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Home My WebLink About185-249C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\0O55OAKD\2025-10-27_23101_KRU_3J-09_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23101 KRU 3J-09 50-029-21466-00 Caliper Survey w/ Log Data 27-Oct-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 185-249 T41044 10/30/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.30 11:55:32 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. 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From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3J-09 (PTD 185-249) Report of suspect IA pressure increase Date:Tuesday, June 10, 2025 1:51:04 PM Attachments:3J-09 90 Day TIO Plot & Schematic.pdf From: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, June 10, 2025 1:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 3J-09 (PTD 185-249) Report of suspect IA pressure increase Well Name: 3J-09 Facility: CPF3 PTD: 185-249 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): Yes Type of Issue: Suspect Integrity Maximum Pressure (if applicable): 955 Date of Occurrence (if applicable): 6/9/25 Chris, KRU 3J-09 (PTD 185-249) is showing signs of suspect IA pressurization during injection. CPAI intends to keep the well online and have DHD perform initial diagnostics, including a MITIA and then bleed the IA after which the well will be put on a 30 day monitor period. If communication is confirmed during the monitor or diagnostic testing, the injector will be shut-in as soon as possible. Any required paperwork for corrective action or continued injection will be submitted upon conclusion of the diagnostics and monitor period. Attached is a 90 day T/I/O plot and wellbore schematic for reference. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 35.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.921 Top (ftKB) 34.7 Set Depth (ftKB) 3,440.3 Set Depth (TVD) … 3,440.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 43.1 Set Depth (ftKB) 6,764.0 Set Depth (TVD) … 6,629.1 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.441 Top (ftKB) 32.0 Set Depth (ft… 6,267.8 Set Depth (TVD) (… 6,134.7 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 32.0 32.0 0.04 HANGER CAMERON TUBING HANGER 2.875 1,782.9 1,782.8 0.17 SAFETY VLV BAKER FVL SAFETY VALVE 2.312 6,179.8 6,047.2 6.22 PBR BAKER PBR 2.500 6,196.4 6,063.7 6.02 PACKER BAKER HB PACKER 3.000 6,234.0 6,101.0 5.85 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,267.0 6,133.9 5.72 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 1,782.0 1,782.0 0.17 FRAC SLV 2.31" BAKER FVL FRAC SLEEVE ( OAL= 143", UPPER SEAL TO LOWER SEAL = 125" ; NOGO 2.35" ; ID= 1.78" ) 7/29/2016 1.780 6,790.0 FISH JUNK Junk from cutting Csg, pushed to PBTD w/ bit 2/8/1986 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 6,442.0 6,450.0 6,308.1 6,316.1 A-3, 3J-09 4/1/1988 4.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,450.0 6,453.0 6,316.1 6,319.1 A-3, 3J-09 4/1/1988 4.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,450.0 6,451.0 6,316.1 6,317.1 A-3, 3J-09 4/1/1988 5.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,453.0 6,456.0 6,319.1 6,322.1 A-3, 3J-09 4/1/1988 4.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,453.0 6,454.0 6,319.1 6,320.1 A-3, 3J-09 4/1/1988 5.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,466.0 6,470.0 6,332.0 6,336.0 A-2, 3J-09 4/1/1988 4.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,470.0 6,471.0 6,336.0 6,337.0 A-2, 3J-09 4/1/1988 5.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,470.0 6,483.0 6,336.0 6,349.0 A-2, 3J-09 4/1/1988 4.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,483.0 6,485.0 6,349.0 6,351.0 A-2, 3J-09 4/1/1988 5.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,485.0 6,487.0 6,351.0 6,353.0 A-2, 3J-09 4/1/1988 4.0 RPERF 0 deg ph; 2 1/8" EnerJet 6,536.0 6,545.0 6,401.8 6,410.8 A-1, 3J-09 8/17/1986 4.0 IPERF 120 deg ph; 4" Jumbo Jet II Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,231.3 2,231.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/20/1986 2 3,703.0 3,702.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/20/1986 3 4,576.9 4,524.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/20/1986 4 5,080.6 4,982.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/20/1986 5 5,368.2 5,253.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/20/1986 6 5,624.8 5,501.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/20/1986 7 5,910.8 5,780.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 8/20/1986 8 6,135.6 6,003.2 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/24/1986 Notes: General & Safety End Date Annotation 1/8/2004 NOTE: WAIVERED WELL: OA x SURFACE CASING COMMUNICATION 11/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: TRDP3J-09, 7/31/2016 12:37:18 PM Vertical schematic (actual) FISH; 6,790.0 PRODUCTION; 43.1-6,764.0 IPERF; 6,536.0-6,545.0 RPERF; 6,485.0-6,487.0 RPERF; 6,483.0-6,485.0 RPERF; 6,470.0-6,483.0 RPERF; 6,470.0-6,471.0 RPERF; 6,466.0-6,470.0 RPERF; 6,453.0-6,456.0 RPERF; 6,453.0-6,454.0 RPERF; 6,450.0-6,453.0 RPERF; 6,450.0-6,451.0 RPERF; 6,442.0-6,450.0 SOS; 6,267.0 NIPPLE; 6,234.0 PACKER; 6,196.4 PBR; 6,179.8 GAS LIFT; 6,135.6 GAS LIFT; 5,910.8 GAS LIFT; 5,624.8 GAS LIFT; 5,368.2 GAS LIFT; 5,080.6 GAS LIFT; 4,576.9 GAS LIFT; 3,703.0 SURFACE; 34.7-3,440.3 GAS LIFT; 2,231.3 SAFETY VLV; 1,782.9 FRAC SLV; 1,782.0 CONDUCTOR; 35.0-110.0 HANGER; 32.0 Annotation Last Tag: SLM Depth (ftKB) 6,636.0 End Date 3/5/2009 Annotation Rev Reason: SET FRAC SLEEVE Last Mod By pproven End Date 7/31/2016 KUP INJ KB-Grd (ft) 32.99 Rig Release Date 11/26/1985 Annotation Last WO: End Date 3J-09 H2S (ppm) Date ... TD Act Btm (ftKB) 6,792.0 Well Attributes Wellbore API/UWI 500292146600 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 26.96 MD (ftKB) 4,500.00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3J-09 KUPARUK RIV UNIT 3J-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/22/2024 3J-09 50-029-21466-00-00 185-249-0 W SPT 6063 1852490 1516 2890 2890 2890 2890 16 8 8 8 4YRTST P Brian Bixby 7/9/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3J-09 Inspection Date: Tubing OA Packer Depth 170 2010 1900 1865IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240710103730 BBL Pumped:1.9 BBL Returned:1.7 Thursday, August 22, 2024 Page 1 of 1             MEMORANDUM TO: Jim Pegg P.I. Supervisor It FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 21, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3J-09 KUPARUK RIV UNIT 3J-09 Src: Inspector Reviewed By: P.I. Supry.� Comm Well Name KUPARUK RIV UNIT 3J-09 API Well Number 50-029-21466-00-00 Inspector Name: Jeff Jones InSp Num: mitJJ200720112148 Permit Number: 185-249-0 Inspection Date: 7/2/2020 Re( Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - — - ' PTO 1852490 'Type 6063 Type Test SPT �T Test psi 1516 Tubing 2825 2825 - 2825 - 2825 - jA 100 1980 - 1860 - 1840 - BBL Pumped: 2 BBL Returned: 2 OA 6 - 11 11 - 11 Interval 4YRTST P/F P Notes: I well inspected, no exceptions noted. Tuesday, July 21, 2020 Page 1 of 1 • • , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon(- Plug Perforations r Fracture Stimulate r Pull Tubing E Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing- Change Approved Program E Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Weld Starter head I✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen r Exploratory r 185-249 3.Address: 6.API Number: Stratigraphi r Service F P.O. Box 100360,Anchorage,Alaska 99510 50-029-21466-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025630 KRU 3J-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6790 feet Plugs(measured) None true vertical 6655 feet Junk(measured) None Effective Depth measured 6636 feet Packer(measured) 6180,6196,6234 true vertical 0 feet (true vertical) 6047,6064,6101 Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 16 110 110' SURFACE 3406 12 3440 .r..:- 3440' PRODUCTION 6721 7 6764 6629' Perforation depth: Measured depth: 6442-6545 5CAt 4 O JAN 3 0 01? R Er Eva(); True Vertical Depth: 6308-6411 AUG 0 2 2016 Tubing(size,grade,MD,and TVD) 2.875,J-55,6267 MD,6134 TVD GCC Packers&SSSV(type,MD,and TVD) PBR-BAKER PBR @ 6180 MD and 6047 TVD PACKER-BAKER HB PACKER @ 6196 MD and 6064 TVD NIPPLE-CAMCO D NIPPLE NO GO @ 6234 MD and 6101 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development f— Service F Stratigraphic r Copies of Logs and Surveys 16.Well Status after work: Oil r Gas r WDSPL 1.-- Printed Printed and Electronic Fracture Stimulation r GSTOR r WINJ F WAG r GINJ r SUSP r SPLUG I- 17. 