-Poly Squeeze] 2/28/2001: PERFORATE 7707.6'-7717.6' W/2" BH (27C)/6 SPF/60 DEG PHASING/RANDOM ORIENTATION - PRESSURED UP ON WELL TO 2800 PSI BEFORE PERFORATING - WHP DROPPED TO 1500 PSI AFTER FIRING GUN [Perf] 3/01/2001: PUMP BREAKDOWN AT 30 BPM - SAW GOOD BREAKBACK FROM 6858 PSI TO 5010 PSI - PERFORM STEP DOWN TEST - ISIP=2505 PSI - FG=0.85 - XS FRICTION=550 PSI AT 20 BPM - PUMP SCOUR STAGE - PERFORM STEP DOWN TEST - ISIP= 3150 PSI - FG=0.95 - XS FRICTION=340 PSI AT 20 BPM - PUMP A SAND FRAC PLACED 140151 LBS 16/20 CARBOLITE BEHIND PIPE - LEFT 1681 LBS IN PIPE - 10 PPA ON PERFS - FLUSHED 2 BBLS SHORT OF TOP PERF - WELL FREEZE PROTECTED WITH 36 BBLS DIESEL *****NOTE: LEFT 3/4 OF A TREESAVER RUBBER IN THE WELL ..... [Frac-Refrac] RECEIVED MAY 0 2 2001 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 208' FNL, 1224' FWL, Sec. 1, T11 N, R9E, UM At top of productive interval 2336' FSL, 1907' FEL, Sec.35, T12N, R9E, UM At effective depth At total depth 2461' FSL, 2048' FEL, Sec.35, T12N, R9E, UM 5. Type of Well: Development __X Exploratow~ Stratigraphic___ Service__ (asp 's 530891, 5975115) (asp's 527748, 5977647) (asp's 527606, 5977771) 6. Datum elevation (DF or KB feet) RKB 105 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1Y-17 9. Permit number / approval number 193-068 10. APl number 50-029-22368 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8050 feet Plugs (measured) 6482 feet Tagged Fill (3/11/01) @ 7720' MD. Effective depth: measured true vertical Casing Length CONDUCTOR 121' SUR. CASING 4359' PROD CASING 7996' 7720 feet Junk (measured) 6172 feet Size Cemented Measured Depth True vertical Depth 16" 230 Sx PFC 121' 121' 9-5/8" 790 Sx PF E, 480 Sx G, 4400' 3573' & 170 Sx C 7" 300 sx Class G 8035' 6468' Perforation depth: measured 7519 - 7585'; 7708 - 7718'; 7730 - 7748' APR 0--9 .2.001 true vertical 5985 - 6046'; 6161 - 6170'; 6181 - 6198' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) . 3-1/2", 11#, J-55 Tbg @ 5156' MD; 3-1/2", 9.3#, J-55 Tbg @ 7637' MD; & 2-7/8", 6.5#, L-80 Tbg @ 7667' MD. Camco HRP-4SP Packer @ 7431' MD; Baker 'D' Perm Packer w/5' SBE @ 7639' MD. Otis 4" FEX Series 10 @ 1798' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation Shut In Subsequent to operation 123 Representative Daily Avera.qe Production or Injection Data Gas-Mcr Water-Bbl - 56 625 Casing Pressure Tubing Pressure - - 162 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended _ Service 17. I hereby certify tha~the foregoing is true and correct to the best of my knowledge. ., / Signed .~_ Title: Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1Y-17 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZES, ADD PERFORATING, & HYDRAULIC FRACTURE TREATMENT 6/20/99: RIH & tagged fill at 7754' MD. Recovered a small sample of rocks & sand. 6/26/99: Ran DH video to top of fill. Saw substantial casing damage at 7730' MD. 12/2/00: RIH & tagged fill at 7751' MD. 12/24/00: MIRU CTU. RIH w/CT & tagged fill at 7723' MD, then squeezed collapsed casing and the perforation intervals located at: 7519 - 7585' MD 'C' Sand 7730 - 7748' MD 'A' Sand Loaded wellbore w/2% KCI Water, then pumped 5 bbls of Neat Latex Acid Resistive Cement, followed by 10 bbls LARC w/aggregate, followed by 10 bbls Neat LARC. Placed all 25 bbls of cement behind pipe without attaining any significant squeeze pressure. Contaminated cement w/biozan & jetted contaminated cement from wellbore to 7715' MD. RD. 12/28/00: RIH & tagged cement at 7750' MD. Was able to inject 37 bbls of Hot Oil into well at 1.25 bpm / 2100 psi. 1/19/01: MIRU CTU. RIH w/CT & resqueezed the collapsed casing and the lower 'A' sand perforation interval (listed above). Pumped 5 bbls of Neat Latex Acid Resistive Cement, followed by 25 bbls LARC w/aggregate, followed by 10 bbls Neat LARC. Hesitated squeeze and pumped additional 9 bbls of LARC. Placed additional 21 bbls of cement behind pipe at final estimated 500 psi squeeze pressure after 3 hours hesitation. Contaminated cement w/biozan & jetted contaminated cement from well to 7723' MD. RD. 1/27/01: RIH & tagged fill at 7746' MD. 2/22/01: Made runs w/dump bailer & dumped cement slurry into wellbore from 7723' to 7715' MD. 2/28/01: MIRU & PT equipment. RIH w/perforating guns & shot 10' of 'A' sand perforations as follows: Added perforations: 7708 - 7718' MD Used a 2" carrier & shot the perfs at 6 spf. POOH w/gun. Rigged down. (Continued) 1Y-17 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZES, ADD PERFORATING, & HYDRAULIC FRACTURE TREATMENT 3/1/01: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 16/20 mesh proppant, through the open perforation intervals (listed above). Pumped Breakdown stage w/200 bbls of 20# Linear Gel @ 30 bpm, followed by Shutdown. ISIP @ 2505. Pumped 100 bbls of 40# Crosslinked Gel, followed by 50 bbls of 40# Scour Gel w/1 ppa 16/20 proppant (2160 lbs), followed by 118 bbls of 20# Linear Gel Flush, followed by Shutdown. ISIP @ 3150. Pumped 150 bbls 40# Crosslinked Gel Data Frac, followed by 86 bbls of 20# Linear Gel @ 20 bpm, followed by Shutdown. ISIP @ 3216. Pumped Fracture Treatment w/275 bbls 40# Crosslinked Pad, followed by Crosslinked proppant stages ramped from 2 to 10 ppa, followed by Flush, followed by Shutdown. Placed a total of 137991 lbs of proppant into the formation. RD. 3/4/01: RIH w/CT & performed proppant fill cleanout to cement tag at 7716' MD. POOH & RD. 3/11/01: RIH & tagged fill at 7720' MD. Returned well to production w/gas lift & obtained a valid well test. 01'40 ggFO 9::} .... 068 93 .... 068 93 ..... 06~,~. 03 ..... 08,~ ,., ............... /'~ ,'...~ '¥ d u - 'i W e i / ,3 e o t o,~.! i c a I M a 't e r' '¥ a i s ..I n v e n 1:: ,:-::, r" y DATA T r"ATA F'LIIS 57 i6 ~, 07 iS, AII..Y WELL OP ~'q P D A T E: (-; D R /,3 D N 0.9 / i 8 / 9:3 T O 9 / t 8 / 9 3 SI...IRVE ¥ C IS, kd, C D R CDR ~NI'IANCEMENT S U R V E Y We 1 i "!:' h e wel 1 C 0 M iq K N T S d i' t c h s a m p I e s r ~:~ q u i' r'ed? ?'es (~,A n d r' e c e i' ~? 'y' c:: :.{; r" (i; (.: o ':t 'v' ,i-!: d '/' ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 14, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~.~ -It[fl 1F-15 Perforate ¢iA-i'bo1 H-1 7 Perforate ~.k-Rb 1Q-12 Stimulate ff:5-t.¢~ 1Y-17 Stimulate ffb-Cq 1Y-28 Stimulate ¢/o.~1~i3G-04 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED FEB 1 6 1994 A~as~ Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,,,..)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 208' FNL, 1224' FWL, Sec 1, T11N, R9E, UM At top of productive interval 2336' FSL, 1907' FEL, Sec 35, T12N,_R9E, UM At effective depth 2438' FSL, 2024' FEL, Sec 35, T12N, R9E, UM At total depth 2461' FSL, 2048' FEL, Sec 35, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 105 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-17 9. Permit number/approval number 93-68 10. APl number 50-029-22368 11. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 1 21 ' Surface 4 3 5 9' Intermediate Production 7 9 9 5' Liner Perforation depth: measured 751 9'-7585' true vertical 5985'-6046' Tubing (size, grade, and measured depth) 8O5O 6482 7950 6388 Size 16" 9.625" 7" feet Plugs (measured) None feet feet Junk (measured) None feet Cemented Measured depth 230 Sx PFC CMT 1 21' 790 Sx Perm. E, 4400' 480 Sx Class G, 170 Sx PFC Top Job 270 Sx Class G 8035' RECEIVED True vertical dept~ 121' 3573' 6468' 7730'-7748' 6181'-6198' 4", 11#/ft., J-55 @ 5137', 3.5", 9.3#/ft., J-55 @ 5137'-7618', 2.875, 6.5#/ft., L-80 @ 7618'-7648' Packers and SSSV (type and measured depth) PKRs: Camco 'HRP-4-SP' Retr. @ 7412' & Baker 'D' Perm @ 7620'; SSSV: Otis Series 10 SE @ 1779' 13. Stimulation or cement squeeze summary Fractured "A3" Sand on 12/29/93. Intervals treated (measured) 7730'-7748' Treatment description including volumes used and final pressure Pumped 9.2 Mlbs 16/20 & 126.5 Mlbs 12/18 ceramic proppant into formation, fp was 7140 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 119 .../3 16 2990 1300 179 3030//' 2327 108 820 214 16. Status of well classification as: Oil X Gas Suspended .