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact Roger Winter Email: NSK n1927@conocophillips.com Printed Name Roq Wint r i Title: Well Integrity Field Supervisor /�� Signature Phone:659-7506 Date l/ Form 10-404 Revised 5/201 qq/// , / - Submit Original Only / { RBDMS � I, AUG2 2016 • • • • ConocoPhillips RECEIVED Alaska AUG 0 2 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360AOG CC July 29, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3J-09 PTD 185-249 surface casing starter head welded repair. Please call myself at 659-7506 or MJ Loveland at 659-7043 if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • 3J-09 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/24/16 Prep and weld starter head. 07/27/16 Test weld with N2 and snoop. A t , •,:„, , M t,„,4,,,,,;:tme,;.',...i,,,,:-.,...:4,01.p,..k,,,17...-. ;-0,,#,:z.:,,H:,„;.;. a r x � R ..,,,1""'7';.'...1..,,,4.....,..!'t dr'''',,,,,4".' $ r t '' s. S} fi 4 ° � ;. nom". ;yy '' ,x } ".., pe'tl ^r .".' Y.�. NAS=.a mak, ' .. 'ApA ,.••:• ' .eft}. ,,,i?..., E i Y .r • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: JiRegg !� DATE: Wednesday,July 06,2016 P.I.Supervisor 11 .- 7/'3/ 40 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3J-09 FROM: Chuck Scheve KUPARUK RIV UNIT 3J-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3J-09 API Well Number 50-029-21466-00-00 Inspector Name: Chuck Scheve Permit Number: 185-249-0 Inspection Date: 7/5/2016 Insp Num: mitCS160705155145 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3J-09 Type Inj W 'TVD 6063 ' Tubing 2900 2900- 2900 - 2900 PTD 1852490 ' Type Test SPT Test psi 1516 - IA 400 2150 2080 - 2070 - Interval 4i RTST P/F P " OA 10 - 22 - 12 12 Notes: SCOW NOV 2 22016 Wednesday,July 06,2016 Page 1 of 1 • • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, May 29, 2016 1:45 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Kuparuk Injector 3J-09 (PTD # 185-249) IA pressure fall off Attachments: 3J-09 90 Day TIO plot.JPG Chris- Kuparuk Injector 3J-09 (PTD# 185-249) is nearing the end of the 60 day monitor period. The initial diagnostics consisting of an MIT-IA and T&IC pack off tests all passed. Although the IC pack off tests passed, due to the nature of the slow leak off it was suspected that there was a very small from the IA to the OA via the IC pack offs. The pack off seals were re-energized several times and it appears seals have regained integrity and stopped the IA pressure fall off. The IA pressure fluctuation during the monitor period is associated with the fluctuations in injection rates as seen on the TIO plot included. The well will be returned to normal injection status. If there are further indications of IA pressure fall of the well will be reported as needed. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot Dusty Freeborn /Jan Byrne Well Integrity Supervisor S 1 2016 ConocoPhillips Alaska, Inc. c� Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM i1/4 ConocoPhillips From:NSK Problem Well Supv Sent:Wednesday, March 30, 2016 2:06 PM To: Wallace, Chris D(00A)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R Tylerenden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: Kuparuk Injector 3J-09 (PTD,t# 185-249) IA pressure fall off Chris- Kuparuk Injector 3J-09 (PTD# 185-249) has shown aslow but consistent IA pressure fall off. The IA was charged on the 20th of January 2016 and has slowly decreased in pressuresince. The well was reported in March of 2014 for a similar issue but showed no further indications of an integrity issues during the monitor period. Initial diagnostics will include an MIT-IA, OA draw down test, and tubing and inner casing pack off-tests. The inner casing pack offs will be re-energized as an attempt to eliminate any undetectable leaks from the IA to the O ithin the wellhead. It is CPAI's intention to continue water injection while the diagnostics are performed. If the MIT-IA ' the well will be shut in and freeze protected as soon as reasonably possible. If passing tests are achieved, the IA wil1`be left with an elevated pressure and monitored for a 60 day period while on water injection. Following the diagnostics monitor period the appropriate paperwork will be submitted for repair or continued injection. Please let me know if you have,any question or concerns. Attached is the 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Well Integrity Supervisor 1 • u { O ro •••• ,•-•-!.... r0,..1 C Lil 1/40 E .0 a)} ,1 i, <-__--__-: 1 .„, ,i ,i 1 _____I- , ki'l ,. , ____-_ . / ›4 ,..0 ...4 r` 1 E. —______ , . 1 i sci 4 1_, ___ _._ 0., z =.: 1. Nimii N �^" H' ! I f ll ~ �� I -� r I IIi i U I 1 --- . e 1 .,...._ I , ., , III , i , , 4.0 . \ E t:4 L 1 1 1 _ _____ �'1 _, w Lik I 1 t,._ ,... 1 ____ 0 an I, �,I -�- ' ,t- '' _ W W i I' g Ng III Hil I-i] • il • N an N. N Ni ':1: O.1H tNCO N• C ' UN> I : '' wII X cn H14 i:14 CC. rn i --- -, _ �!, aIn a SZ Z Z I —r-- W H H H O H O II Millilit 4.1 11WWII i II I b 1 • _— ' •rel O CO 5.D N' N O co .A .r N C '•-I C7 CIN o. Cr, ON O", CO CO CO CC+ N Q O = R k.0 LP rf, N ri I I:0 W ,-1 _. c W�y� V N .. • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, March 30, 2016 2:06 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Kuparuk Injector 3J-09 (PTD # 185-249)IA pressure fall off Attachments: 3J-09.pdf; 3J-09 90 Day TIO plot.JPG Chris- Kuparuk Injector 3J-09 (PTD# 185-249) has shown a slow but consistent IA pressure fall off. The IA was charged on the 20th of January 2016 and has slowly decreased in pressure since. The well was reported in March of 2014 for a similar issue but showed no further indications of an integrity issues during the monitor period. Initial diagnostics will include an MIT-IA,OA draw down test, and tubing and inner casing pack off tests. The inner casing pack offs will be re-energized as an attempt to eliminate any undetectable leaks from the IA to the OA within the wellhead. It is CPAI's intention to continue water injection while the diagnostics are performed. If the MIT-IA fails the well will be shut in and freeze protected as soon as reasonably possible. If passing tests are achieved, the IA will be left with an elevated pressure and monitored for a 60 day period while on water injection. Following the diagnostics monitor period the appropriate paperwork will be submitted for repair or continued injection. Please let me know if you have any question or concerns. Attached is the 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 AZELLS TEAM SCp►NKErj MAR 3 Z016 ConocoPhillips • . ow U ce z CO U.z w M a U ca 4 LLL CO CC N- O. u_ G o w r• m• cy o E a ,- -a c a1 x w y m ,4 r. W N K N d z IA CD 0 uJ "- 2 4 H N 0 JI 61 J 4 M O 00 O O O d6ap 11(1 I U CJ ' U IXi ltl +l CV O OD I i I I I 1 I I 4 4,1 -1 a W W M a) U C eaW 7 N C O '= LL D E O L I!1el J Q1 3 O C Z C Q t0 tD W W {P1 CO O1 O O GOM ,- C7 a,- Y } } o N M d I u, u, dE 22 #{ d Q ti d " '3 41 v v c-, c, c, c-, c Cj r.§ § 7 il $ o a 00 Z Q co C.3 . UV CJ U CJ r) n'{ „o C3 LIJ C.) u, Odie WON TD • now IS MEIVIORANDLTll~ To: Jim Regg 'k~ P.I. Supervisor ~l~G ~' ~~I(I~~ FROM: Bob Noble Petroleum Inspector State of Alaska , Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 31-09 KUPARUK RIV UNIT 31-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~.J ~~+--- Comm Well Name: KUPARUK RN UNIT 3J-09 API Well Number: 50-029-21466-00-00 Insp Num: mitRCN080708074113 Permit Number: 185-249-0 Rel Insp Num: Inspector Name Bob Noble Inspection Date: 76/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WeI~ 31-09 (Type Inj. j N ' TVD I 6063 ~ IA 0 i 2460 /~ 2350 2320 I p.T. Iss249o TypeTest SPT ~ Test psi z46o OA 2 ~ ~ 6 j 6 Interval 4YRTST P~ P Tubing ~ 1625 1625 1625 1625 i I Notes' OA had a sign saying do not exceed 50 psi. Paper in wellhouse said OA X OOA communication. ~l; ~ _ ~~ ~ ~'h°Ssvu~ l ~t~ ~' ;/ ~d~Nl~~~ fiUG ° ~ 2068 Tuesday, July 08, 2008 Page 1 of 1 RECE\VED 06/13/06 I.IUN 1 4 [(JOB ScblunlbepglP ~Oì /d" NO. 3850 Alæk~ ŒI &. Gas Cons. Anchor~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ..,- /.' , ,~. ~. \ ",\ e, ""i ?" ~.. <¡f\nv) :~ :z, L'J, ','; Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 C\\~\ .. ......í..'Ç¡,.I..¡¡· :ç: t·. ."",.~.."~,,, .v' J"'¡¡" Field: Kuparuk Well Job# Log Description Date BL Color CD h- 3J-16 11249908 INJECTION PROFILE 06/03/06 1 1 R-08 11249909 INJECTION PROFILE 06/04/06 1 3H-11 . 11213760 PRODUCTION PROFILE WIDEFT 05/31/06 1 1 R-07 11249912 PRODUCTION PROFILE 06/07/06 'I 1F-12 11320981 PRODUCTION PROFILE WIDEFT 06/06/06 1 3G-20 11249911 INJECTION PROFILE 06/06/06 1 2A-16 11213754 PRODUCTION PROFILE W/DEFT OS/25/06 1 2A-22 11213756 LDL OS/27/06 1 1Y-04 11320980 LDL 06/03/06 1 2Z-02 CREDO) 11235362 INJECTION PROFILE OS/28/06 1 1 H-19 (REDO) 11320975 INJECTION PROFILE OS/29/06 1 2A-13-fREDO\ 11320976 LDL 05/30/06 1 3J-09 11320977 INJECTION PROFILE 05/31/06 1 1 F-17 11249913 PRODUCTION PROFILE W/DEFT 06/08/06 1 1J-170 11320983 USIT 06/11/06 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (N / ./)f/,,---. (:) / I L11tß e e ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3J-09 08/10/05 Arend I Savageau AES .