__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned''~t~ ~'' ~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE Procedure Date: Service Co: Annulus Press' AFE: Zone- Test L~nes To- ( _ -- . Perfs' __ STAGE VOL FL U I D PROP RATE ' · ~. ~o~/,.,/,.,,' ~k~._~ ~,,,~.~.,~. . ~.., ~.~ ~,, _ s/~,L'~,,J - ~.. - .... · , PRESSURE ,m -- __ 1 (30 -- - ,- - ' = -- -,.-- RECE!¥ED ' " mm · ' FEB '1 6 1994, . - - ISIP: ~ 15 Min: ~ Avg Press: ~'00 psi · _ Fluid to Recover: Y~T7 (~/y~L(~O__ Sand .In Zone: c~z'~O~ '('(z~~(~J~ , ,,~~ ~.~.._ Sand In Csg: Job. Compl ere' TA/mjk/3100/104 2/27/87 !NDIVIDUA~ELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 11/18/1993 PAGE: 1 93-068 CDN 93-068 CDR 93-068 CDR ENHANCEMENT 93-068 SURVEY 93-068 407 93-068 DAILY WELL OP 93-068 SURVEY 93-068 5716 OH,7360-8045 OH,4320-8045 OH,4338-8025 SUB-SURFACE COMP DATE: 09/18/93 5/16/93 TO 9/18/93 0.00-8050 4339-8049, CDR/CDN SUMMARY Are well tests required? Yes F~ Was well cored? Yes ~ If yes, was the core analysis & description received? Are dry ditch samples required? WELL IS IN COMPLIANCE. ~~ I~qI-TIAL Yes COMMENTS: STATE OF ALASKA ALASr,~ OIL AND GAS CONSERVATION COMMIU~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS ~ SUSPENDED [~] ABANDONED [] SERVICE [---I 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-68 3 Address 8 APl Number ///%1/ P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22368 4 Location of well at su~ace ~ .............. _,~;~ 9 Unit or Lease Name KUPARUK RIVER 208' FNL, 1224' ~L, SEC 1, T11N, R9E, UM i f¥",TE ~ ~~ 10 Well Number At Top Producing Inte~al i ¢/~__ ¢; At Total Dep~ ~ ? ;11 Field and Pool 2461' FSL, 2048' FEL, SEC 35, T12N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER RKB 105', PAD 64' GL ADL 25641 ALK 2572 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ 115 Water Depth, if offshore 116 No. of Completions 17-May-93 22-May-e3 ~(COMP) ~/~F,5_ "* f~tus~l ~7 Total Dapth (MD+IVD) 18 ~lu~ Back ~opth (M~+~D) 1~ Diroctional Su~oy 120 ~op~ whero SSSV set 21 lhickness of permafrost 8050' MD, 6482' ~D 7950' MD, 6388' TVD YES ~ NO ~ ] 1798 feet MD 1500 APPROX ~ Type Electric or O~er Logs Run CDR, CDN, CET,CBT, GOT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE C~ 16" 62.5~ H-40 SURF 121' 24" 230 SX PFC CMT 9.625 47~/36ff L-80/J-55 SURF 4400' 12.25" 790 SX PF E CMT, 480 SX CLASS G CMT TOP JOB 170 SX PFC CMT 7" 26¢ L-80 SURF 8035' 8.5" 300 SX CLASS G 24 Pedorations open to Production (MD+TVD of Top and BoUom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4', 3-1/2', 2-7/8' 7666' 7431', 7639' SWS 4.5" CSG GUN HJII ~ 12 SPF 7519'-7585' MD 5985'-6046' TVD 10.9~, 9.3~, 6.5~ SWS 4.5" CSG GUN BH ~ 4 SPF 7730'-7748' MD 6181'-6198' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Me~od of Operation (Flowing, gas li~, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR ~TE E 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. OOT 7 t99 -~[ask~ 0il & Gas Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 751 4' 5980' 3i. LIST OF A'FrACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing-the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1Y-17 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25641 ALK 2572 50-029-22368 93-68 ACCEPT: 05/16/93 08:00 SPUD: 05/17/93 07:00 RELEASE: 09/17/93 06:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 05/16/93 (1) PARKER 245 TD: 121'( 05/17/93 (2) PARKER 245 TD: 121'( o) 0) 05/18/93 (3) PARKER 245 TD: 4075'(3954) 05/19/93 (4) PARKER 245 TD: 4414'( 339) MOVING RIG TO 1Y-17 MW: 0.0 VIS: 0 05/20/93 (5) PARKER 245 TD: 4414'( MOVE RIG F/lB-12 TO 1Y-17, BALL MILL AND UTILITY MODULE ON 1Y PAD, RIG @ CPF3 - 2Y PU BHA MW: 9.2 VIS: 72 o) MOVE RIG F/CPF-3/CPF-2Y TO 1Y DS. SPOT RIG. RU, NU DIVERTER, MIX SPUD MUD, FUNCTION TEST DIVERTER. WITNESS WAIVED BY DOUG AMOS- AOGCC, FILL STACK CHECK FOR LEAKS, OK, PU 30 STDS "G" DP AND 10 STDS HWDP, 1 STD STEEL DC AND 1 STD MONEL DC. DRILLING MW:10.6 VIS: 51 PU BHA, ORIENT TOOLS, CO 16" CONDUCTOR F/104'-121', DRLG 12-1/4" HOLE F/121'-372'. ADT 1.35 HR. REPAIR BOP ACTUATOR ON TOP DRIVE, DRLG TO 740', SERVICE RIG, DRLG TO 4075' RIH W/ 9-5/8" CASING MW:10.6 VIS: 45 DRILL & SURVEY F/4075' TO 4414', ADT=2 HRS, CIRC & COND MUD @ 4414', POOH & WORK THROUGH TIGHT SPOTS, WORK BRIDGE @ 2216', POOH LD BHA, PU HO AND RIH, REAM BRIDGE @ 2169'-2180' & 2216'-2280', RIH, CIRC & COND MUD, PUMP SLUG, POOH TO RUN 9-5/8" CSG, RU TO RUN 9-5/8" & HOLD SAFETY MEETING, RIH W/CSG DRLG FLT COLLAR 9-5/8"@ 4399' MW: 8.8 VIS: 29 FINISH RUNNING 9-5/8" CSG, WASH DOWN F/2543'-2583', RU CMT HEAD, CIRC & COND MUD & HOLE, SWITCH TO HOWCO & PUMP 5 BBL WATER, DROP BTM PLUG, TEST LINES TO 3000 PSI, PUMP 45 BBLS WATER, DROP 2ND BTM PLUG, PUMP 305 BBLS 12 PPG LEAD CMT & 98 BBLS 15.8 PPG TAIL CMT, DROP TOP PLUG. DISPLACE W/20 BBLS WATER 282 BBLS MUD. AFTER PUMPING 258 BBLS MUD LOST RETURNS & NEVER REGAINED. BUMPED PLUG TO 2000 PSI, FLOATS HELD. RD CMT HEAD, LD LDG JT & RD CSG EQUIPMENT, ND 20" DIVERTER & RU FOR TOP JOB, CMT TOP JOB, FLUSH W/ 220 BBLS WATER & FOLLOWED W/170 SXS PERMAFROST "C" @ 15.6 PPG, INSTALL PACKOFF, MU 11-3/4" BTCXll" BRAIDENHEAD, BAKERLOK & TORQUE TO 25K FT LBS, NU 13 5/8" 5M BOP STACK & TEST, TEST WAIVED BY AOGCC DOUG AMOS, INSTALL WEAR RING, MU 8 1/2" BHA, ORIENT TOOLS, RIH & TAG CMT @ 4300', FILL PIPE, CO CMT TO 4314', CIRC 10 MIN. PRESS CSG TO 2000 PSI & HOLD FOR 30 MIN. DRILL PLUGS & FLT COLLAR. WELL: 1Y-17 API: 50-029-22368 PERMIT: 93-68 PAGE: 2 05/21/93 (6) PARKER 245 TD: 7463' (3049) 05/22/93 (7) PARKER 245 TD: 7685' ( 222) 05/23/93 (8) PARKER 245 TD: 8050'( 365) 05/24/93 (9) PARKER 245 TD: 8050'( 05/25/93 (10) PARKER 245 TD: 8050'( o) o) DRILLING 9-5/8"@ 4399' MW:ll.2 VIS: 41 FINISH DRILLING FC, CMT, & FS & 10' NEW FORMATION, FIT W/8.7 PPG MUD, EMW = 12.6, DRILL W/TURBINE & MWD SURVEY F/4424'-7463' DRILLING 9-5/8"@ 4399' MW:ll.6 VIS: 45 CIRC OUT GAS CUT MUD, MUD CUT F/ll.2 TO 10.8 PPG, INCREASE MUD WT TO 11.4 PPG, DRILL F/7463' TO 7525'. ADT=l.25, CBU, WELL FLOWING, INCREASE MUD WT. TO 11.6 PPG, SHORT TRIP 20 STANDS, HOLE TOOK PROPER FILL. CBU, NO GAS PUMP PILL, POOH, LD SINGLE HWDP & CHANGE OUT PIPE DOPE ON HWDP BREAKS FROM CATS PAW TO BESTOLIFE. LD BHA, PU NEW BHA, RIH TO 4300' & FILL PIPE, SLIP & CUT DRLG LINE. SERVICE RIG & TOP DRIVE. RIH TO 7450', WASH & REAM DOWN WHILE LOGGING W/ ANADRILL F/7450'-7525', DRILL F/7525' TO 7685', ADT = 3.65 LOGGING W/SCHLUMBERGER 9-5/8"@ 4399' MW:ll.6 VIS: 46 DRILL F/7685'-8050', ADT=12 HRS, CBU, MONITOR WELL FOR FLOW, & PUMP DRY JOB, MAKE 25 STAND SHORT TRIP TO 5695', NO TIGHT HOLE, RIH TO 8050' WTH NO FILL, CBU, NO GAS, DROP SURVEY & PUMP DRY JOB. POOH, REMOVE SOURCE FROM LWD TOOL & DOWN LOAD SAME. LAY DOWN ANADRILL TOOL & STAND BACK BHA, RU SCHLUMBERGER & RUN USIT LOG CEMENTIN 7" CASING 7"@ 8034' MW:ll.6 VIS: 43 CONT LOGGING W/SCHLUMBERGER USIT LOG, COULD NOT GET LOG BECAUSE LCM WAS CLOGGING TOOL. WIPER TRIP, NO FILL, ALL BHA HAS COPPER COATED DOPE AND DP HAS CATS PAW, CIRC & COND MUD TO RUN CSG, POOH, LD BHA, HOLE IN GOOD COND. W/ NO TIGHT SPOTS, PULL WEAR RING AND RIG UP TO RUN 7" CSG, RUN 7", 26#, L-80 BTC MOD, TOTAL OF 190 JTS & MARKER JT. CIRC & COND MUD - ONLY PARTIAL RETURNS @ 3 BPM, REGAINFULL RETURNS AFTER CIRC APPROX ONE CASING VOLUME, ESTABLISH RATE OF 5.5 BPM WITH FULL RETURNS, BEGIN CEMENT JOB W/HOWCO PUMP 20 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER, & 300 SX (61 BBLS) CLASS G PREM CEMENT. PUMP @ 5.5 BPM. RELEASE RIG 7"@ 8034' MW: 0.0 VIS: 0 FINSH CEMENTING 7", PUMP 300 SX, 65 BBLS, PREM "G" 15.6 PPG CMT & DISPLACE W/307 BBLS 11.6 PPG BRINE. BUMP PLUG W/3500 PSI, HOLD 15 MIN, CIP 0719 HRS, ANNULUS FLOWING, SHUT IN WELL, WAIT ON CEMENT MONITOR PRES BUILDING TO 128 PSI, BLEED PRESSURE OFF & WAIT FOR FLOW TO STOP, RD CMT HEAD, PU STACK, SET SLIP W/235K, MAKE ROUGH CUT ON 7", RD CSG TOOL, RU DP TOOLS, SET BACK STACK, MAKE FINAL CUT ON 7". INSTALL PACK OFF & NU TREE. PT TO 3000 PSI, FREEZE PROTECT WELL W/100 BBLS H20 & 80 BBLS DIESEL, LD DP, RIG RELEASED @ 21:30 ON 05/24/93 WELL: 1Y-17 API: 50-029-22368 PERMIT: 93-68 PAGE: 3 09/13/93 (11) TD: 8050 PB: 7950 09/14/93 (12) TD: 8050 PB: 7950 09/15/93 (13) TD: 8050 PB: 7950 RIH W/DP TO TAG TOP OF SAND 7"@ 8034' MW:ll.5 NaCl/Br MOVE RIG F/1Y-23 TO 1Y-17. ACCEPT RIG @ 1600 HRS, 09/12/93. SET TEST PLUG & NU DSA. NU 13-5/8" BOP STACK. NU ALL LINES & FLOWLINE. TEST CHOKE MANIFOLD, HCR, CHOKE & KILL LINE VALVES, BLIND RAMS, & PIPE RAMS ALL TO 3000 PSI. TEST ANN TO 1500 PSI. BOP TEST WAIVED BY STATE MAN JOHN SPAULDING. SLIP & CUT 100' DRLG LINE. RU TO RUN 3-1/2" DP. PU & RIH W/BAKER MODEL D BP. SET PLUG @ 718' POOH. LD RUNNING TOOL. PU 1 JT 5" CSG & RIH UNTIL COLLAR 3' OFF FLOOR. SLOWLY DUMP 1200# SAND DOWN 5" & INTO WELL. WAIT ON SAND TO FALL TO TOP OF BP. ND BOPES 7"@ 8034' MW:ll.5 NaCl/Br RIH W/BIT, TAG SAND @ 685'. POH. MU CSG CUTTER. RIH. MU KELLY. LOC COLLAR @ 103'. CUT 7" CSG. REVERSE ARCTIC PACK F/7" X 9-5/8" ANN. S/B KELLY. POH. LD CSG CUTTER. ND BOP'S, REMOVE TBG SPOOL & 7" PACKOFF. TACK-WELD 7" SLIPS TO CSG. SET DSA, SET BOP'S, TEST FLANGES TO 1000 PSI. RU GBR, MU 7" CSG SPEAR & BHA. RIH, ENGAGE CSG STUB & POH. LD 40' TOP JT & 22' STUB. MU TRI-STATE CSG BACK-OFF BHA & RIH. ATTEMPT TO BACK-OUT CSG STUB @ 103' W/O SUCCESS. PRESS TOOL TO 4700 PSI & CSG WOULD NOT BACK-OUT. POOH TO SURF W/TOOL & FUNCTION TEST. OK. REPIN TOOL & RIH TO COLLAR @ 146'. BREAK COLLAR W/1800 PSI ON TOOL. REPEATEDLY CYCLE TOOL & MAKE TOTAL OF 4 TURNS ON CSG. POOH. LD ALL DC'S & BACK-OFF TOOL. RIH W/FISHING SPEAR. LATCH ONTO 7" CSG. BACK OUT CSG @ 146'. POOH W/20' CUT JT & 1 FULL JT OF PIPE W/COLLARS ON BOTH ENDS, LEAVING PIN LOOKING UP. RIH W/7" CSG & WASHOVER SUB TO GUIDE COLLAR OVER PIN. RUN TOTAL OF 3 JTS NEW CSG & LANDING JT. BEFORE SCREWING CSG TOGETHER, DISPLACE 9-5/8" X 7" ANN & 7" CSG TO DIESEL @ 146'. SCREW CSG TOGETHER & TEST SAME TO 3500 PSI F/30 MIN. LOST 100 PSI IN 30 MIN. DRAIN BOP STACK. ND RISER & BOP'S TO SET SLIPS. RIH W/BIT & SCRAPER 7"@ 8034' MW:ll.5 NaCl/Br MAKE ROUGH CUT ON 7". REMOVE 13-5/8" BOP STACK & DSA. SPEAR 7" & SET SLIPS WITH 165K#. MAKE FINAL CUT ON 7" & BEVEL STUB. SET PACKOFF. Nil FMC TBG HEAD. TEST PACKOFFS TO 3000 PSI, OK. TEST BOPE TO 3000 PSI. BREAK DN TRI-STATE SPEAR & LD. MU REVERSE CIRC JET BASKET & RIH. TAG SAND FILL @ 670'. WASH DN TO 689' TO PU ANY JUNK IN BASKET. POOH. LD TRI-STATE TOOLS, NO JUNK IN BASKET. MU BAKER BP RETRIEVING TOOL & RIH. TAG SAND @ 689', WASH DN TO 718' & LATCH ONTO BP. ROTATE & RELEASE BP. CIRC VISC BRINE OUT OF WELL WITH CLEAN BRINE. POOH. LD BRIDGE PLUG & RETRIEVING TOOL. SET WEAR BUSHING. LOAD 50 JTS DP IN SHED, STRAP SAME. MU 6-1/8" RR BIT & 7" SCRAPER. RIH ON 4-4-3/4" DC & 3-1/2" DP. CONT RIH. PU SINGLES TO TAG BTM. WELL: 1Y-17 API: 50-029-22368 PERMIT: 93-68 PAGE: 4 09/16/93 (14) TD: 8050 PB: 7950 09/17/93 (15) TD: 8050 PB: 7950 09/18/93 (16) TD: 8050 PB: 7950 PREP T/RIH W/PKR 7"@ 8034' MW:ll.5 NaCl/Br SERV RIG. FUNCTION BOP. CONT RIH. TAG PBTD @ 7937' NORDIC RKB. PU 1' OFF BTM & CIRC HOLE CLEAN. POOH. LDDP. LD DC, BIT, & SCRAPER. PULL WEAR BUSHING. RU SWS. TEST LUB TO 1000 PSI. PERF A & C SANDS IN 4 GUN RUNS: A SAND F/7730'-7748' ORIENTED, C SAND F/7519'-7585' NONORIENTED. RUN 6" GAUGE RING & JB TO 7700' RECOVERED + 1 GALLON OF PERF DEBRIS ON FIRST RUN. LD 6~ GR & JB. PU--BAKER MODEL D PERM PKR W/5' SEAL BORE EXTENSION + 8' PUP 2-7/8" TBG + D NIPPLE + 8' PUP + CAMCO SOS. MU ON WL SETTING HEAD & PREPARE TO RIH. RIH 7"@ 8034' MW:ll.5 NaC1/Br RIH W/BAKER MODEL D PERM PKR. SET TOP @ 7620' ELM. POOH. RD SWS. RU TBG TOOLS. RUN 3-1/2" X 4" SS COMP ASSY. TEST CONTROL LINE TO 5000 PSI WHEN MU TO SSSV & HGR. PRESS TBG TO 2500 PSI TO SET PKR, CAMCO SOS SHEARED JUST AS 2500 PSI WAS REACHED. CALL OUT OTIS SL UNIT. CHANGE OUT LANDING JT & INSTALL PMP-IN T. RU OTIS SL. TEST LUB TO 1000 PSI. RIH W/STANDING VALVE TO SET IN 2.25" D-NIPPLE. RIG RELEASED 7"@ 8034' MW:ll.5 NaC1/Br RIH & SET STANDING VALVE IN D-NIPPE @ 7656'. POH W/SL. ATTEMPT TO PRESS TBG TO FIN SETTING PKR, STANDING VALVE LEAKING. RIH & PULL STANDING VALVE. RERUN & RESET STANDING VALVE IN D-NIPPLE. PRESS TBG TO 3000 PSI & HOLD FOR 30 MIN TO COMPLETE SETTING PKR. POOH W/SL. TEST ANN TO 2500 PSI, OK. BLEED OFF PRESS. BOLDS. PU TO SHEAR PBR, FOUND IT HAD SHEARED W/PRESS. RELAND. RILDS. TEST CSG & TBG TO 2500 PSI, OK. BLEED PRESS DN TO 1000 PSI, CLOSE SSSV, BLEED TBG ABOVE SSSV TO 500 PSI. TEST SSSV FOR 15 MIN, OK. EQUALIZE & REOPEN SSSV. RIH W/SL & RETRIEVE STANDING' VALVE. RD SL. SET BPV. CLOSE SSSV. ND BOPE. NU FMC GEN IV 4-1/16" 5000 PSI TREE. PULL TEST PLUG. REVERSE CIRC 11 BBLS DIESEL INTO ANN. BULLHEAD 6 BBLS DIESEL DN TBG. CHECK VALVE IN GLM @ 7361', HELD. SECURE WELL. SET BPV. MOVE RIG OFF WELL @ 1530 HRS. CLEAN UP AROUND WELL SITE. CLEAN PITS & HAUL OFF BRINE. INSTALLED REAR AUX WHEELS IN CELLAR AREA WHILE CLEANING PITS. RELEASE RIG @ 1800 HRS 09/17/93. SIGNATURE: (d~uperint~nt SUB - SURFA CE DIRECTIONAL SURVEY ~1 UIDANCE [~ ONTINUOUS r'~ OOL ..~SK~ ,~_,... Gas Anchor~e Company ARCO ALASKA, INC. Well Name 1¥-17 (Z08' FNL, lZZ4' F~L, SEC ! Field/Location KUPARUK, NORTH SLOPE, ALASKA,~ Job Reference No. Date ~ss ~i~ Loc~cjecl By: ~-~ I C R 0 II~l L ~ i~ ~ Com~pT:te~g:: · SCHLUMBERGER * . * OCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1Y-l? KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 27-MAY-1993 ENGINEER: JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH $0 DEG $8 MIN WEST COMPUTATION DATE' 21-JUN-93 PAGE 1 ARCO ALASKA, INC. 1Y-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 27-MAY-1993 KELLY BUSHING ELEVATION' 105.00 FT ENGINEER' JEFF FORMICa 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 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -105 O0 lO0 2OO 3OO 399 499 599 699 799 899 O0 -5 O0 O0 95 O0 O0 195 O0 99 294 98 394 96 494 95 594 93 694 59 794 0 0 N 0 0 E 0 6 S 54 21E 0 22 S 26 53 E 0 32 S I 47 E 99 0 34 S 11 39 E 98 0 56 S 33 30 E 96 I 11 S 27 21E 95 0 34 S 17 31E 93 2 38 N 45 30 W 59 6 4 N 43 29 W 0 O0 -0 12 -0 46 -0 94 -1 77 -3 03 -4 64 :6 16 -5 O4 2 92 0 O0 1 37 0 35 0 75 0 69 0 04 0 66 0 67 5 75 I 98 0 O0 N 0 06 N 0 44 S I 07 S I 96 S 3 36 S 4 98 S 6 36 S 5 87 S 0 11S 0 O0 E 0 20 E 0 23 E O34 E 0 68 E I 18 E 194 E 2 77 E 174 E 3 85 W 0.00 N 0 0 E 0.21 N 73 50 E 0.50 S 27 24 E I 12 S 17 23 E 2 08 S 19 13 E 3 56 S 19 22 E 5 34 S 21 18 E 6 94 S 23 31E 6 12 S 16 29 E 3 85 S 88 19 W 1000.00 998.84 893.84 7 55 1100.00 1097.56 992.56 10 8 1200.00 1195.80 1090.80 11 43 1300 O0 1292.87 1187.87 15 57 1400 O0 1388.02 1283.02 20 4 1500 O0 1480.44 1375.44 24 30 1600 O0 1570.02 1465.02 28 10 1700 O0 1656.85 1551.85 31 27 1800 O0 i740.70 1635.70 34 45 1900 O0 1821.12 1716.12 38 21 N 41 3 W N 42 32 W N 44 49 W N 48 55 W N 47 35 W N 48 16 W N 47 25 W N 46 0 W N 45 49 W N 46 12 W 14 95 30 63 49 18 73 05 103 69 141 77 186 12 235 55 289 79 348 97 2 64 1 O0 3 50 3 31 5 21 5 11 4 23 3 26 2 66 2 20 8 94 N 20 34 5O 71 96 126 160 198 239 86 N 22 42 N 35 63 N 52 01N 75 60 N 104 29 N 137 35 N 173 30 N 212 54 N 255 12 O0 W 14 96 N 53 19 W 53 W 30 70 N 47 12 W 40 W 49 38 N 45 49 W 99 W 73 29 N 46 18 W 92 W 103 95 N 46 55 W 20 W 142 09 N 47 10 W 21 W 186.48 N 47 22 W 24 W 236.05 N 47 13 W 30 W 290.51 N 46 57 W 05 W 349.90 N 46 48 W 2000.00 1897.95 1792.95 41 11 2100.00 1972.95 1867.95 41 37 2200.00 2046.79 1941.79 43 55 2300 O0 2117.99 2012.99 44 47 2400 O0 2188.13 2083.13 46 21 2500 O0 2256.99 2151.99 46 41 2600 O0 