~ tßi\\L<;, , ~cl \ ~ \ ·ll. ~ /'rùf , \C51 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Depth Well 3J-09 Type Inj. S TVD 6,063' Tubing P.T.D'.1~85249 Type test P Test psi 1516 Casing Notes: Diagnostic MIT to test packoff assembly Pretest 2700 500 Initial 15 Min. 30 Min. 2700 2700 2700 3000 2910 2890 Interval P/F o P Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin g P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Test Details: SCANNED NO'~ Q 3 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-081 O_MIT _KRU_3J-09.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~q 9/7t 104- DATE: Monday, September 20, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3J-O9 KUPARUK RIV UNIT 3J-O9 FROM: Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 31-09 API Well Number: 50-029-21466-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS040803205O4 7 Permit Number: 185-249-0 Inspection Date 8/312004 Rei Insp Num: MITOPOOOOO0382 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3J-O9 Type Inj. S TVD 6063 IA 0 2180 2100 2080 P.T.D 1852490 TypeTest SPT Test psi 1515.75 OA 0 0 0 0 Interval Four Year Cycle PIF Pass Tubing 2900 2900 2900 2900 Notes: Pretest pressures observed for 30+ minutes and found stable. This Well has a waiver for OA leak. Monday, September 20, 2004 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~4C{ '1ì,dO4- DATE: Wednesday, August 04, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3]-09 KUPARUK RIV UNIT 3]-09 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By:--.. P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 31-09 API Well Number: 50-029-21466-00-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40803205047 Permit Number: 185-249-0 Inspection Date: 8/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3]-09 Type Inj. S TVD 6655 IA 0 2180 2100 2080 P.T. 1852490 TypeTest SPT Test psi 1515.75 OA 0 0 0 0 Interval 4YRTST P/F P Tubing 2900 2900 2900 2900 Notes: Pretest pressures observed for 30+ minutes and found stable. This Well has a waiver for OA leak. Wednesday, August 04, 2004 Page I of I MEMORANDUM TO: Dan Seamount ~,.J' Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: John Crisp_~lvt ~__,. Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 9, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 3J Pad 09,12,13,16 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL P.T.D.I 1852490 Notes: Well! 3J-12 P.T.D.I 1852520 Notes: 'WellI 3J-13 P.T.D.I 1852870 Notes: WellI 3J-16 P.T.D.I 1852900 Notes: WellI P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnj.I S I T.V.D. I 6063 l Tubing I 29~5 I 2925 I=~*~ !=,=~ I,ntervall 4 TypetestI P. ITestpsiI 151.6 I CasingI 520 I' 16801 1620 I 16001 P/.F i P' I Type,nj.I s I T.V.D.1~o~5 I Tubing 12~5o I =,~o I =~° I=~° I'"t~rv"'l 4 I .TypetestI P _lTestpsil 1516 I Casingl 1000 I 2000 I 1950I 1950I P/F I P- ~_ ]Typelnj.I S I T.v.a:l ~4o I Tubingl=~0 ! =~0' I =~0 1=~0 I'nterva'l4 TypetestI P ITestpsil 1535 ICasingI 1200I 2100I 2090J 2090I P/F I P ' , . I~,,e,ni.Is ! T.v.~. I~ I Tub,n~12900 I 2900 I2900I~oo I,.terva,I 4 TypetestI I5 ITestpsil 1541 I Casingl 95O I 19501 1940 1'191~ I P/FI P' I Type INJ. Fluid Codes F = FRESH WATER INJ, G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details 4 M]T's performed, no failures witnessed. All tests performed Lq a safe & c~cicztt maimer. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) .I.T.'s performed: 4_ Attachments: Number of Failures: 0 Total Time dudng tests: 2 hrs. cc,; MIT report form 5/12/00 L.G. MIT KRU 3Jb 9-9-00jc.xls 9/13/00 ~ OIL AND GAS CONSERVATION ~ION REPORT OF SUNDRY WELL OPERATIONS ORIGtN4t_ 11. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casing 2. Narrle of Operator J 5. ARCO Alaska. In(;, 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate Plugging __ Perforate __ Repair well .. Other Type of Well: Development ... Exploratory _ Stratigraphic Service .~ 4. Location of well at surface 990' FSL, 564' FWL, $EC.3, T12N, R9E, UM At top of productive interval 1431' FSL, 1198' FWL, $EC.3, T12N, R9E, UM At effective depth 1435' FSL, 1201' FWL, SEC.3, T12N, R9E, UM At total depth 1450' FSLr 12,31' FWLr SEC.3~ T12N~ R93~ UM 12. Present well condition summary Total Depth: measured 6 7 9 0' feet true vertical 6 6 5 5' feet 6. Datum elevation (DF or KB) RKB 74 7. Unit or Property name Kuparuk River Unit 8. Well number 3J-09 9. Permit number/approval number 85-249 / 7-651 10. APl number 50-029-2146600 Plugs (measured) feet 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 6450' feet Junk (measured) 6316' feet 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Lenglh Size 81' 1 6" 3407' 9-5/8" 6735' 7" measured 6450'-6485' true vertical 6316'-6351' Cemented Measured deplh True vertical depth 171 SX AS II 110' 110' 1010 SX AS III & 3436' 3435' 295 SX CLASS G 350 SX CLASS G & 6764' 6628' 175 SX AS I Tubing (size, grade, and measured depth) 2-7/8" J~55 @ 6268' Packers and SSSV (type and measured depth) HB-1 BeT @ 6196' AND TRDP-1A-SSA @ 1783' Stimulation or cement squeeze summary CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL c, ~ Intervals treated (measured) RECE[VF.D Anchorage Treatment description including volumes used and final pressure 14. ~eoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 48 31 0 22 104 Subse({uent to operation 0 0 1075 1931 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations__ 16. Status of well classification as: Water Injector _X Oil __ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' Title Petroleum Enc~ineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO ' · Alaska, .~,. ¢) ~ ' SulDs~diary o! Allanhc Ricnfiel(:l Coml3any WELL 'PBOT CONTRACTOR REMARKS IFtEI. D · DISTRICT- STATE IOPERATION AT REPORT TIME WELL SERVICE REPOR~ iDAYS . [:)ATE c.c.: ARCO Alaska, Inc. Post Office B,... I00360 Anchorage, Alaska 99510 Telephone 907 276 1215 Sa~IP LE TRANSMITTAL SHIPPED TO' · State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle hand-carried DATE' 5-12- 88 OPERATOR- ARCO NAME' see below S~Zx~PLE TYPE' core chips, plug ends NL6{BER OF BOXES' 63 SAMP LES SENT' Lisb L5-21:11 boxes 12088/89 12123 12145/46 12151/52 12151/52 12200/01 12230/31 12290/91 12373/74 12396/93 12422/23 12435/36 12449/50 12467/68 12473/74 12482/83 12492/93 12520/21 - 12133/34 - 12144 - 12149/50 - 12198/99 - 12198/99 -. 12223/24 - 12288/89 - 12371/72 - 12390/91 - 12406/07 - 12425/26 - 12445/46 - 12463/64 - 12471/72 - 12581/81 - 12490/91 - 12510/11 - 12614/15 .5 KRU 2T-9; 1 box . KRU 3J-9:12 boxes .a 5-.r'~P. OS" 2150.8 -~ 6320 - 6393 '(~'250 & 2315 are 6395 - 6436 preserved - no 6438 - 6453 samples are available)6459-- 6503 6507 - 6545 KRU 3H-9.: 9 boxes 6548 - 6570 '6868 - 6908 KRU 3K-9:16 boxes 6911 - 6958 6971 - 7058 3365.2 - 3501.3 6967 - 7009 KRU 3H-11:2 boxes 7027 - 7060 7060 - 7099 3941 - 3954 7102 - ~174 3970 - 3974 7199 - 7243 3979 - 3983 3993 - 3994 4025 - 4035 4057 - 4059 4061 - 4081 SHIPPED BY:,~"--~-'i"3- _Z~_~. ~_~ UPON RECEIPT OF THESE SAMPLES, COPY OF THIS FOP~M TO' · KRU 3M-9:5 boxes 6531 - 6577.0 6579 - 6618 6637 - 6650 -KRU 3M-16:7 boxes' 7580 - 7614 7617 - 7690 .Bayview Facility Coordinator PLEASE NOTE ANY DISCREP.~CIES AND ~t~IL A SIGNED ARCO ALAS[a~, INC. P.O. BOX 100360 , ~~~,, ~~ ANCHORAGE, ALASKA 99510 ATTN: Pa leo Lab - RECEIVED BY' DAT~:E: ~ ..~ · ARCO Alaska. Inc. is a Subsidiary of AllantlcRIchfleldCompany ARCO Alaska, Inc. Pos! Office Be .)0360 Anchorage, Alaska 99510-0360 Telephone .007 276 1215 February 17, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commission Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. The wells are listed below. Wel 1 Action Anticipated Start Date 2G-9 Fracture 2D-16 Perforate & Stimulate February, 1988 March 4, 1988 2F-10 Perforate & Stimulate March, 1988 3M-21 Perforate & Stimulate February, 1988 2E-11 Stimulate February, 1988 2H-15 Perforate February, 1988 2H-13 Perforate February, 1988 3M-1 Perforate & Stimulate FebFuary, 1988 3M-2 Conversion February, 1988 3M-10 Conversion February, 1988 3M-15 Conversion February, 1988 3M-16 Conversion February, 1988 3J-4 Perforate March, 1988 3J-9 Perforate March, 1988 3J-13 Perforate March, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:pg:0154 Attachments cc: File KOE1.4-9 AlnIco Alaska. Inc. is a S~bsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASF~..