2324,41 2219.41 48 21 2700 O0 2390.55 2285.55 48 47 2800 O0 2456.45 2351.45 48 48 2900 O0 2522.71 2417.71 47 33 N 45 33 W N 45 3 W N 45 4 W N 45 8 W N 47 32 W N 47 45 W N 47 10 W N 46 57 W N 48 22 W N 49 4 W 1057 412 71 478 53 545 57 615 42 686 42 758 82 832 53 907 35 982 44 27 0 75 0 67 3 92 0 24 1 50 1 03 0 96 0 78 0 44 2 61 284 03 N 301 03 W 413.88 N 46 40 W 330 378 427 477 526 576 627 677 727 61 N 348 O1 W 480.01 N 46 28 W 36 N 395 60 W 547.41 N 46 17 W 91 N 445 36 W 617 61 N 46 9 W 41 N 496 62 W 688 88 N 46 8 W 16 N 550 30 W 761 36 N 46 17 W 09 N 604 71 W 835 20 N 46 23 W 28 N 659.53 W 910 20 N 46 26 W 83 N 715.22 W 985 39 N 46 32 W 45 N 771,32 W 1060 25 N 46 41W 3000 O0 2590.84 2485.84 46 50 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2659.46 2554.46 46 33 O0 2728.49 2623.49 46 10 O0 2797.99 2692 99 45 44 O0 2867.81 2762 81 45 41 O0 2937.79 2832 79 45 33 O0 3007.96 2902 96 45 12 O0 3078.64 2973 64 44 51 O0 3149.71 3044 71 44 35 O0 3220.45 3115.45 45 22 N 49 3 W 1130.44 N 48 47 W 1203 13 N 48 49 W 1275 43 N 51 3 W 1347 30 N 52 12 W 1418 87 N 51 32 W 1490 30 N 50 46 W 1561 55 N 50 57 W 1632.29 N 50 47 W 1702.64 N 52 15 W 1773.31 0.81 0 36 0 22 3 76 0 17 0 92 0 77 0 31 0 40 0 47 775 24 N 826 77 W 1133 38 N 46 51W 823 14 N 881 52 W 1206 870 78 N 935 96 W 1278 917 53 N 990 59 W 1350 961 60 N 1047 O0 W 1421 1005 63 N 1103 25 W 1492 1050.46 N 1158.63 W 1563 1095.09 N 1213.51W 1634 O8 N 46 58 W 39 N 47 4 W 23 N 47 12 W 58 N 47 26 W 81 N 47 39 W 94 N 47 48 W 58 N 47 56 W 1139.54 N 1268.05 W 1704.84 N 48 3 W 1183.54 N 1323.35 W 1775.40 N 48 12 W COMPUTATION DATE' 21-JUN-93 PAGE 2 ARCO ALASKA, INC. 1Y-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 27-MAY-1993 KELLY BUSHING ELEVATION' 105.00 FT ENGINEER' JEFF FORMICA 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 4000 O0 3290 86 3185.86 45 5 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3361 O0 3431 O0 3502 O0 3572 O0 3643 O0 37~4 O0 3782 O0 3850 O0 3917 74 3256.74 44 53 93 3326.93 45 40 02 3397.02 45 19 70 3467.70 44 36 99 3538.99 44 40 67 3609.67 45 57 85 3677.85 47 31 39 3745.39 47 35 81 3812.81 47 31 N 52 10 W 1844.30 N 52 29 W 1914.82 N 53 51W 1985.99 N 54 15 W 2057,.20 N 54 29 W 2127.83 N 54 57 W 2197.80 N 55 10 W 2268.36 N 55 33 W 23~1.30 N 55 46 W 2414.80 N 55 52 W 2488.39 0 36 1 53 0 56 0 27 1 40 0 43 3 63 0 39 0 28 0 32 1227 04 N 1379 48 W 1846 23 N 48 21 W 1270 1312 1354 1395 1436 1476 1518 1560 1601 24 N 1435 86 N 1492 66 N 1550 98 N 1607 41N 1664 95 N 1722 55 N 1782 14 N 1843 65 N 1904 23 W 1916 31W 1987 09 W 2058 52 W 2129 82 W 2198 79 W 2269 96 W 2341 85 W 2415 94 W 2488 61 N 48 29 W 61 N 48 40 W 61 N 48 51W 05 N 49 2 W 84 N 49 13 W 22 N 49 24 W 99 N 49 35 W 33 N 49 46 W 79 N 49 57 W 5000 O0 3985 32 3880.32 47 30 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4052 O0 4120 O0 4187 O0 4255 O0 4323 O0 4390 O0 4459 O0 4528 O0 4600 84 3947 84 47 33 31 4015 77 4082 34 4150 08 4218 84 4285 29 4354 89 4423 31 4495 31 47 35 77 47 33 34 47 25 08 47 18 84 47 21 29 46 16 89 45 20 31 43 39 N 56 6 W 2561 88 N 56 8 W 2635 N 56 9 W 2708 N 56 18 W 2782 N 56 35 W 2855 N 56 50 W 2928 N 56 48 W 3002 N 54 45 W 3074 N 53 18 W 3146 N 51 56 W 3216 34 85 37 75 95 10 75 43 40 0 27 0 O8 0 25 0 33 0 55 0 23 I O3 0 48 2 58 2 32 1642.91 N 1966 09 W 2562 16 N 50 7 W 1684.05 N 2027 1725.17 N 2088 1766.25 N 2149 1807.01N 2211 1847.41 N 2272 1887.59 N 2334 1928.71 N 2394 1970.76 N 2452 2013.43 N 2508 31W 2635 61W 2708 94 W 2782 37 W 2855 84 W 2928 44 W 3002 63 W 3074 82 W 3146 53 N 50 17 W 97 N 50 27 W 43 N 50 36 W 77 N 50 45 W 95 N 50 54 W 10 N 51 2 W 76 N 51 9 W 46 N 51 13 W 30 W 3216.44 N 51 15 W 6000 O0 4674 19 4569.19 41 21 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4750 O0 4829 O0 4909 O0 4991 O0 5075 O0 5160 O0 5246 O0 5332 O0 5420 42 4645.42 39 8 35 4724.35 37 3 85 4804.85 35 45 63 4886 63 34 7 20 4970 20 32 29 10 5055 10 31 13 15 5141 15 29 56 99 5227 99 29 29 72 5315 72 27 53 N 51 11W 3283 77 N 50 56 W 3348 N 51 10 W 3409 N 5O 0 W 3469 N 48 45 W 3526 N 48 13 W 3581 N 47 56 W 3634 N 47 54 W 3685 N 47 56 W 3734 N 48 11W 3782 SO 89 22 73 58 35 23 74 67 3 05 4 68 2 O6 2 09 2 83 1 20 I 19 0 60 0 57 0 35 2055 41N 2561 O0 W 3283.81 N 51 15 W 2O96 2134 2172 2209 2246 2281 2315 2348 2381 16 N 2611 29 W 3348.54 N 51 15 W 76 N 2659 02 W 3409.93 N 51 14 W 28 N 2704 99 W 3469 25 N 51 14 W 79 N 2748 61 W 3526 76 N 51 12 W 24 N 2789 67 W 3581 60 N 51 10 W 56 N 2828 98 W 3634 37 N 51 7 W 70 N 2866 79 W 3685 23 N 51 4 W 96 N 2903.55 W 3734 74 N 51 2 W 03 N 2939.26 W 3782 67 N 50 59 W 7000 O0. 5509 55 5404 55 26 44 7100 O0 5599 7200 O0 5690 7300 O0 5782 7400 O0 .5874 7500 O0 5967 7600 O0 6060 7700 O0 6153 7800.00 6246 54 5494 85 5585 71 5677 77 5769 30 5862 26 5955 28 6048 72 6141 7900.00 6340.80 6235 54 25 2 85 23 26 71 23 4 77 22 S1 30 21 40 26 21 45 28 21 16 72 20 23 80 19 25 N 49 0 W 3828.53 N 50 14 W 3872.13 N 50 20 W 3912.88 N 50 22 W 3952 39 N 49 57 W 3991 45 N 49 36 W 4029 35 N 49 41W 4066 20 N 48 45 W 4102 89 N 47 59 W 4138 48 N 47 5 W 4172 28 1 . 28 1.21 0.04 0.22 0.66 0.73 0.47 0.86 1.17 0.00 2411 44 N 2973 66 W 3828 53 N 50 58 W 2439 2465 2490 2516 2540 2564 2588 2611 2634 66 N 3006 70 N 3038 96 N 3068 O0 N 3098 48 N 3127 37 N 3155 31N 3183 97 N 3210 90 N 3235 90 W 3872 25 W 3912 64 W 3952 62 W 3991 56 W 4029 63 W 4O66 45 W 4102 08 W 4138 02 W 4172 13 N 5O 57 W 88 N 50 56 W 39 N 50 56 W 45 N 50 55 W 35 N 50 55 W 2O N 5O 54 W 89 N 50 53 W 48 N 50 52 W 29 N 50 50 W ARCO ALASKA, INC. 1Y-17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 21-JUN-93 PAGE 3 DATE DF SURVEY: 27-MAY-1993 KELLY BUSHING ELEVATION: 105.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTL~E 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 6435.11 6330.11 19 25 N 47 5 W 4205.46 8050.00 6482.26 6377.26 19 25 N 47 5 W 4222.05 0.00 2657.55 N 3259,37 W 4205.48 N 50 48 W 0.00 2668.88 N 3271.54 W 4222.07 N 50 48 W COMPUTATION DATE: 21-JUN-93 PAGE 4 ARCO ALASKA, INC. iY-i7 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 27-MAY-1993 KELLY BUSHING ELEVATION: 105.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 8050 0 O0 -105 O0 0 0 N 0 0 E O0 998 84 893 O0 1897 95 1792 O0 2590 84 2485 O0 3290 86 3185 O0 3985 32 3880 O0 4674 19 4569 O0 5509 55 5404 O0 6435 11 6330 O0 6482 26 6377 0 O0 0 O0 000 N 84 7 55 N 41 3 W 14 95 95 41 11 N 45 33 W 412 71 84 46 50 N 49 3 W 1130 44 86 45 5 N 52 10 W 1844 30 32 47 30 N 56 6 W 2561 88 19 41 21 N 51 11 W 3283.77 55 26 44 N 49 0 W 3828,53 11 19 25 N 47 5 W 4205.46 26 19 25 N 47 5 W 4222.05 64 8 75 284 81 775 36 1227 27 1642 05 2055 28 2411 O0 2657 O0 2668 94 N 12 03 N 301 24 N 826 04 N 1379 91N 1966 41N 2561 44 N 2973 55 N 3259 88 N 3271 O0 W 14 03 W 413 77 W 1133 48 W 1846 09 W 2562 O0 W 3283 66 W 3828 37 W 4205 54 W 4222 0 O0 E 0 O0 N 0 0 E 96 N 53 19 W 88 N 46 40 W 38 N 46 51W 23 N 48 21W 16 N 50 7 W 81 N 51 15 W 53 N 50 58 W 48 N 5O 48 W 07 n 50 48 W COMPUTATION DATE' 21-JUN-93 PAGE 5 ARCO ALASKA, INC. 1Y-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 27-MAY-1993 KELLY BUSHING ELEVATION' 105.00 FT ENGINEER' JEFF FORMICA 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 BIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 105 O0 205 O0 305 O0 405 O1 505 02 605 O4 705 05 805 08 905 44 0 O0 -105 O0 105 205 305 405 505 605 705 805 905 O0 0 O0 O0 100 O0 O0 2O0 O0 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 0 0 N 0 0 E 0 7 S 25 46 E 0 22 S 29 34 E 0 33 S 5 18 E O0 0 36 S 9 59 E O0 0 56 S 33 4 E O0 I 11 S 28 39 E O0 0 33 S 14 51E O0 2 55 N 45 5 W O0 6 10 N 43 14 W 0 O0 -0 13 -0 49 -0 97 -1 81 -3 11 -4 74 -6 20 -4 80 3 49 0 O0 1 27 0 28 0 74 0 74 0 10 0 50 0 57 5 39 2 03 0.00 N 0.05 N 0.47 S 1.12 S 2.01 S 3.42 S 5.07 S 6.41 S 5.69 S 0.31 N 0 O0 E 0 21 E 0 24 E 0 34 E 0 69 E 1 22 E 1 99 E 2 78 E 1 56 E 4 25 W 0 O0 N 0 0 E 21 N 75 39 E 53 S 27 20 E 