~OIL AND GAS CONSERVATION COMb~.cSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate [] Other [] 2. Name of Operator ARCO Alaska: Inc. 3. Address P.O. Box 100360~ Anchorage, Alaska 99510 4. Location of well at surface 990' FSL, 564 FWL, Sec. 3, T12N, R9E, UM At top of productive interval :!.43:1' FSL, 1198' At effective depth 1435' FSL, 1201' At total depth 1450' FSL~ 1231' 11. Present well condition summary Total depth: measured true vertical FWL, Sec. 03, T12N, R9E, UM FWL, Sec. 03, T12N, R9E, UM FWL~ Sec. 03~ T12N~ R9E~ UM 6790' 6655' feet feet Plugs (measured) 5. Datum elevation (DF or KB) RKB 7 6. Unit or Property name Kuparuk River Unit 7. Well number 3J-09 8. Permit number 85-249 9. APl number 50-- 029-21466 10. Pool Kuparuk River Oil feet Pool Effective depth: measured 6450 ' feet true vertical 6316' feet Junk (measured) 6680' 6680' Casing Length Structural Conductor 110' Surface 3436' Intermediate Production 6764' Liner Perforation depth: measured Size Cemented Measured depth True Vertical depth 16" 171 Sx AS II 110' 110' 9-5/8" 1010 Sx A.S. III 3436' 3435' 295 Sx Class "G" 7" 350 Sx Class "G" 6764' 6628' 175 Sx A.S. I 6450-6485' true vertical 6316'-6351' Tubing (size, grade and measured depth) .~7;;' ' ' '" 2-7/8", J-55, tbg w/tail @ 6268' MD Packers and SSSV (type and measured depth) ~ HB-1 BOT pkr @ 6196' and TRDP-1A-SSA SSSV @ 1783' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Perforate C Sand, add A Sand perforations, 13. Estimated date for commencing operation March 1, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the f.[oregoing is true and correct to t.he best of my knowledge Signed ./'~ ~----'(~-4,/ ~. ~¢/¢~-~ Title)-,.,,..~ /~. ,~,~..~ .,,~._,,¢~,-~, Commission Use On/ly approval Notify commission so representative may witness I Approval Conditions of [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returne.a z2~ ORIGINAL SIGNED BY Date Approved by LONNIE C. SMITH Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ~.,- STATE OF ALASKA ALA-~,A. OIL AND GAS CONSERVATION CO~,,...,.~-SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate Fl Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 990' FSL, 564 FWL, Sec. 3, T12N, R9E, UM At top of productive interval 1431' FSL, 1198' FWL, Sec. 03, T12N, R9E At effective depth 1435' FSL, 1201' FWL, Sec. 03, T12N, R9E At total depth 1450' FSL, 1231' FWL, Sec. 03, T12N, R9E , UM , UM 5. Datum elevation (DF or KB) RKB 74' 6. Unit or Property name Kuparuk River Unit 7. Well number 3J-09 8. Permit number 85-249 9. APl number 50-- 029-21466 10. Pool , UM feet Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6790' 6680' 6655' feet Plugs (measured) feet 6680' 6450' feet Junk (measured) 6316' feet Casing Length Structural Conductor 110 ' 3436' Surface Intermediate 6764' Production Liner Size Cemented Measured depth True Vertical depth 16" 171 Sx AS II 110' 110' 9-5/8" 1010 Sx A.S. III 3436' 3435' 295 Sx Class "G" 7" 350 Sx Class "G" 6764' 6628' 175 Sx A.S. I Perforation depth: measured true vertical 6450-6485' Tubing (size, grade and measured depth) 6316'-6351' OC-[ 0 2 i987 2-7/8", J-55, tbg w/tail @ 6268' MD Packers and SSSV (type and measured depth) j~lc~lofage HB-1 BOT pkr @ 6196' and TRDP-1A-SSA SSSV @ 1783' N~$~Oi~&GasCo~s-6°mm'tss 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Convert KRU Well 3J-09 from oil producer to water injector. 13. Estimated date for commencing operation October 15, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to tl~ best of my knowledge Signed ~ C4~ ~ ~./'~~/(/'T~ Title Commission Use ~'nly Conditions of approval Notify commission so representative may witness I Approval No. I Approved by .FI Plug integrity [] BOP Test [] Location clearance ,,;l(:.h~i ...... !~' :'; :... ,, i~ ' ':.%.,:...'.", .... . ~ ~..: "' Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicatu/~ ARCO Alaska, Inc. Post Office B(~ ;)0360 Anchorage. AI~S~,a 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal ~5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints' ~ --~flR-14 gET/gEL ~ ~1R-14 CET/CEL ~ -~ 2A-14 CET/CEL '~ ~-~3A-1 CET/CEL ~ -~f3A-2 gET/gEL '~ -J~--3A-3 CET/CEL ."~. ~ .... 3A-15 gET/gEL ~ ~3A-16 gET/gEL ~ ~-~3C-15 gET/gEL '' ~ --a-~3C-16 gET/gEL ._ ~ '",,J3F-1 .. gET/gEL '~. ---U_3F-lO .gET/gEL ~ '"-J~3F:11 gET/gEL ~ 'J --3J-4 gET/gEL "-x~--.~ ~3J-6 CET/CEL ~3J-9 gET/gEL 10-12-85 10-13-85 10-02-85 10-01-85 10-01-85 10-01-85 12-30-85 12-30-85 10-!5-85 10-15-85 10-!7-85 12-19-85 12-19-85 10-05-85 10-19-85 12-18-85 Receipt Acknowledged' Run #2 8600 - 9120 Run #3 85.50 - 8894 Run ~1 6~95 - 7763 Run #1 7~50 - 9467 Run ~1 6680 - 8570 Run #1 6080 - 8256 Run ~2 6400 - 8038 Run ~2 7300 - 9030 Run #1 5887 - 7730 Run ~1 3995 - 6753 Run ~1 7000 - 8488 Run ~1 5166 - 6483 Run #1 6950 - 8322 Run ~1 6860 - 8410 Run #1 7000 - 8487 Run ~1 36 - 6678 / ~ Alask~ Oil & Gas Cram. Oommissio~. Anchorage K Drilling Vault(1 film) ARCO Alask3. Inc. i~ a Subsidiar), ol AllanlicRichfie;dCompany · STATE OF ALASKA ALAS'~-L AND GAS CONSERVATION'~U"O~'MISSION WELL COMPLETION OR RECOM LETIOI, I REPORT Al, ID 1. Status of Well Classification of Service Well / OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-249 . 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 5o- 029-21466 4. Location of well at surface 9. Unit or Lease Name 990' FSL, 564' FWL, $ec.3, T12N, RgE, UN KuParuk River Unit At Top Producing Interval 10. Well Number 1431' FSL, 1198' FWL, Sec.3, T12N, RgE, UN 3J-9 At Total Depth 11. Field and Pool 1450' FSL, 1231' FWL, Sec.3, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 74' RKBJ ADL 25630 ALK 2563 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/07/85 11/22/85 09/09/86*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6790'MD,6655'TVD 6680'MD,6545'TVD YES'ii NO [] 1783 feet MDI 1700' (Approx) 22. Type Electric or Other Logs Run 5HDI/GI~, I{I~I/L;I~, WST, (;CT ((;yro), G~/ccL/_~, DIL/(;R/LSS, Density/EPT/CNL/GR, Dipmeter/GR, DI L/FDC/CNL/GR, LS$/GR 23. CASING, LINER AND CEMENTING RECORD . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 52.5# H-40 Surf 110' 2M' 171 sx A5 ii 9-5/8" ~6.0# J-55 Surf 3436' 12-1/4" 1010 sx AS III & 295 sx :lass G 7" 26.0# J-55 Surf 676~' 8-1/2" 356 sx Class G & 175 sx ~.S I · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6450' MD 6316' TVD w/1 spf, 90° phasing 2-7/8" 6268' 6196' 6453' MD 6319' TVD w/1 spf, 90° phasing 6470' MD 6336' TVD w/1 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6483' MD 6349' TVD w/1 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6484' MD 6350' TVD w/1 spf, 90° phasing See attached Addend Jm (dated 9/12/86) for fracture data. 6485' MD 6351' TVD w/1 spf, 90° phasing 6536'-6545' MD 6401'-6410' TVD w/4 spf, 90° phasing , , 27. N/A PRODUCTION TEST · Date First Production I Method of Operation (Flowing, gas lift, etc.) I . Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-MCF WATER-BBL OiL GRAvITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See core descrption attached to Well Completion Report dated 1/10/86. ! - ' - . Form 10-407 * NOTE: Drilled RR 11/26/85. Perf'd well & ran tubing 8/18/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/127 Submit in duplicate 29. GEOLOGIC MARKERS NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Euparuk A MEAS. DEPTH 6327' 6366' 6432' 6546' TRUE VERT. DEPTH 6193' 6232' 6298' 6411' 31. LIST OF ATTACHMENTS Addendum (dated 9/12/86) 30. ' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. D.epth Hydro Press Shut-In Pressure 6362' 3295 psi 6361' 3295 psi ': 6361' 3295 psi ' 6382' 3310 psi 6381' 3305 psi TIGHT 6409' 3323 p~i 6408' 3319 psi TIGHT 6444' 3344 psi 3221 psi 6450' 3342 psi 3173 psi 6443.9' 3331 psi 3185 psi ;463' 3343 psi ;468.9' 3346 psi 3178 psi 6483' 3353 psi 3183 psi 6490' 3355 psi 6490' 3353 psi 6489.1' 3349 psi TIGHT 6504.1' 3360 psi TIGHT 6542.1 3388 psi 6538.0' 3382 psi 6662' ~71 p~i 'T!GHT 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . Date /~ ~//~--~--~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion.- Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 ADDENDUM WELL: 12/02/85 12118185 12/19/85 12/30/85 6/19/86 8/14/86 9/9/86 3J-9 RIH to 1800', displ contaminated brine w/10.3 ppg filtered brine. RU CTU, RIH pmp'g hot brine @ 1.5 BPM, wrk'g CT up & dn @ 200'. POOH w/CT, filling 7" csg w/brine. Displ brine in coiled tbg w/diesel, RD CTU. RU Schl, rn static pass f/surf-1800', log PTS f/surf-460'. RU Schl, rn GR/CCL/CET & gage ring f/6678'-5300' & 3490' - surf. Rn GCT gyro f/PBTD - surf. Monitor circ rates. RU SL, RIH w/6" gage ring to ±2025' WLM, POOH. Arctic Pak'd well w/175 sx AS I & 35 bbls Arctic Pak. (First Arctic Pak failed). Frac'd Kuparuk "A" sand perfs 6450', 6453', 6470', 6483', 6484', 6485' & 6536'-6545' in 7 stages per 9/4/86 revised procedure using gelled diesel, 100 mesh & 20/40 mesh. Press'd ann to 2540 psi w/diesel. Tst ins to 7600 psi; OK. Stage #1: Pmp'd 69 bbls gelled diesel pre-pad @ 20 BPM & 5400-4600 psi Stage #2: Pmp'd 21 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM & 4500 psi Stage #3: Pmp'd 172 bbls gelled.diesel pad @ 20 BPM, 4500 psi Stage #4: Pmp'd 21 bbls gelled diesel w/3 ppg 20/40 mesh @ 20 BPM, 4900 psi Stage #5: Pmp'd 51 bbls gelled diesel w/6 ppg 20/40 mesh @ 19 BPM, 5800 psi Stage #6: Pmp'd 51 bbls gelled diesel w/8 ppg 20/40 mesh' @ 18 BPM, 6200-6500 psi Stage #7: Pmp'd 2 bbls gelled diesel flush. Well screened out. Pmp pressure limit switches. Trip~ed @ 7000 psi. Shut down 39 bbls short of desired displm't; 10 bbls of 8 ppg in formation Pmp'd 840# 100~mesh & 14,860# 20/40 mesh in formation leaving appr/o~ 10,100# 20/40 mesh in csg. Load to recover 357 bbls of gelled diesel. Job complete @ 1212 hrs, 9/9/86. ADDENDUM WELL: 3J-9 9/10/86 RU CTU, RIH w/2" jetting nozzle to 4700', wsh sand to below tbg tail, tag PBTD @ 6690' CT depth, circ well cln, POH, disp'g to cln diesel, RD CTU. Drilling Superintendent Date STATE OF ALASKA ALASI'X~--)IL AND GAS CONSERVATION COMM~.,~ION REPORT OF SUNDRY WELL OPERATIONS Feet 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging ~ Perforate::~;: Pull tubing Alter Casing [] Other Z:Z Com[:)'l e'h_.e 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 990' FSL, 564' FWL, Sec.3, T12N, R9E, UM At top of productive interval 1431' FSL, 1198' FWL, Sec.3, T12N, R9E, UM At effective depth 1446' FSL, 1224' FWL, Sec.3, T12N, R9E, UM At total depth 1450' FSL, 1231' FWL, Sec.3, T12N, R9E, UM 5. Datum elevatiOn (DF or KB) RKB 74 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3J-9 8. Approval number 163 9. APl number 50-- 029-21466 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3406' 6790'MD 6655'TVD 6680 'MD 6545 ' TVD Size 16" 9-5/8" Pr oducti on 6734 ' 7" feet feet feet feet Plugs (measured) None Junk(measured) None Cemented 171 sx AS II 1010 sx AS III & 295 sx Class G 356 sx Class G & 175 sx AS I Measured depth 1lO'MD 3436'MD 6764'MD ~ue Vertical depth 110'TVD 3436'TVD 6628'TVD Perforation depth: measured 6450 'MD 6453 'MD true vertical 6316 'TVD 6319 'TVD Tubing (size, grade and measured depth) 2.-7/8", J-55, tbg w/tail @ 6268' Packers and SSSV (type and measured depth) HB pkr @ 6196' & FVL SSSV @ 1783' 6470 'MD 6484 'MD 6483 'MD 6485 'MD 6336'TVD 6350'TVD 6349'TVD 6351 'TVD 6536' - 6545 'MD 6401' - 6410'TVD 12. Stimulation or cement squeeze summary RECEIVED S E P 0 9 1986 N/ IntervalAs treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 13. Representative Daily Average Production or Injection Data N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation Tubing Pressure 14. Attachments (Completion Well History w/Addendum, dated 6-26-86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and Correct to the best of my knowledge Form 10-404 Rev. 12-1-8 Title Associate Enqineer (DAM) SW0/092 Date C/',.5'-~b Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report- Daily InatructJona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are stalled. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. Dislrict Alaska Field Kuparuk River Auth. or W,O. no. AFE AK0162 Nordic #1 ICounty. parish or borough North Slope Borough ILease or Unit 25630 Imitle Re comp let ion IState Alaska IWell no. 3J-9 AP1 50-029-21466 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 8/09/86 thru 8/11/86 8/12/86 8/13/86 8/14/86 8/15/86 8/16/86 thru 8118/86 Date and depth as of 8:00 a.m. IA"cOw.'. 56.24% 8/10/86 1745 hrs. Complete record for each day reported 7" @ 205' (Top of) Brine Accept rig @ 1745 hrs, 8/10/86. ND tree, NU & tst BOPE. RIH, tag top of 7" stub @ 205', set dn @ 236', cent RIH to 2016', circ, POOH. PU 7" csg spear & fsh'g assy. 7" @ 258' (Top of) Brine RIH w/7" spear, jar on fsh, tel spear, POOH. RIH w/6-1/8" flat btm mill; unable to get below 206'. RIH w/6-1/8" string mill, wrk thru TOF to 261', POOH. RIH, cut 7" @ 258'. RIH w/7" spear, jar on fsh, spear pulled free, POOH. RIH w/new 7" spear, spear fsh, POOH w/52' of 7" csg. RIH w/6-1/8" flat btm mill to 1800', circ & warm well, POOH. 7" @ 695' (Top of) POOH. Rn scrpr to 258'. Rn & set RTTS @ 180', tst above to 500#; OK. Set RTTS @ 247', tst below; some rtns around pkr. RIH, cut csg @ 695'; left 1 cutter in hole. RIH w/7" spear, POOH w/7" csg, dropped colr clamp pin in hole. Rn csg scrpr to 695'. RIH, set RTTS @ 679', break dn formation @ 700#; pmp in @ 3 B?M w/900 psi. 7" @ 6764' 2049' PBTD, LD 7" csg stub 10.3 ppg NaC1/NaBr Arctic Pak w/175 sx AS I thru RTTS pkr. csg. BO 7" csg stub, ?OH & LD same. Rm cmt f/top of 7" 7" @ 6764' 2049' PBTD, Tst BOPE 10.3 ppg NaC1/NaBr LD 7" csg stub. Fsh f/junk w/magnet on WL. Rm cmt 695'-726' RU & rn 18 jts, 7", 26#, J-55 BTC csg. Screwed into colr @ 726' & tst csg. Set 7" csg slips, ND BOPE, instl tbg head. & tst BOPE. 7" @ 6764' 6680' PBTD, Displ well w/diesel 10.0 ppg NaCl/NaBr Make 2 trips w/jet bkst, rec'g junk off of BP. Retry BP. Rn gage ring to 6550'. RIH w/6-1/8" bit, rev out dirty brine. Displ hole w/10.0 ppg brine. RU DA, perf 6536'-6545' @ 4 SPF & 1 shot @ 6483', 6484', 6485', 6450', 6453' & 6470'. RU & rn 196 its, 2-7/8", 6.5#, J-55 RUE 8RD AB Mod tbg w/SSSV @ 1783', HB Pkr @ 6196', TT @ 6268'. Displ well w/diesel. The abo~.J~ correct Signal re For form preparatiol~a~d distribution, see Procedures Maffl~[l, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submil;ed also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICount"y or Parish Alaska I North Slope Borough Field Lease or Unit Kuparuk River ADL 25630 Auth. or W.O. no. Title AFE AKO162 Recompletion Nordic #1 API 50-029-21466 IAccounting cost center code State Alaska IWell no. 3J-9 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Workover 8/10/86 Date and depth Complete record for each day reported as of 8:00 a.m. I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our ~ Prior status if a W.O. 1745 hrs. 8/19/86 7" @ 6764' 6680' PBTD, RR Diesel Fin displ'g well to diesel. Old TO Released rig 0800 hrs. Classifications (oil, gas, etc.) Oil INew TO Date Producing method Flowing Potential test data Set BPV. RR @ 0800 hrs, 8/18/86. PB Depth 6680' PBTD J K .d of rg Rotary 8/18/86 Type completion (single, dual, etc.) Single IOfficial reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, spa X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling Supervisor Drilling, Pages 86 and 87. ADDENDUM WELL: 12/02/85 12/18/85 12/19/85 12/30/85 6/19/86 3J-9 RIH to 1800', displ contaminated brine w/10.3 ppg filtered brine. RU CTU, RIH pmp'g hot brine @ 1.5 BPM, wrk'g CT up & dn @ 200'. POOH w/CT, filling 7" csg w/brine. Displ brine in coiled tbg w/diesel, RD CTU. RU Schl, rn static pass f/surf-1800', log PTS f/surf-460'. RU Schl, rn GR/CCL/CET & gage ring f/6678'-5300' & 3490' - surf. Rn GCT gyro f/PBTD - surf. Monitor circ rates. RU SL, RIH w/6" gage ring to ±2025' WLM, POOH. Drilli~~n uperintend~ /Date STATE OF ALASKA ALASI~"~OIL AND GAS CONSERVATION COMMI'&'SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate ~ Other~,,._ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage~ AK 99510 4. Location of well at surface 990'FSL, 564'FWL, Sec.3, T12N, RgE, UM At top of productive interval 1431'FSL, 1198'FWL, Sec.3, T12N, R9E, UM At effective depth 990'FSL, 564'FWL, Sec.3, T12N, R9E, UM Att(~t~b~-PstLh, 1231'FWL, Sec.3, T12N, RgE, UH 5. Datum elevation (DF or KB) 74 ' RKB 6. Unit or Property name Kuparyk River g13~ 7. Well number 3J-9 8. Permit number 85-249 9. APl number 50-- 029 -21 466 10. Pool K~Jparuk River Oil Pool 11. Present well condition summary Total depth: measured 6790 feet true vertical 6655 feet Plugs (measured) (see below) Effective depth: measured 2 049 feet true vertical feet 2049 Casing Length Size Conductor 80 ' I 6" Surface 3406 ' 9-5/8" Product i on 6734 ' 7" Junk (measured) N/A Cemented Measured depth 171 sx AS II 1lO'MD I 01 0 sx AS I I I & 3436 'MD 295 sx Class G 356 sx Class G & 6764'MD 250 sx AS I ~ue Ve~icaldepth 110'TVD 3436'TVD G628'TVD _. Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None RECEIVED J U ['4 0 6 1986 Alaska Oil & Gas Gens, Oommissio~ Anchorage Packers and SSSV (type and measured depth) 7" retrievable Bridge plug (~ 2049' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch~,. 