17 S 16 50 E 13 S 19 1E 64 S 19 40 E 45 S 21 26 E 99 S 23 28 E 90 S 15 20 E 26 N 85 50 W 1006 22 1005 O0 1107 1209 1312 1418 1527 1639 1756 1879 2009 55 1105 4O 1205 63 1305 15 1405 13 1505 92 1605 96 1705 54 1805 37 1905 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 8 4 O0 10 12 O0 12 4 O0 16 21 O0 21 2 O0 25 42 O0 29 21 O0 33 9 O0 37 40 O0 41 15 N 4O 53 W N 42 42 W N 45 13 W N 49 0 W N 47 33 W N 48 15 W N 46 44 W N 45 48 W N 46 11W N 45 29 W 15 80 31 95 51 10 76 56 110 09 153 27 205 31 265 84 336 42 418 85 2 63 0 93 4 21 3 11 5 45 3 62 2 8O 4 07 4 49 0 63 9 59 N 21 35 52 75 104 139 181 230 288 84 N 23 78 N 36 94 N 55 34 N 80 26 N 112 40 N 151 53 N 195 81N 245 36 N 305 43 W 32 77 W 51 64 W 76 65 W 110 78 W 153 29 W 205 07 W 266 97 W 337 43 W 420 12 57 W 15 81 N 52 39 W 03 N 47 1W 31 N 45 47 W 8O N 46 25 W 36 N 46 57 W 59 N 47 15 W 72 N 47 20 W 46 N 47 4 W 30 N 46 49 W O5 N 46 39 W 2142.99 2005 O0 1900 O0 42 1 2281.70 2105 2424.46 2205 2570 86 2305 2721 93 2405 2873 58 2505 3020 68 2605 3166 06 2705 3310 05 2805 3453 17 2905 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 N 44 49 W O0 44 46 N 45 8 W 602 O0 46 27 N 47 48 W 704 O0 48 5 N 47 21W 810 O0 48 50 N 47 14 W 923 O0 48 16 N 48 38 W 1037 O0 46 45 N 48 54 W 1145 O0 46 15 N 48 49 W 1250 O0 45 43 N 51 25 W 1354 O0 45 34 N 51 59 W 1456 507 03 60 11 84 81 68 50 94 49 87 1 80 0 11 0 30 1 15 1 54 3 35 0 63 0 32 2 97 0 57 350 90 N 368 24 W 508.66 N 46 23 W 418 489 561 638 714 785 854 922 984 81N 436 34 N 509 33 N 588 52 N 671 54 N 756 14 N 838 65 N 917 02 N 996 94 N 1076 22 W 604.72 N 46 10 W 71 W 706.59 N 46 10 W 75 W 813.46 N 46 22 W 61 W 926;70 N 46 27 W 56 W 1040.65 N 46 38 W 13 W 1148.44 N 46 52 W 52 W 1253.90 N 47 2 W 21 W 1357.41 N 47 13 W 99 W 1459.46 N 47 33 W 3595 81 3005.00 2900.00 45 13 3737 3878 4020 4161 4304 4445 4586 4732 4881 15 3105.00 3000.00 44 44 04 3205.00 3100.00 45 16 O1 3305.00 3200.00 44 59 48 3405 O0 3300.00 45 36 23 3505 O0 3400.00 45 18 28 3605 O0 3500.00 44 27 14 3705 O0 3600.00 45 31 78 3805 O0 3700.00 47 28 03 3905 O0 3800.00 47 34 N 50 45 W 1558.58 N 50 51 W 1658.46 N 52 3 W 1757.70 N 52 9 W 1858 46 N 53 29 W 1958 48 N 54 15 W 2060 21 N 54 51W 2159 49 N 55 8 W 2258 47 N 55 38 W 2365 38 N 55 50 W 2474 44 0.87 0.34 1.31 0.87 1.15 0.19 0.54 3.34 0.24 0.05 1048 58 N 1156 33 W 1560 97 N 47 48 W 1111 1173 1235 1296 1356 1414 1471 1532 1593 60 N 1233 82 W 1660 71 N 47 59 W 95 N 1311 03 W 1759 82 N 48 9 W 73 N 1390 66 W 1860 37 N 48 23 W 54 N 1470 12 W 1960 17 N 48 35 W 42 N 1552 54 W 2061 61 N 48 51W 32 N 1633 41 W 2160.63 N 49 7 W 28 N 1714 64 W 2259.35 N 49 22 W 20 N 1802.89 W 2366.02 N 49 38 W 79 N 1893.35 W 2474.87 N 49 55 W COMPUTATION DATE: 21-JUN-g3 PAGE 6 ARCO ALASKA, INC. 1Y-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 27-MAY-1993 KELLY BUSHING ELEVATION: 105.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5029 13 4005 O0 3900 O0 47 30 5177 5325 5473 5620 5765 5906 6040 6169 6294 30 4105 O0 4000 52 4205 O0 4100 33 4305 O0 4200 87 4405 O0 4300 86 4505 O0 4400 45 4605.00 4500 73 4705.00 4600 39 4805.00 4700 03 4905.00 4800 O0 47 34 O0 47 30 O0 47 19 O0 47 12 O0 45 49 O0 43 27 O0 40 30 O0 37 33 O0 35 49 N 56 6 W 2583 27 N 56 8 W 2692 N 56 22 W 2801 N 56 46 W 2909 N 56 25 W 3017 N 53 54 W 3122 N 51 52 W 3220 N 50 58 W 3310 N 51 3 W 3391 N 50 7 W 3465 17 11 45 35 O7 83 42 34 72 0 33 0 10 0 34 0 34 2 31 I 56 2 90 I 13 I 23 2 20 1654 89 N 1983 92 W 2583 52 N 50 10 W 1715 1776 1836 1896 1956 2016 2072 2123 2170 84 N 2074 69 N 2165 67 N 2256 02 N 2347 28 N 2433 17 N 2511 16 N 2581 11N 2644 03 N 2702 70 W 2692 30 N 50 24 W 61W 2801 15 N 50 38 W 44 W 2909 45 N 50 51W 24 W 3017 36 N 51 4 W 20 W 3122 10 N 51 12 W 78 W 3220 86 N 51 15 W 73 W 3310.46 N 51 15 W 58 W 3391.38 N 51 15 W 31 W 3465.76 N 51 14 W 6416 12 5005 O0 4900 O0 33 48 6535 25 5105 6652 36 5205 6767 82 5305 6882 20 5405 6994 9O 5505 7106 O1 5605 7215.42 S705 7324.22 5805 7432.77 5905 O0 5000 O0 32 8 O0 5100 O0 30 40 O0 5200 O0 29 39 O0 5300 O0 28 4 O0 5400 O0 26 47 O0 5500 O0 24 55 O0 5600 O0 23 24 O0 5700.00 23 2 O0 5800.00 22 32 N 48 32 W 3535.72 N 48 6 W 3600.40 N 47 57 W 3661.24 N 47 52 W 3718 88 N 48 9 W 3774 31 N 48 57 W 3826 24 N 50 14 W 3874 65 N 50 18 W 3919 01 N 50 15 W 3961 88 N 49 49 W 4004 09 1 45 1 25 1 63 0 51 1 15 1 10 1 55 0 10 0 46 1 38 2215 73 N 2755 36 W 3535 75 N 51 12 W 2258 2299 2338 2375 2409 2441 2469 2497 2524 82 N 2803 61N 2848 32 N 2891 45 N 2933 93 N 2971 27 N 3008 61N 3042 01N 3075 15 N 3108 7O W 36OO 96 W 3661 78 W 3718 03 W 3774 93 W 3826 84 W 3874 97 W 3919 94 W 3961 29 W 4004 42 N 51 9 W 25 N 51 5 W 88 N 51 2 W 31 N 51 0 W 24 N 50 58 W 65 N 5O 57 W O1 N 50 56 W 88 N 50 56 W 10 N 50 55 W 7540 54 6005 O0 5900.00 21 33 7648 14 6105 O0 6000.00 21 33 7755 42 6205 O0 6100.00 20 51 7862 03 6305 O0 6200.00 19 38 7968 08 6405 O0 6300.00 19 25 8050 O0 6482 26 6377.26 19 25 N 49 32 W 4044.26 N 49 22 W 4083.96 N 48 23 W 4122.79 N 47 13 W 4159.67 N 47 5 W 4194.87 N 47 5 W 4222.05 0 58 0 60 0 91 1 10 0 O0 0 O0 2550 16 N 3138 gl W 4044.26 N 50 55 W 2575 90 N 3169 14 W 4083.96 N 50 54 W 2601 50 N 3198 38 W 4122.79 N 50 53 W 2626 28 N 3225 77 W 4159.68 N 50 51W 2650 32 N 3251 59 W 4194.89 N 50 49 W 2668 88 N 3271 54 W 4222.07 N 50 48 W COMPUTATION DATE: 21-JUN-93 PAgE 7 ARCO ALASKA, INC. 1Y-17 KUPARUK RIVER NORTH SLOPE, ALASKa MARKER 9 5/8" CASING TOP KUPARUK C GCT LAST READING PBTD 7" CASING TD DATE OF SURVEY: 27-MAY-1993 KELLY BUSHING ELEVATION: 105.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 208 FNL A 1224 FWL, SEC1 TllN RgE MEASURED DEPTH BELOW KB 'TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4400 O0 7514 O0 7899 90 7950 O0 8035 O0 8050 O0 3572 70 5980 32 6340 71 6387 95 6468 11 6482 26 3467 70 5875 32 6235 71 6282 95 6363 11 6377 26 1395.98 N 2543.82 N 2634.87 N 2646.23 N 2665.48 N 2668.88 N 1607 52 W 3131 48 W 3235 O0 W 3247 19 W 3267 89 W 3271 54 W COMPUTATION DATE: 21-JUN-93 PAGE 8 ARCO ALASKA, INC. 1Y-17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 27-MAY-1993, KELLY BUSHING ELEVATION: 105.00 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY ************ MARKER SURFACE LOCATION = 208 FNL ~. 1224 FWL, SEC1 T11N RgE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST TOP KUPARUK C PBTD TD 7514.00 5980.32 5875.32 2543.82 N ,3131.48 W 7950.00 6387.95 6282.95 2646.23 N 3247.i,9 W 8050.00 6482.26 6377.26 2668.88 N 3271:54 W FINAL WELL LOCATION AT 11): TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8050.00 6482.26 6377.26 4222.07 N 50 48 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WELL 1Y-1 7 COUNTRY USA RUN ONE DATE LOGGED 27 - MAY - 93 DEPTH UNIT FEET REFERENCE 93255 guarantee the accuracy or correctness of any Interpretations. and we shall not. except In the case of gross or wllfull negligence on our par[. be liable or responsible for any loss. costs, damages or expenses Incurred or sustained by anyone resulting from any interpretation made by any of our officer~, agents or employees. These interpretations ere also subject to our ('~eneral Terms and Conditions as set out In our current price ~chedule. _ #ELL' 1¥-17 (208' FNL, 1224' FWL, SE(: 1, T11N, RgE, tiN) HORIZONTAL PROJECTION NORTH 5000 REF 93255 4OOO 30O0 2O00 1000 - 1000 ~2OO0 SOUTH -3000 -5OOO SCALE= 1/ 1000 ~N/FT iii !:i!,~ii: i;!i i.!: ii!! !i:: :::! :~!!,~ .: ::.ii ~;~ ~:i~.-ii.i.i..i-i..i..~...i~..i.~.i.i.i.. i..L.i~. ~L.~..~..'.~.i;~:i;;;:;.; ii!. .:; ......... i...;i..L.ii...i--i i..i..i...i---i.i..-i--.i ...... ii--.i--.i .... ii.i...i ..... i.-i-..i.i .... i.~..i...i .... i..i..i-..;...i...iii..i...;..;; ..;i:..i i~ i. ii.i .~i..ii...i. ~.i..!i.! .... i..i_i..! .... iii~.~!. !.iil...ii-i..i.-~!...!-i-~i..i..i.i!. i!i.i ~.!..! : .!i!! ~ :.i ....... .::. :.:. :.:: :::: .:.: ::::,::: :::. .:: :::. :: :. .::- :::,~:::. ::.: ::-: :::: :.:: :.:: .::: .:. :. ..:: .. !!!