13. Estimated date for commencing operation June 10, 1986 14. If proposal ~vas verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~/ r~L/-L~ Title Associate Engineer (~ Commission Use Only ( LWK ) SA/054 Date ~-L~-8(~ . Conditions of approval Approved by Notify commission so representative may witness Approval No. /~,~ ~L-~ [] Plug integrity /~ BOP Test [] Location clearance Gommissionor tho commission Dato Form 10-403 Rev 12-1.85 Submit in triplicate ARCO Alaska, Inc., proposes to Arctic Pack and complete Kuparuk 3J-9. The procedure will be as follows: 1. NU BOPE and test. 2. RIH. Cut and pull 7" casing ~ 265'±. 3. R I H wi th 9 -5/8" RTTS packer to 1 ocate 1 eak. 4. Downsqueeze Arctic Pack below packer. 5. Unseat packer and displace with Arctic Pack to surface. 6. POOH wi th packer. 7. R IH with spear and backout top joint of 7" casing. POOH. 8. RIH with 7" casing to 300'±. MU 7" casing and test to 3500 psi. 9. ND BOPE. NU tree and test. 10. NU BOPE. 11. RIH to retrieve 7" Bridge plug ~ 2049'. POOH. 12. Test 7" casing to 3500 psi. 13. Complete as approved in original Permit to Drill. Kuparuk 3J-9 is being evaluated for used as a water injector or a water alternating gas injector. SA/O54a:tw 06/06/86 11" 5000 psi BOP Stack" · BLn~ ~ 'L 1. 16" conductor 2. 16" 2000 psi x 16-3/4" 2000 psi starting head 3. 16-3/4" 2000 psi x 11" 3000 psi casing head 3 4. 11" 3000 5. 11" 5000 6. 11" 5000 7. 11" 5000 psi x 11" 5000 psi tubing head psi pipe rams psi blind rams psi annular _-~.~nticRichfieldCompanY"~> Daily Well History-Initial Report Instructlone: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0162 Rowan 34 ICounty or Parish North Slope Borough L ...... Unit ADL 25630 Title ~ R~e~~e t ion ~for'Ko¢cr IState Alaska IWell no. 3J-9 A_PI 50-029-21466 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 2/06/86 2/07/86 Date and depth as of 8:00 a.m. 2/6/86 Complete record for each day reported IHour 0600 hrs. IA.R.Co's W.I. Prior status if a W.O. 56.24% 7" @ 6764' 6680' PBTD Accept rig @ 0600 hrs, 2/6/86. 7" @ 6764' 6680' PBTD, POOH w/stinger 10.3 ppg brine Rev out diesel in 7" x 2-7/8" w/10.3 ppg brine. ND tree. Pull pack-off. RIH w/7" spear, att to retry slips on 7" w/o success. Rn APR freept, unable to find freept & no movement on csg. POH & LD spear. NU & tst BOPE. RIH w/retrv BP on 3½" DP, set @ 2049', POOH. The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title Drilling Superintendent ~,-' STATE OF ALASKA ~¢,¢.~ ALASKA O~ AND GAS CONSERVATION coi~¢¢IISSION ~- MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONSd · Drilling well [] Workover operatior¢~] _). Name of operator 7. Permit No. ARCO Alaska, Inc. 85-249 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21466 4. Location of Well atsurface 990' FSL, 564' FWL, Sec.3, T12N, RgE, UM (approx) 5. Elevation in feet (indicate KB, DF, etc.) 74 ' RKB 6. Lease Designation and Serial No. ADL 25630 ALK 2563 For the Month of February ,19 86 9. Unit or Lease Name Kuparuk River Unit 10. Well No. ~J-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig @ 0600 hfs, 2/6/86. ND tree. NU BOPE & tstd. Set bridge plug ~ 2049'. Cut 7" csg (~' 35' RKB. Pulled csg slips. RIH w/free point found csg ~ 250' RKB. Backed off 7" csg (~ 215' RKB & POH. Set RTTS (~ 180' RKB & attempted to pump between 7" x 9-5/8" annulus. Reset RTTS ~ 210' RKB. Found hole in 9-5/8" below 210'. ND BOPE. NU tbg spool. Secured well & RR (~ 0400 hrs, 2/8/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report orO~his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR24 Submit in duplicate ARCO Alaska, Inc. Post Office B~"'~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 3, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3J-9 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU14/L08 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 0'TI' AND GAS CONSERVATION COi~I~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 85-249 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-21466 OTHER [] 4. Location of Well Surface: 990' FSL, 564' FWL, Sec.3, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 74 ' 12. 6. Lease Designation and Serial No. ADL 25630 ALK 2563 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3J-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [-1 Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~,07 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 0600 hrs, 2/6/86. Reversed out diesel in 7" x 2-7/8" annulus (w/lO.3 ppg brine). ND tree. Pulled 2-7/8" tubing. NU BOPE & tstd - ok. Set retrievable bridge plug ~ 2049' and dumped 2 sx (approx. 5' sand on top of plug. Cut 7" csg @ 35' RKB (5' below wellhead). Spear into cutoff & POH. Recovered 5' 7" cs. and csg slips. Found csg 100% stuck ~ 250' RKB. Backed off 7" csg ~ 215' RKB. Recovered 4 joints of 7" cs~ (181.72'). Top of fish (7" csg) @ 212'. Set RTTS ~ 180'; attempted to pump between 7" x 9-5/8" annulus (pumped in ~ 100 psi @ 40 spm). Released RTTS & reset @ 210'. Tstd backside, pressured up to 800 psi - ok. Hole in 9-5/8" below 210'. POH. ND BOPE. NU tubing spool. Secured well & released rig ~ 0400 hrs, 2/8/86. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space bel~/v for Commission se Conditions of Approval, if any: Title Associate Engineer Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 GRU13/5N34 ' " STATE OF ALASKA ALASKA -'OTL AND GAS CONSERVATION C"O,' M ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I% 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-249 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21466 4. Location of well at surface 'r-----------_~ 9. Unit or Lease Name 990' FSL, 564' FWL, Sec.3, T12N, R9E, UNfLC%ATIO~-~T. Kuparuk River Unit At Top Producing Interval ~'E~FJED: 10. Well Number 1431' FSL, 1198' FWL, Sec.3, T12N, RgE, UM Surf.~ 3J-9 At Total Depth j !~. N.__~ 11. Field and Pool 1450' FSL, 1231' FWL, Sec.3, T12N, RgE, UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 74' RKBI ADL 25630 ALK 2563 12. Date Spudded11/07/85 13. Date T.D. R eachedl 1/22/85 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 1/26/85 N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6790 'MD ,6655 'TVD 6680 'MD ,6545 'TVD YES)[~ NO []I N/A feetMDI 1700' (approx) 22. Type Electric or Other Logs Run SHDT/GR, RF'T/GR, WST, GR/CCL/CET/Gauge ring, DIL/GR/LSS, Density/EPT/CNL/GR, Di pmete r/CR, D I L/FDC/CNL/GR, LSS/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 171 sx AS II 9-5/8" 36.0# J-55 Surf 3436' 12-1/4" 1010 sx AS Ill & 295 s~ Class G 7" 26.0# J-55 Surf 6764' 8-1/2" 356 sx Class G & 250 s; AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See core description attached to Well Completion Report dated 1/10/86. Anchorage Form 10-407 DAM/WC83 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 Kuparuk C 6327' 6193' DEPTH HYDRO. PRESS: SHUT-IN PRESS. Base Kuparuk C 6366' 6232' 6362' 3295 psi Top Kuparuk A 6432' 6298' 6361' 3295 psi Base Kuparuk A 6546' 6411' 6361' 3295 .psi 6382' 3310 psi 6381 ' 3305' psi TIGHT 6409' 3323 psi 6408' 3319 psi TIGHT 6444' 3344 psi 3221 p~i 6450' 3342 psi 3173 psi 6443.9' 3331 psi 3185 psi 6463' 3343 psi 6468.9 3346 psi 3178 psi 6483' 3353 psi 3183 psi 6490' 3355 psi 6490' 3353 psi 6489.1' 3349 psi TIGHT 6504.1' 3360 psi TIGHT : 6542.1 3388 psi 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 6538.0' 3382 psi 6662' 3471 psi TIGHT 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation; injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from'more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Jl .,/ I0 -15 14' · I$ 12' '11 I0' .7 6. · 5 4- · $ 2' · I RESERVE PIT RESERVE PIT r NQTES I. COORDINATES ARE A.S.P. ,ZONE 4 2. SECTION LINE DISTANCES ARE TRUE. $ HORIZONTAL POSITIONS BASED ON THE D,S.-$J NORTH- WEST 8~ SOUTHWEST WINDOW CORNERS PER E R.B. &ASSCXZ. 4. VERTICAL POSITIONS BASED ON TBM 85-7-27-1 ,'"ER LHD 8~ ASSOC. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED - RlXX --3060 rev. ~ ~ ! ~0 ~¢ oF 4/..,~t. .~. ~ I .-.-. ..,/ ~'.,--',,,~,-,_-M,-~,,~"~,'"'y"' ~' ~ ~1 ~.0 '~'"~ .... - --/ ~ ~ '~ '" " EL ' ~" .~l ~ -.,.,,~ ~ - F. ~O~E{~T ~, L · ~ ~I ~'~.x;,'::' .. &.'~ I HEREBY CERTIFY THAT lAM PROPERLY REGISTERED AND LISCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA~ THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF dULY :50~ 1985. _ - _ _ _ 7- _ 9- 10- 11- 12- 13- 14- AS B'"LT Y= 6,002,422.64 X= 519,544.60 563~ F~L, 7~0 FSL, Y= 6,002,447.64 X= 519,544.66 563 FilL, 765 FSL, Y= 6,002,472.59 X= 519,544.60 563 FWL, 790 FSL, Y= 6,002,497.59 X= 519,544.63 564 FWL, B15 FSL, Y= 6,002,522.57 X= 519,544.65 564 FWL, 840 Y= 6,002,547.61 X- 519,544.65 564 FWL, 865 Y= 6,002,572.61 X= 519,544.67 564 FWL, BgO Y= 6,002,597.57 X= 519,544.68 CONDUCTOES .!- 16 · LAT. 70°25'0~.020'' LONG. 149°50 26.870" OG. 41.3, PAD 45.3 LAT. 70o25'04.266" LONG. 149°50 26.B66" 0G.41.0, PAD 45.6 LAT. 70°25'0&.512" LONG. 149o50 25.866" OG. 40.9, PAD 45.