~ ~!-!-!!':!~ !-!...!--!.-!!! ..... !.~!..! !!-!!.-:-!!!.- !!.-!!-.!!!.!-.:!'' !.~ ! .............. · ::- .:: .:: :~:: ::': :::: :.-: ,::: .:.: ::.: ,:: :::. : -- :: .:: :::. .::: :: ...... :: : .. ::: .... ;.i .... ; .i~.,.~.;...~...;.; ..~...~...~..;...;.;...;..;..;.;,.; ;;~...;i.;.~..;...~.. ~.,...;.~..~..~.).~ ..... ~.~.., ~..,~..~..;;, ; : ,., : : .: .: ::.. : : -..:-:: : : : ...... ........................................ ........................................ i ~;;. ;[~ i~.~;;L,.~;..~.;i.i .~i~[ ~Li.i;.i.i; ~.~.i~ :i~ ;.[..~..[~,~; ;.; ........ ~ i! :!!~ i ! : :i!: :ii: ::i. !~:. i::!': : : : i:: ................. ::~ ..... ~'~-?-'? .... ~-'~-: .... '-'-:~ ...... ,'~'-?-;-':'-:--'~ .... ?i')~',~':-!-'~-'.-~'~-~--' ~-,"~-'~; ~'~'+i "~'~ ~!~ ';~": :"~ ..... ! ........ ~ .... i '! ~-!-i "~'i-i'~'': ~-" ~ ~!~ ::~: ii}i .... i-.i-i!- :!~-} ...... iii---i..-ii~.i i}.--!..i }~i.i---i.~-.}-:-}~.ii~.;.~i.: ........ :: ...... : -:: :::. . -: . : . . . . ~,}i ..... ' ::: ':'' :: ' ' ' ~ ,.i.i ~ i.~ !..! i i ...... ~ i-i..! !.i.i i..i ~ : ! ! i.} ! ! ! ! ~- i i ! ; ~ ! ! i i } : ~ i~,i !!i.i i..i.!..::.:..: !:i.~ .!.{;! .ii: ::ii ii!~ i:i: .... ..... .......................... ....... i ""'~'"i'"'}"i'"!-'i ..... i-'-!--i---! ..... i"!"i'"i ...... i"!"'i'"'i'i'"!'"i'i ...... :"'!'!~ .... i'"ii'i"'i"!!": .... !~",'!' :'~:'!' ::: '!~': .... ; ; ; ;- --; ;~; ;~ --! i i-! ' : : : : : : : .... ! : ~ ~ ~ ~-~ ~ , !-~ ~- -. ........ ....................... i ~ i : i :..}.~ .i.l.i.~ i- L.i..i .... i..i i-i ..: i i ~ ~ : ; i i i.i ~ i i.i ; i ~ ~ ;. : ; : i ~.: : ~ : ' . : :. :::: :.: :.: ~.: i~i. ;i.i.; -;.ii..i. ~..i~-i...i...;.i-..i..i :.;i. il ;i-i; i~;..i. ;iii ;.i i.i .:.;: ~., :.; !~!-! !!-.i.i ...... i.~i.i.~,i ..... :i.!.i ...... !...!...!.i ...... i.!!..! i..ii~..!.:...i.ii~..! ..... i.!.ii :.i..i! .... ,..i..!.~.:.i..i. :..: -4000 -3000 -2000 - 1000 0 1000 2000 3000 WEST EAST WELL' 1Y-17 (208' FNL, 1224' Fi~, SEC 1, IllN, RgE,. b~) VERTICAL PROdECTION 129.00 -2000 -1000 0 0 1000 2000 3000 4000 5000 6000 :::: ::::::iii ~!-.-!-!-. !--i-.-i-i--.~--i---~-~--~---?-'~ ....... ~b(:~3.2000 .... :i:: i::i :~': ' ;! ....... i ....... !..!.!..;..;i...;...;.-.i.-.1 ;..'..'.: i..ii .y-E.-.L.'a ~ooo.;. i.:.;~ ~: .. ~. ~..~.: .............. ~.. ! ~ i : ; i i.! ..i i ! i.. i.i.i~,.: : , : i ~ i ' i ~ : · ~ ! ~ ~ -! : ~ !- ...... !.i ~ : : ,.. : : : : : ' .... ..... : ! : ~ ; i ~ ! : : ' : : .... ;. .;.; : :--. : h, ...... ,-, . , ......... ~--?'-r, ':'"; ' : "; : "F";'~ :'; ~ : ; ; : : ' ............ : . ..: .... :: ~.::: :::: , : ~ ~ : ~ ~ ~ ~ }-} ~ ~ .... ; ~ ;.~. ~-.~.; ~ ?i ~ ~ .~.: ~ ; ~ ¢ t ~ : : ; ~- ; · - : , · ~i-~,--~--~-i ...... ~-!!-.~ ...... ~.~-..i-.~-i--.~--!--! ..... ~-!---:--~-,-~--?! .-~-i:-:-.f~:- ~..}.~ ....: ~;'~' ,, ........ : . ~ ~ ~ ; .~ ; ~..~ .~ ; :..~ ~..; ~.~..-~--.~-}-~ .... ~ ~ ~ ~..~ ~ ~.~ ~ ~ ~ ; -~ ~'~ ~ ~ : : ~ : : · . : : ~ . : ..... ~-~. ~.~-~: .... ~_.~.~?..-~-.}.}...~..-~...~ .... ~.~}...~.~-.~-~...~--~?;~ ~:::.. ~- ~ .... ~.~ ~ ...... · ~.~--~-.~.-~-~ .... ~---~-i-~-l---~.-~---i.-~---h!.-h}--'!--h-~--;--,'--~---}~i'-f:'~---i .... ~'-,'~' ~":' !~':~ :'~: ..... ~ : : ; ; , :..~ ~ ......~..J ~.~..-l.-h-; i-; -~ ~--;-; ;-i-.~ ~ ; : } ~ ! ~ ~ : ~' : ' .... :': : ! ....... ....................... .~;.~ ..... ~.;..;...~....:.~...;...;...;...,...~...~...~...~ ..... ;...;...:..; ..... ;..~..;..: .... ;...;..;.;i.~..;.;~ ...... ;.;.;:..: ~: ..:- . : .... ~ ! i ~ ~ ;'F'F"~"?'?'; ~' '~ ; ; : '~ i';'; ; ~ : i ; : ~ : '; ; ; ~ ; : : ' : : : : ::: :::: :::: :::. .::: . . : . .... :.::~ ~:. .::: .; . ;.~.:..:...:..;.;...~..,..;...~...~ ~ .~...~..; ~ ..... ~.~ i..~ ..... ~-~.-~-!~.! ~.~.;--~-;-~ --~ : ~ ~- : ............... . ....... ....... ; ..................... .:...::..~.~ ..... ~ .... ~..~..:~ ....~...i..;..~.-:...~..~-..;..-F.?-;...~ ~7-; :--::'-:'; · .. : } ~ ~ .... ~.~ ~ ~ .... ~-}-~ ~- :-;.;.--i ..... !-~ ~--i-- ~.~-~ i ~-~ ; ~ .... ~'~ : ~''i : ; ~ '' ~ ~'~' : : ~ ~ .......... : ::.: :::: :::: ::: ::.: :::: ~;!i 309 O0 PROJECTION ON VERTICAL PLANE 129.00 309.00 SCALEC) IN VERTICAL DEPTH9 HORIZ SCALE = I / I 000 IN/FT ARCO Alaska, Inc. Date: August 20, 1993 Transmittal #: 8838 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following ~ items. receipt and return one signed copy of this transmittal. Y-23 Y-23 Y-23 H-14 H-14 H-13 H-13 H-13 Y-17' Y-17 Y-17 H-01 H-02 H-09 ,,~CDN LWD/Depth Corrected '~C D R Very-enhanced LWD/Depth Corrected · cC;DR LWD/Depth Corrected ~3DR LWD/Depth Corrected v..-CDR Enhancement LWD/Depth Corrected ~,-CDR Enhancement LWD/Depth Corrected v/CDN LWD/Depth Corrected ~.-CDR LWD/Depth Corrected ,,"CDR Enhancement LWD/ Depth Corrected ~/'CDR ~,," CDN ,,"CDR Enhancement LWD/ Depth Corrected v--CDR Enhancement LWD/ Depth Corrected v..CDR Enhancement LWD/ Depth Corrected 7-06-93 7-06-93 7-06-93 5-18-93 5-18-93 6-01-93 6-01-93 6-01-93 6-18-93 6-18-93 6-18-93 3-05-93 3-05-93 4-26-93 Receipt Acknowledged: DISTRIBUTION: Please acknowledge 3739-7499 3746-7497 3739-7499 4695-10524 4786-10522 6368-10165 6360-10167 6360-10167 4338-8025 432O-8045 736O-8045 7188-7942 7388-8O37 1 0855-11750 Date: ARCO Alaska, Inc. Date: July 23, 1993 Transmittal #: 8812 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '1,,-~29~' ~1 3"~LIs Tape and Listing: · 10-18-92 92622 ,~ ¢ /..,, ,//n,,'TBit Runs of CDR. Corrected HLDT ,~¢Z~.07 -.)'l LIS Tape and Listing: .9-18-93 92563 /,A? ,-.4,l,,,\ 3 Bit Runs of CDR. Corrected HLDT ~'~.,~-21 S'I ,. LIS Tape and Listing: '3-27-93 93132 Io~. ¥',~ -3,.L) CDR/CDN & QRO Enhanced Resistivity '~i¢',~-32 '3~ .~, LIS Tape and Listing: 11-17-92 ' 92686 k,~,'"'~\'\CDR Runs '1 & 2, Averaged Cased Hole HLDT ..NY-~ LIS Tape and Listing: 6-26-93 93292 ~ ,~-4~ DTE/SDN & CNTH ~rC/~ ~ ~' LIS Tape and Listing: '6-9-93 93263 ~0 J..,, ~/~ CDR/CDN & GR CBT in LDWG Format ~~?-22 "'ii)' !', LIS Tape and Listing: 5-29-93 93244 ~,~,~ _. ~..,~ \L~CDR/CDN in 1 Bit Run, GR from CBT )/.4.~-17 ¢1) ~. /LiS.Tape and Listing: 5-23-93 93241 ~,,\ i ,,,,/-.,cDR Runs 1 & 2, CDN Run 2, QRO Processed ~"~".~B<12 <:::J'~ '"LIS Tape and Listing: 5-18-93 93239 CNTG/HLDT & Arithmetic Average ___ Receipt Ackn~_~ / ,ll,J, iC/,,4,~,~,~~,'/Date: . DISTRIBUTION: Bob Ocanas State of Alaska ARCO Alaska, inc. Date: June 25, 1993 Transmittal #: 8778 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed copy of this transmittal. 1Y-17 Sub-Surface Directional Survey Please acknowledge receipt and 5-27-93 93255 Receipt Acknowledged: DISTRIBUTION: Date: D&M State of Alaska (2 copies) ARCO Alaska, Inc. Date: June 04, 1993 - Transmittal #: 8~56 RETURN TO: ARCO Alaska, inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 RY-17 Y-17 eceipt Acknowledge: Transmitted below are the following receipt and return one signed copy of thfs-t~.' Cement Evaluation Log Cement Bond Log 5-27-93 5-27-93 Date: Please acknowledge 6700-7939 6700-7918 Drilling ~Stafe--- ;o f A I as ka ( + sepia) WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION May 7, 1993 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 1Y-17 ARCO Alaska, Inc. Permit No: 93-68 Sur. Loc. 208'FNL, 1224'FWL, Sec. 1, TllN, R9E, UM Btmhole Loc. 2809'FNL, 2081'FEL, Sec. 35, T12N, 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° 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. David W. ~Johnston ~-~- Chairman ~ 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 ALA,SKA ALA, ~ OIL AND GAS CONSERVATION COMMISL PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r'~ lb Type of Well Exploratory ~--~ Stratigraphic Test r-] Development Oil X Re-Entry D Deepen E] Service E] Development Gas E] Single Zone X Multiple Zone r-] 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska~ Inc. RKB 105'~ Pad 64' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage, AK 99510-0360 ADL 25641~ ALK 2572 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 208' FNL, 1224' FWL, Sec. 1, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2919' FNL, 1945' FEL, Sec. 35, T12N, R9E, UM 1Y-17 #U-630610 At total depth 9. Approximate spud date Amount 2809' FNL, 2081' FEL, Sec. 35, T12N, R9E, UM 5/1 2/93 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 Y- 1 6 8037' M D 1224 @ TD feet 25.4' @ 660' MD feet 2560 6445' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 750 feet Maximum hole angle 46.86° Maximum surface 211 0 psig At total depth (TVD) 31 88 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Couplin~l Len~lth MD TVD MD 'I'VD linclude sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' 4-200 CF 12.25" 9.625" 36.0# J-55 BTC 4350' 41' 41' 4391' 3565' 490 Sx Permafrost E & HF-ERW 480 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 7996' 41' 41' 8037' 6445' 180SxClassG HF-ERW Top 500' Above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sC:, :cU:'°' Intermediate Production Liner [~/.