~ LAT. 70o25'04.758" LONG. 1~9°50 26.B63~ OG. 40.8, PAD 45.5 LAT. 70°25'05.003'' LONG. 149o50 26.B51" FSL, OG. 40.9 PAD 45.~ LAT. LONG. FSL, OG. LAT. LONG. FSL, OG. LAT. LONG. 70025'05.250" 149050 26.859" ~1.0, PAD 45.4 70025 05.495" 149o50 26.856m b1.1, PAD. 70o25 05.741" 149050 26.85~" 564 FWL, 915 FSL, OG. '41,2, PAD. &5.3 Y= 6,002,672.63 LAT. 70025 06.~79" X= 519,544.74 LONG. 149°50 26.8~6" 564 FWL, 990~ FSL, OG. 41.0, PAD 45.5 Y= 6,002,697.65 LAT. 70025 06.725" X= 519,544.74 LONG. 149°50 26.845" 565 ¢wL, 1015' FSL, OG. 41.0 PAD 45.b Y= 6,052,722.6b LAT. 70025 06.97~" X= 519.544.73 LONG. 149°50 26.8~3" 565 F~, 1040'- FSL, OG. 40.7 PAD ~5.3 Y= 6,002,747.62 LAT. 70025 07.217" X= 519,544.78 LONG. 149o50 26.8~0" 565 FN~, 1065'FSL, OG. 40.7, PAD 45.5 Y= 6,0.2,772.67 X= 5.19.-a4.78 565 F~_, 1090' Y= 6,0L},797.59 X= 519.~44.78 565 F~_, 1115' LAT. 70025 07.463" LONG· 149050 26.837" FSL, OG. 40.4, PAD 45.4 LAT. 70o25'07.'708" LONG.149°50'26.836" FSL, OG. 40.3, PAD 45.5 16- Y= 6,002,847.58 LAT. 70°25'08.200'' / DRILL SITE 5d nnmm / CONDUCTOR AS-BUILT mm mm,,/ LOCATIONS ~--/~ ::~ , ' ," ~oo' LOCATED INPIRi::)TRACTEDSEC. 3, TI2N, R9E,U. MER- 15- Y= 6,0~ ;,822.60 LAT. 70°25'07.954'' ARCO Alaska. In Post Offic~'"~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 01-28-85 TRANSMITTAL # 5541 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ One * of each 5" DIL/SFL-GR 12-24-85 Run #1 2" DIL/SFL-GR 12-24-85 Run #1 5" Den/Neu (poro) 12-24-85 Run #1 2" Den/Neu (poro) 12-24-85 Run #1 5" Den/Neu (raw) 12-24-85 Run #1 2" Den/Neu (raw) 12-24-85 Run #1 Cyberlook 12-24-85 Run #1 1700-6966 1700-6966 6100-6940 6100-6940 6100-6940 6100-6940 6100-6900 3J-9 ~3J-10 5" DIL/SFL-GR 11-24-85 Run #2 2" DIL/SFL-GR 11-24-85 Run #2 5" Den/Neu (poro) 11-24-85 Run #2 2" Den/Neu (poro) 11-24-85 Run #2 5" Den/Neu (raw) 11-24-85 Run #2 2" Den/Neu (raw) 11-24-85 Run #2 Cyberlook 11-24-85 Run #2 5" Dual Dipmeter-GR 11-23-85 Run #2 5" LSS-GR 11-23-85 Run #2 2" LSS-GR 11-23-85 Run #2 P~T Log 11-24-85 Run #2 5" DIL/SFL-GR 12-08'85 Run #1 2" DIL/SFL-GR 12-08-85 Run #1 5" Den/Neu (poro) 12-08-85 Run #1 2" Den/Neu (poro) 12-08-85 Run #1 5" Den/Neu (raw) 12-08-85 Run #1 2" Den/Neu (raw) 12-08-85 Run #1 Cyberlook 12-08-85 Run #1 3448-6770 3448-6770 3448-6744 3448-6744 3448-6744 3448-6744 6100-6717 3448-6767 3448-6762 3448-6762 6361-6662 0100-7322 0100-7322 2336-7298 2336-7298 2336-7298 2336-7298 2400-7275 *The API serial # is incorrect on all of these logs. it should read 50-029-21500. Receipt Acknowledged: State of AK*bl/se NSK Clerk*bl _ R Date: ~s~ OIt ,', ~,:~ uu,,~. ~ommJ~Jo~ Dri!ling*bl Rathmell*bl D & M*bl Vault*films ARCO Alal~'a, Inc. ~ · SuDi~a~·r¥ OI AllantlcRichfJe/clComDanY ARCO Alaska, Inc. Post Office B'~)"~i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3J-9 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to repair a surface casing leak in 3J-9. Since we expect to start this work on February 3, 1986, your earliest approval will be appreciated. If you have any questions, please call Larry Kappmeyer at 263-6980. Sincerely, J. Gruber Associate Engineer JG/tw SN/L090 Enclosure Ala,ka Oil & Gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKAO1L AND GAS CONSERVATION COI~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Nameof Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage~ AK 99510 4. Location of Well Surface: 564' FWL, 990' FSL, Sec.3, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 7. Permit No. 85-249 RKB 74' 12. 8. APl Number 50-- 029-214F, F, 9. Unit or Lease Name Kuparuk R,.'ver Unit 10. Well Number 3J-9 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River Oil Pool ADL ~_5630 ALK 2563 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate} Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to repair a surface casing leak in 3J-9. The procedure will be as follows: I. 2-7/8" ci rcul ati ng string wi 11 be pul 1 ed. 2. 7" ret. Bridge plug set inside 7" casing. 3. POH w/7" casing from above Bridge plug. 4. Set Arctic pack annulus w/ret, packer. 5. Set 9-5/8" ret. Bridge plug below casing leak. 6. Repair 9-5/8" casing and test. 7. Remove 9-5/8" Bridge plug. 8. RIH w/7" casing. Make up and test. Remove 7" Bridge plug. 9. Perform Arc-~tic pack job. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli w~thin the permafrost interval. ~. ~ .,F ~ ,~~~ ~,j~ ~..~i~, ~ Estimated Start: February 3, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.(f~ ~ Title Associ ate Engi neet The space belo~l/for Commission use Date Conditions of Approval, if any: Approved by_ Form 10-403 Rev. 7-1 ~0 COMMISSIONER By Order of the Commission Date SN/129 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate General Purpose Worksheet iSuDject File ]Paae No. By %. General Purpose Worksheet tSubjec! File 1Page No. Of I'~ I~''''/~q,~ i K~4PfI~. u K ~_IRe..qL,~T//JG uJAAr',l B,~ltJ~. RECEIVED JAN 2 4 I986 Alaska, 0it & Gas Cons. Coa'imission 0 Anchorage ARCO Alaska, Inc. Post Office B~j~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 10, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3J-9 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3J-9. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/mh GRU13/L169 Enclosure Alaska Oil & Gas Cons. Oommjssio~ Anch0rag~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKa..,,.... AND GAS CONSERVATION 'Q_,_~_~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED r~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-249 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21466 4. Location of well at surface 9. Unit or Lease Name 990' FSL, 564' FWL, Sec.3, T12N, RgE, UN (approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3J-9 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 74' RKBI ADL 25630 ALK 2563 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore J 16. No. of Completions 11/07/85 11/22/85 11/26/85J N/A feet MSLJ N/A 17. Total Depth' (M D+TV D)6790 'MD, 18. Plug Back Depth (MD+TVD) 6680 ' MD YEsl 9. Directional Survey[] NO I-~X J 20. Depth where SSSV setN/A feet MD I21 ' Thickness °f Permafr°st1700' ( app rex) 22. Type Electric or Other Logs Run 5HD I/CiA, t~1- T/Gl~, w51, GR/CCL/CET/Gauge ri ng, D I L/GR/LSS, Densi ty/EPT/CNL/GR Dipmeter/CR, D IL/FDC/CNL/CR, LSS/CR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 11~" '6Z.5# H-40 Surf 110' 24" 171 sx AS !1 9-5/8" 36.0# J-55 Surf 3436' 12-1/4" 1010 sx AS Ill & 295 s; Class G 7" 26.0# J-55 Surf 6764! 8-1/2" 356 sx Class G .. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) --Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED,1~ OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE '~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See attached core description EiVED A!aska Oil & Gas Cons, hnehr~r~-~ Form 10-407 TEMP3/WC36 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. _ · GEOLOGIC MARK'ERS ' ' FORMATIONTEST~; ~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted w~ ,~n gyro is rece~¢ed, WST data to be submitted when received. 31. LIST OF ATTACHMENTS Core Description: Vle]] History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~ ~'~-~' ~:/~J~L/ Title Ass°¢i ate Engi neet Date /-/~) -~-~ __ _ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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". TEMP3/WC36a Form 10-407 3J-9 CORE DESCRIPTION Core # 1 Core #2 Core #3 Core #4 Core #5 Core #6 Core #7 Core #8 Core #9 6320 - 6351 ; cut 31 , recovered 29'10" Shale and siltstone 6351 - 6395 ; cut 44 , recovered 42'5" 1' sandstone, 40'5" siltstone 6395 - 6412 ; cut 17 , recovered 17' 1' sandstone, 16' siltstone 6413 - 6427 ; cut 14 , recovered 13'10" 13'10" siltstone 6327 - 6337 ; cut 10 , recovered 9'11" 9'11" siltstone 6438 - 6459 ; cut 21 , recovered 15'6" 10' sandstone, 5'6" siltstone 6459 - 6507 ; cut 48 , recovered 46' 10' sandstone, 36' siltstone 6507 - 6567 ; cut 60 , recovered 41' 1' sandstone, 40' siltstone and shale 6567 - 6604 ; cut 37 , recovered 24'5" 24'5" shale GRU12/CDO2:tw 12/18/85 ~, lal~-Pmplm and .~bmlt the "lnlt~l R~4rl" On,thl..flret Wednesday aftez a well Is spudded or workoVer operations are started. : ' ' , -: ,'-: Dilly work' prior te Ipuddlng ~hould be iumm_~ed*on the form giving Inclusive dates only. :: DI-tdot Alaska Kuparuk River Field Auth. or W,O, no. AFE AK0162 · ::.c~ · -.,:.::,. - North Slope Borough Leaae or Unit ADI. 25630 State Alaska IWell no. 30'-9 Rowan 34 AP1 50-029-21466:- Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour Spudded 11/7/85- : :: .0430 hrs, Date and depth as of 8:00 a.m. 11/o5/85 11/o6/85 11/07/85 11/o8/85 11/o9/85 thru 11/12/85 11/[3/85 11/14/85 Complete record for each day reported IARCO W.I. Prior status if a W.O. 56.24% 16" @ 110' General RU. 16" @ 110' General RU. 16" @ 110' 228', (118'), Drlg Wt. 9.3, PV 18, YP 25, PH 10, WL 9.5, Sol 4 'Accept rig @ 2230 hrs, 11/6/85. NU diverter sys. 0430 hfs, 11/7/85. Drl to 228'. Spud well @ 16" @ 110' 2097', (1869'), Drlg Wt. 9.7, PV 17, YP 23, PH 9.5, WL 6.3,-Sol 6 Drl to 2097'. 