~" '~ 'i~ Perforation depth: measured true verticalAlaska Oil & Gas Cons. Cornrnissioo Anr, horac~e 20. Attachments Filing fee X Property plat [~] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis r~ 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 Signed- ~/~/~J~ ~CommissionTitleuse Only Area Drillini~ Engineer Date Permit Number I APl number I Approval d a~e,~..-· I See cover letter for c:~,.~ ,~<:~ 50- d3,2,.~-- .,~_.. ~,- ~ ~ - 7 '""¢,.~ other recluirements Conditions of approval Samples required E] Yes ~,~ No Uud log required E] Yes [~ No Hydrogen sulfide measures [~ Yes J~ No Directional survey required ,~ Yes D No Required working pressure for BOPE D 2M ~ 3M ~] 5M E] 1OM [~ 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate I I V g 25O ,50O 750 1000 ARCO ALASKA, Inc. Sfrucfure : Pad 1Y Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 105' Created by : jones For: D.b'"roLTz Date plotted : 27-Apr-95 Plot Reference is 17 Version #2. Coordinates are in feet reference slot #17. True Vertical Depths are reference wellhead. BAKER HUGHES INTEQ N 50.97 DEG W 4080'(T0 TARC,ET) ~ - - W e s f ~o,, 1: 150.00 KOP 1%'D=750 TMD=750 DEP=O 3600 3..~30 3000 2700 2400 2100 1800 1500 1200 900 600 DE(; / 100' /~'~ ] TD LOCATION.' ] f270° 9.OO BUILD [ ( "-. ) / 12~, ..., ~o.,. ~'1 15.00 ~~J' "~ / Is£c. ~5. nZN.~gEI 21.00 B/ PERMAFROST 240,0 WD=1405 TMD=1419 DEP=116 . ~ [ TARGET LOCATION: ] 27.0033.00 ~ ] 291g' FNL, 1945' FEL[ t2100 ? ~ I SECl 35, T12N. RgE I TARGET t18oo ~ 1VD=5065 39.00 ~ DEP=4.080 45'00EOC TVD=2144 TMD=2312 T 316g DEP=604 ~,, NORTH 2569 1500 1/ UGNU SNDS TVD:2575 TM0=2943 DEP=1064 ~ 9o0 T/ W SAK SNDS ~ TVO = 2~K25S I~DM~) = 3455 DEP=1438 MAXIMUM ANGLE B,/ W SAK SNDS 46.86 DEC- wD=~3S5 mD=409~ DEP=1907 9 5/8" CSG PT 1VD=3565 TMD=4391 DEP=2121 K-la WD=5840 TMD=4793 DEP=2414 BEGIN ANGLE DROP TVD=4484 TMD=5735 DEP=3102 DROP 1.5 DEG / 100' K-5 TVD=5055 TMD=6495 DEP=3601 TARGET - T/ KUP SNDS SURFACE LOCATION: ] 208' FNL. 1224' FWl_ SEC. 1, TllN, 1~gE 45.00 42.00 3g.o0 36.00 .33.00 30.00 TVD=5965 TMD:7526 DEP=4080 T/ ZONE C WD:5977 TMD:7539 OEP:4084 T/ ZONE A W0=6133 TMD=7705 DEP=¢141 B/ KUP SNDS TVD=6257 TMD=7837 DEP=4186 TI) / LOGGING PT TVD=6445 TIMID-=8037 DEP=4954 0 250 500 750 10 12 0 1500 17 2000 2250 2500 27 3600 3250 3500 5750 4000 Scale 1 : 125.00 Vedical Section on 309.03 azimuth with reference 0.00 N, 0,00 E from slot #17 27.00 ~iaob3 ,-..,~m.. ,,_,Il & Gas O0ilS. CO['[IlitlSSIuP 24.00 21.00 TARGET ANGLE 20 DEG i i i i 4250 4500 100 1000 900 800 700 2800 600 500 West 4OO 2600 2200 2400 2000 1800 300 2000 200 Scole 1 100 · 100.00 0 100 ARCO St~K~me : Pad IY Well: 17 Looaflon : Norfh Slope, ~:Nica Flekl: K~amk Rker UnH I Inc. - 1800 8OO 700 600 500 A I 2200 2600 20O0 1800 2400 ) 1600 1800 2200 2O00 2000 1600 1800 1400 1600 1400 1000 1400 1200 3oo ~ 0 20( .,~ 100 ('3 100 o , , . . , , , , . 10. 11 12 13 14 15 16 17 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1Y-17 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4391')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 (8037') 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 sudace and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BQPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 1Y-17 Density PV YP ViscoSity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin.~ 9.0-10.5 15-25 15-35 50-100' 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% Drillina 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: Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% 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 2110 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1Y-17 is 1Y-16. As designed, the minimum distance between the two wells would be 25.4' @ 660' MD. The wells would diverge from that point. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left'with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 80-100 sec/qt to drill gravel beds. ,.~,.iask?.. L~ii & G~{s Col;s. ,CormT~.issioo Casing Design / Cement Calculations 6-May-93 Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 4,391 ft 3,565 ft 8,037 ft 6,445 ft 3,455 ft 7,526 ft 5,965 ft 10.6 ppg . ... " . ::::::::::::::::::::::: 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = :1 3,565 ft 2,110 psi1 10.6 ppg 5,965 ft 3,288 psi 3188 psiJ Surface lead: Top West Sak, TMD = 3,455 ft Design lead bottom 500 ft above the Top of West Sak = 2,955 ft Annular area - 0.3132 cf/If Lead length * Annulus area = 926 cf Excess factor - 15% Cement volume required - 1,064 cf Yield for Permafrost Cmt - 2.17 Cement volume required =1 490 sx_J Surface tail' TMD shoe = 4,391 ft (surface TD- 500' above West Sak) * (Annulus area) = 450 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 484 cf Excess factor = 15% Cement volume required = 557 cf Yield for Class G cmt = 1.15 Cement volume required =[ 480 sxJ Casing Design / Cement Calculations 6-May-93 Production tail' TMD = 8,037 ft Top of Target, TMD = 7,526 ft Want TOC 500' above top of target = 7,026 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 176 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 194 cf Excess factor = 15% Cement volume required = 223 cf Yield for Class G cmt = 1.23 Cement volume required =[ 180 sxJ TENSION -Minimurn Design Factors are: T(.ob)=l.5 and T(is)=l.8 Surface (Pipe Body): 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 (Pipe Body) = Design Factor =1 Surface (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 =[ 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 =I 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) = .... ge~.ig,Q ~,~q.t~ ?J 564000 lb 4,391 ft 36.00 Ib/ft 158076.0 lb 24792.6 lb 133283.4 lb 4.21 639000 lb 4,391 ft 36.OO Ib/ft 158O76.O lb 24792.6 lb 133283.4 lb 4.81 604000 lb 8,037 ft 26.00 Ib/ft 208962.0 lb 33406.8 lb 175555.2 lb 3.41 667000 lb 8,037 ft 26.00 Ib/ft 208962.0 lb 33406.8 lb 175555.2 lb 3.81 Casing Design / Cement Calculations 6-May-93 BURST- Minimum Desi(~n Factor = 1.1 -- Surface Casing Burst = Maximum surface pressure 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 COLLAPSE- Minimum Desic~n 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-(20~0'TVD of 9# Mud) Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Max Shut-in Pres = Design Factor =[ Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =l. Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =l 3520 psi 2110.5 psi 1.71 7240 psi 7052 psi 2983 psi 4070 psi 1.8J 2020 psi 0.551 Ib/ft 1029 psi 2.01 5410 psi 0.551 Ib/ft 3552 psi 1.51 Alaska Oil & Gas Cor~$. Corr~mission Casing Design / Cement Calculations 6-May-93 OD ID Ib/ft Grade I 9.625 8.681 47 L-80 2 9.625 8.835 40 L-80 3 9.625 8.921 36 J-55 4 10.750 9.950 45.5 J-55 Surface Casing Choices Metal X-Section Jt Strength Body Strength Collapse Burst 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi OD ID Ib/ft I 7,000 6.276 26 2 7.000 6.276 26 Production Casing Choices Grade Metal X-Section Jt Strength L-80 7.5491 sq. in. 667000 lb J-55 7.5491 sq. in. 490000 lb Body Strength Collapse Burst 604000 lb 5410 psi 7240 psi 41 5000 lb 4320 psi 4980 psi Oil & Gas Ooi,,s. Oorr~missior, A!~chorage 13 5/8" 5000 Phi BOP STACK 7 , 6 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2- ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING 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-TOM PIPE RAMS. TEST BO'I-I'OM RAMS TO 250 PSI AND 30(30 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 UNES 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 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-518" - 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 KL../ARUK RIVER UNIT 20" DIVERTER SCHEMATIC DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE 8,, 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., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) ....... ~) u ~l .... Aiask~ (.ti,l & Gas '-'~ ° Cor~r~dss~,~ ;Anchorage 1. 16" C~BUCTOR 2~ SLIP-ON WELD STARTING H~D 3. DIVER~R ASSEMBLY WI~ ONE 2-1/16"- 2000 PSi BALL VALVE 4. 20" - 2~0 PSI DRILLING SP~ WI~ ~O 10" OUTLETS. 5. 10" HCR BALL VALVES WI~ 10" DI~R~R LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNU~R PREVEN~R. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSi ANNU~R PREVENTER EDF 3/10,92 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fee ( 2 ) Loc '[2 thru 8] (3) Admin ~,~/" ,.~',,/:~/?.~ h~u 13] [lO & 13] (4) Cascj ~ 5-//7/~ , [ 14 thru '22] [23 thru 28] Company /~c~c:::~ Lease & Well YES NO 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 well bore plat included ................... ~. 7. Is operator the only affected party .................................. ~ 8. Can permit be approved before 15-day wait ............................ ~ .... REMARKS . 10. 11. 12. 13. 14. 15. .1.6. !7. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is 1 ease nLrnber appropriate .......................................... Does well have a unique name & nL~nber ................................ Is conductor string provided ....................................... -- Wil 1 surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to c i rculate 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 ~©~o psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... E29 thru 31] (7) Contact ~/2/__ -~..//~.~,¢~ [32] (8) Add] ~:~ ceol ocly' enm i neet i nc ' DWJ MTM ~ RAD,~q, LG .-'~- rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLOP~TORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA .~ SHORE MER I D I AFl' UM ~ Exp/Dev L/ I nj~ SM ~ TYPE' Redril I Rev O -H ~O ITl Z 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, informati;3n 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. Date ~chl umb~.r, qer A,!,aska Compt!t,,i,t:~ Cent. e~ D~TF : CO>~E~'.F : ~,RCO ,ALASKA, INC,,KUPARUK RIVER {.II";!".[~ 1~-17,50-029-22368-00 D,A TF~ : 93I()~/22 CDNT1. NUATtB't'~'~ ~ : i. Caa~E~,~T : ARC[} ALASKA, INC,,KUPARLIK R1VP~R UM!T~ 1Y-tT,$O-O29-223fl~-O0 !224 !. 95. O0 r'~pl-iN HO!..F CAS[t:G [3P.I.L!.ERS FIT $IZF' .............. ;-;-~ ..... ~''''''' F~.500 ,,, 2 4 9.0 ~ch.lUmber~er ...l_~sk.a Co,',putJ..nO Center 22-,..IUN-1993 1.0:01 PAGE: BeP. th st,.irt, ed anti c]..ipped ctlr'ves~ all. h.it runs ,,eroeO. l)W, pm~i !~'~CRbT,"~Fit,JT 0.5000 F l [_,~/ S!.i !,a ~x A Ry ~:'~ ,or)!, CO!)~ START D~;PTH ~7 ~2.5 '1~74.0 772P.5 7713.5 76~6.5 7597. r) STOP G023.0 {chlUmb~.r~)~r A!,:a.~ka C, omput,~.n~ Center 22~',.Ji.J ~- 1993 lO;O1 7575,5 75 ,] 2,0 7440,5 7395.5 7394.0 7263.0 7],7~ .0 6 ~ 46,5 6759.5 6719,0 !00.0 S :~FP~ED t'.),~TA SOURCE ~R~..I T~30[, COOT: S 7565.5 75~..0 74:F 0.5 7435,0 7390,5 7378.5 7257.(,) 7].64.5 7!,45.5 (: ~ 47,0 69~9.0 6839.0 6752,5 67~ 1.5 92.5 1. 4']97 2 7525.0 ~.~ER GE BASE 7 5 8023.0 LIS F[i~,r~','!~.T DA?A PAGE: ** r't,.TA FrlRt4h? 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ComFutip. o Cen. te~ 27-J!..,It,l- 1993 10:.Ol PAGE: F '.1' I'.., W HFADFR Curves and l..og header data for each bit run set:,arat, e files, STOP DE: PT'H v4oOC P050.9 4399,0 22.0 46.0 ~GEO22 ,.iS Te~e Verification ~,i. st:~ng ~chl. ur~b~r~er AlasKa Con, put!no Celt. er PAGE 1.0 I) P T T, L ..E R ':' C 4 3 99.0 1., 1 · 7 0 2.1.60 68.0 68.0 ~. 5 0 0 ** ~hATA F'QR~T SP~'CIF.[CATTOt' PEC..f..)PD ** 3 73 P'J~ 4 66 ~ ~ 7) 7 65 ~,.rs :rar:e v~,?rt ~!catlon [,tsti ;chlum?,~r?er A~as~a Comput;i~o Cent, er 22-dU~'-1993 10:01 9 1.1 66 12 1.3 66 0 66 0000000000 0000000000 0000000000 OOO0000000 OOO0000000 00 0 0 () 0 0 0 0 0 O00000000O DFPT. 75 .,?,-5.00(; aTR. [.,W l,. -99 .C,R. I,,w ~ -999, ~50 I ~. LW 1 -99 .p,. [;.lCw. . . 75on,, , . Dna. ,. ,. hl'~,,,. 1...,l',' 1 -09 G~. Lv~ 1 -999. 250 TA!:~. L~i ! ,.69 DFp'r. 7000. 000 ATR. LW 1 [',Fp'r. 65¢)0. OOI) ATR. LW ! ar~. I,w l I. ~_5..3oe. 'FAB. bt,'l [;F;DT. 6 ¢$00. (':00 ATP. !,!,~ 1 (;P. I,L,,,' 1. 7b. 4:05 TAB. !.,w 1 t.,. F~p'r. 55o0. oo0 Gr~' .I.W1 69.79 G~ L,k'~ P5 743 Th? 1"~1 , .-. , · ~ 9.250 PSR.LWl -999.250 ROPE. I.,W 1. 9.250 ~.SI.LW1 -999.?,,50 9.250 PSR.LW! -999.250 RF, PF. [,W 1. q.~50 RS!.bWl -999.250 2.528 PS~.LWl 2.148 ~nPE.LW~ 0.499 ~SJ.,L~! 0.000 2.]26 e.370 RS!.L', I 1.OOO ' 2.312 PSR.LWi 2.324 R~IPE.LW1 0.35~ PS!.t.,W! 0.000 2.683 ~S~.Lwl 2.58fi RqPE.I.,w1 O. 2P 1 ~S!. I,~ 1 (',. OOO 4.!07 ~SR.LWl 4.o9! ROPE.LWl 0.~96 =8I.b~"l 0.O00 3.592 0.9! ! RSI.LWl 0.000 71,49,8 38,461 1[~9.100 305.9[¢7 346.642 278.!35 371.493 3!_2.$5~ ,I$ Va~e Ver~flcet,for~ t, lst,J, na ;chlumber.,.',.~er Alas!ca Computi. nq Center' 22-Jt.!~-i. gg3 !0:.0.1 PAGE: 1¸2 4339.500 ATP.big1 ~.99q. 250 PS h~. L~,,,i 'l -999.25() 5~.{~;] Th[.~ [,,W1. 999 ?50 PSI bW1 -q9q 250 ROPE.LN1 -999. 250 Curves and l~a hea~er ~ata f!or each bit run .t.n se~.~arate files. P, Ij 1',! 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LW 2 -999i250 -996.250 G~.Sw2 -999 250 -999.250 TI~BD,LW2 -999.~50 -999.250 DRN[].LW2 -999.250 -999.950 TNPH.I,,,W2 -999.250 -999.250 Ce.bW2 -999.950 -999.250 TABD.[,,W2 -9q9.~50 -099.250 -999.250 -099. 250 rjR. bw2 -'g99. 250 - 999. ? 5 ('. i':, g.. !-.~ 0..L W 2 -999.750 Tr',~PH. LW 2 -qgq. 250 (;U. T,,w2 -9e9.250 -090.250 -990.250 -999.250 -999.250 -999.950 -999.25O -999.25O -999.250 19CAT,.Lw2 -999.250 bP~I.LV'2 -999.250 TYPH. b,,~2 -99Q.25~ ese'. LW2 -999. 259 ~'OPK. [,W2 -~90. 250 GR. h;v2 -999. 250 Ht;F~. L~2 -909.250 T~B.i, W2 -99a.250 TABg. Lw2 -qaq.250 ~ST. L/2 (,. PEF.[.,w2 H E r,' .t~ . b 'W 2 a$I. PEF. I,., W 2 u s I: b'w 2 PEF.LW2 ATR. LW2 HENA. I, W2 N$i.LW2 AT'R. hW2 H E N .~. b W 2 ¢,,i $ I'. !, W 2 PEF.bW2 ITR.bW? ~!SI.LW2 PEF. LW2 ~ T R. L W 2 ~,~SI .LW2 ,~TR. b',~ 2 :'~£.I. [.,w2 DCAI,. r.,<!2 -999.2~0 D[:'W T. 1,~2 -090.250 TYP.~4. [,W2 -999.250 ! -~ -- .... ~ I .... I · o ..... * - o · --- .. ~ .'. m - _. P,~GE: 15 4.504 2.158 296.393 -999.250 100.000 1.517 240.885 -999.250 -999.250 -.999.250 -999.250 0.000 -999.250 -999.250 -999.250 0.000 -999.250 -999.250 -999.250 0.000 -999.250 -999.250 -999.250 0.000 -999.250 -999.25O -999.250 O.O00 -999.250 -999.250 -999.250 0.000 -999.2~0 -999.250 -999.250 -9o9.250 .,I$ Tape V~rif!cat,ion Listin~ ;chlt.~mber.qeI. AlaSKa Comput!r~c Center 22-J[.]N'-199:t lO:r) l PAGE: S~RVICE~ vFPSION : O07. A()7 D~TF : o3106/22 t~A.X ~5:C SIZE FI[,~ TYPF: ~ LD sn~..f:ted and cl].t.,ped curves~ all bit runs r,:,erqed. ............4 ~i~7~ .... ........ ~02 FOP S~IFTS: ~ASKLII.,iE 88gg n ~887a.5 77~2.5 7774.a 77~2.~ 7713.5 760~.5 7597.0 757~.5 7565.5 7532.n 7522.0 7489.0 7440.5 7395.5 7~90.g 7394.n 737[~o5 ~ i ce t I o n T., ,i. s t' i r~ a AlasKa C'omputi~ C~nter 726~,0 717!.© 7152,0 69~1,5 695.4,0 6~95,~ 684.6,5 675!.). 5 67.1~. 0 ~ (') (',) . 0 E', D P A. '... 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