9-5/8" @ 3436' 3436', (1364'), Tst BOPE Wt. 9.1, PV 8, YP 9, PH 9.5, WL 8.5, Sol 3 Drl to 3461', C&C, TOH. RU Schl, log DIL/GR/LSS f/3461'-114', log FDL/EPT/CNL/GR f/3461'-1682' & 3461'-2870'. Log Dual Dipmeter/GR f/3461'-1682', RD Schl. Make cond'g trip. RU & rn 87 jts, 9-5/8", 36#, J-55 HF/ERW csg w/FS @ 3436', FC @ 3354'. Cmt w/1010 sx AS III w/10#/sx Gilsonite, followed by 295 sx C1 "G" w/l% S-1 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 1830 hrs, 11/11/85. ND diverter sys. NU &tst BOPE. 9-5/8" @ 3436' 3554', (118'), Trip f/DD Wt. 9.1, PV 8, YP 10, PH 9.5, WL 8.8, Sol 3 Tst BOPE. PU BHA, TIH to FC, tst csg to 1500 psi. DO cmt & flt equip + 10' new hole to 3471'. Conduct formation tst to 12.5 ppg EMW. Drl to 3554' KOP, TOH f/DD. 9-5/8" @ 3436' 4496', (942'), TIH Wt. 9.2+, PV 13, YP 7, PH 9.5, WL 7.2, Sol 6 DD & surv 8½" hole to 4496'. 3513', Assumed vertical 3727', 8.7°, N58.9E, 3726.38 TVD 16.09 VS 8.38N, ,~ " A~ska Oil ? ~, The above Is correct For form preparation and dlstrlbut~n, see Procedures Manual, Section lB, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company,,,"~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the' week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Alaska County or Parish Field ~Lease or Unit Kuparuk RiverI ADL 25630 Date and depth Complete record for each day while drilling or wOrkover in progress as of 8:00 a.m. North Slope Borough IState Alaska IWell no. 3J-9 11/15/85 11/16/85 thru 11/18/85 11/19/85 11/20/85 11/21/85 11/22/85 9-5/8" @ 3436' 5425', (929'), Drlg Wt. 9.3, PV 15, YP 13, PH 9.5, WL 6.4, Sol 6 Drl & surv 8½" hole to 5425'. 4444', 27.1°, N61.1E, 4408.08 TVD, 228.45 VS, 116.30N, 198.83E 4976', 23.3°, N53.9E, 4889.49 TVD, 451.20 VS, 242.68N, 386.40E 5292', 18.0°, N54.8E, 5185.06 TVD, 560.40 VS, 307.19N, 477.39E 9-5/8" @ 3436' 6393', (968), Coring Wt. 10.1, PV 14, YP 10, PH 9.5, WL 4.8, Sol 9 Drl & surv 8½" hole to 6320', circ hole cln, TOH. TIH w/core #1, core f/6320'-6351', rec'd 30'. Core #2, 6351'-6393', incompl. 5479', 16.3°, N54.8E, 5363.75 TVD, 614.41VS, 338.98N, 522.45E 5848', 11.1°, N53.6E, 5722.92 TVD, 696.27 VS, 389.67N, 589.65E 9-5/8" @ 3436' 6413', (20'), TIH w/core #4 Wt. 10.1, ?V 15, YP 11, PH 9.5, WL 5.2, Sol 9 Cut core #2, 6393'-6395', rec'd 42.5'. Core #3, 6395'-6413', rec'd 17'. TIH w/core #4. 9-5/8" @ 3436' 6438', (25'), TIH w/core #6 Wt. 10.1, PV 15, YP 8, PH 10, WL 5.2, Sol 8 Cut core #4, 6413'-6428', jammed, rec'd 14'. Core #5, 6428'-6438', jammed, rec'd 9'. TIH w/core #6. 9-5/8" @ 3436' 6512', (74'), Cut core #8 Wt. 10.2, PV 15, YP 8, PH 9.5, krL 5.2, Sol 9 Cut core #6, 6438'-6459', rec'd 15.5'. Core #7, 6459'-6507' rec'd 47'. 'TIH w/core #8. 9-5/8" @ 3436' 6604', (92'), LD core bbl Wt. 10.3, PV 16, YP 8, PH 9.5, WL 5.2, Sol 9 Core #8, 6507'-6567', rec'd 41'. Core #9, 6567-6604', TOH, LD core bbl. The above is correct Sign at u re ,~ ~~~,~ For form preparation and distril~.tion see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inslruclionl: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~ort" should be submitted aJso when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final RapoW' form may be used for reporting fha entire operation if space is available. District }County or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE AK0162 Operator ARCO Alaska, Inc. Rowan 34 A.R.Co. W.I. Spudded or W.O. begun Date Spudded Date and deplh Complete record for each day reported as of 8:00 a.m. 11/23/85 thru 11/25/85 11/26/85 11/27/85 Accounting cost center code State North Slope Borough Alaska ADL 25630 Drill IWell no. 3J-9 API 50-029-21466 rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I JHour J Prior status if a W.O. 11/7/85 ! 0430 hrs. 7" @ 6764' 6790', (0'), Rn'g 7" csg Wt. 10.3, PV 15, YP 9, PH 9.5, WL 5.8, Sol 9 POH w/core #9, no rec'y amts reported. TIH drl & surv to 6790', C&C, TOH f/logs. RU Schl, log DIL/FDC/CNL/GR f/6776'-3430', LSS/GR f/6776'-3406', SHDT/GR f/6776'-3430', RFT/GR f/6776-3430', WST f/6750'-225', RD Schl. TIH, make cond'g rn, TOH. Chg rams to 7". RU to rn 7". 6748', 3°, N61E, 6617.11TVD, 790.32VS, 442.72N, 669.83E 7" @ 6764' 6790' TD, 6680' PBTD, Blow dn 120' brine in 7" csg 10.3 ppg Brine Rn 156 its, 7", 26#, J-55 HF/ERW BTC R-2 csg w/FC @ 6681', FS @ 6764', Mkr jt @ 6299'. Cmt w/356 sx Cl "G" w/1.2 gal/sx D-600, .3% D-65 & .2% D-46. Displ w/10.3 ppg brine using rig pmps, bump plug. CIP @ 1545 hrs, 11/25/85. Chg rams to 5", ND BOPE, instl upper pack-off & tbg head. Tst flange to 3000 psi. Blow brine dn 7" csg. 7" @ 6764' 6790' TD, 6680' PBTD, RR 10.3 ppg Brine Inj 60 bbls diesel in 9-5/8" 11/26/85. x 7" ann. RR @ 1630 hrs, Old TD Released rig 1630 hrs. New TD Date IPB Depth 6790' TD 6680' PBTD I Kind of rig 11/26/85 Rotary Classifications (oil, gas, etc.) Oil IType completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands RECEilr£D Producing method Flowing Polential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production -J ---=, m ~" ~ Oil on test ? ~ .. Gas per day . . Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity ~lowa~l ~ ~ E~tive date corrected A~ ~ ~urls. C0h'i~is8 The above is correct For form preparation an(~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate [Title Drilling Superintendent ~UB.$URFACE DIRECTIONAL SURVEY r~ UIDANCE [~]ONTINUOUS [-~OOL Company Well Name Field/Location Job Reference No. 71265 WEST ARCO ALASKA INCORPORATED WELL 3J-9 (990' FSL, 564' FWL, S3, T12N, R9E,) KUPARUK, NORTH SLOPE, ALASKA $CT DIRECTZ]N~L SURVEY 'JJST]MER LZSTIN'i -g q 3J-~) SURVDY 3~TE: 18-D~'-$3 -'NSZNzr-7: W:ST METHDDS~'~= C]qPdFIT~]q. T]DL LD'-~TI]N: T~N]ENTiaL- Z~IT:RDS_ATi]>4: LIN:&R V=~TZC&i. 'S:CTI]~I: ii,IF_. DIST. PRDJECTED D'4T] ~ T:qGET ~ZIMJTH ~ZI~UTH ~3RTH .D=S 25 '-.~S T C3~PUT~TI2~ 35-9 K'JP~RJR NP~TH O~T=:_ 13-F=B-85 3EOTH INTEqOOL~TED V&LUSS F3R =VEN 100 ~E,=_T O: CgJRSE VSRTIS~L DgGLE$ 3~VI~Ti2N ~Z!MJTH ~ECTION SEVERITY ]EG ~IN DE~ MIq ~EET ~55/100 0 230 3~0 )ioo ' O0 ~130 ~00 TRd: SJ3-S~ VERTIS&L VERTI'&L -0 0 N 0 3 E 0,00 0 7 N 1 59 E -0.0~ 0,37 0 35 N 80 30 .= 0.05 5,73 0 ~1 S Z? 5 ,4 -D.11 1.12 0 13 N 5 58 E -0,46 0,31 0 14 N =13 42 W -0.40 0.95 0 7 N 21 5~ N -0.28 1.39 0 8 N 1~ ~Z ~ -0.27 3.8I 0 17 N 9 Z E -.9.35 3.al 0 15 N 11 ~ W -0,42 2.91 i000 1100 1200 1330 1~30 1500 1500 1730 19~0 ,00 0,00 -7~,00 · 00 100,00 25,00 ,OD 200,30 ,00 299.38 225,98 .00 399.98 325,98 .00 4:99.~8 425.g8 · 00 5~g.g9 525,98 .OD 599,~8 525.93 · 9~ 799,~8 725,98 ,JO 899,97 825,97 0 14 N 78 33 N -3.47 1.09 0 12 S 27 45 W -0.43 0.5~ 0 9 S 8~ 3 ~ -0.a8 0.92 0 10 N 20 27 W -0,82 ~,41 O 1~ S 52 13 W -0.57 ~.~ 0 13 S 27 7 i -0.82 3.5'5 O !7 S ~ 13 W -1.13 ~.2~ 0 ~$ S 5 7 6 -1.Z4 3.9'3 0 8 S ~4 5 E -1,50 0 12 S 59 35 N -1.46 ~,77 2130 2230 2300 ~30 Z?OO 2330 · 00 999,~7 925,97 · 0~ 1099,~? 1025,97 · 00 11.:39.97 1125.97 · 00 12~9,97 1225.97 .OD 1399.~7 13Z5.97 .00 1~'~'9.~7 1425.97 · DO 1599.~7 1525.97 · ~0 1699.~7 1625.~7 · 33 1799.~7 1715.9~ · ~0 18~9.~7 18Z5.97 0 16 N 48 2~ E -1.37 2.39 0 30 N ~$ 57 W -1.Z5 3.41 0 gO N 3 37 W -1.46 ].17 0 Sa N 3 1~ E -1.!I 0 52 N 3Z 1Z W -3.57 1.07 0 $3 q ~$ 3~ J -1.34 0.33 0 ~5 N 5~ 51 N -Z.38 9.53 0 ~5 N 55 13 ~ -3.36 0.5~ 0 23 N 75 43 W -3.69 0 ~2 N ~1 39 W -~.09 ~.11 3030 3100 3230 3330 3q~30 3500 3530 3700 3330 · 09 1999,97 1925.97 · 00 2099,97 2~25,97 ,OO 219~,06 2125,96 · 20 2299.96 !225.96 .DO 2399.95 2325,~5 · 33 2499.~4 2~25.9~ ,DO 2599.33 2525.93 · 90 2699.32 2525.92 .00 2799.)2 2725.92 .03 2399.91 Z825.91 9 0 I T 1Z 0 24 N 5~ 59 N -~.39 1.01 O 1:$ S ~& 45 J -4.97 0.19 0 1; S 42 3 W -5.32 3.27 O 31 S 23 33 ~ -5.52 3.36 %1 S 15 ~3 W -5.5~ 3.21 lq '% 15 1 ,J -7.19 0.31 ~3 N ~l 33 ~ -5.73 ~5 N ~ 17 d 1.30 5.1I 15 N c5 5Z 5 19.52 3.95 2999.91 2~25.'91 3099.)1 3025.91 3199.~1 3125.9i 3299.~0 3ZZ5.90 3399.~0 3325.90 3499.39 3425.89 3599.86 3525.83 3599.~7 3625.47 3797,91 ~723,91 3894.~8 3320.92 2&TE 3; SURVEY: 13-D:C-S5 <SLLY BUSqINS ELEVATION: EN$INEE~: ,4EST 1 7~.00 FT MEASURED DEPTH REST~NSUL&R C]3RDIq~TES H3~IZ. N3RTH/SOUTH E~ST/N:ST DIST. FEET FSET 0.00 X) 0.00 E O.DO 0.34 N 0.20 'W 0.39 0.36 N 0.10 W 0.38 0.33 S 9.02 E 0.33 0.~3 S 0.32 ',,/ 0.53 0.~7 S 0.24 W 0.53 0,19 S 0.23 W O ' Z m9 0'14 ~ 0'36 W 0'38 0.3~ N 0.5~+ W 0.56 0,58 '~ 0,71 N O, 92 0.53 ~ 0.79 W 1.01 0.7Z N 0.7~3 W !.05 0.31 N 0.87 W 1.19 O.TZ ~q 1,O0 W 1.23 0.59 ti 0.99 W 1.15 0.54 'q 1.13 ,4 1.26 0.10 N 1.28 W 1.29 0,24 S 1,25 W 1,28 0,53 S 1,41 W 1,50 0.72 S 1.28 W 1.~? 0,07 S 1.29 W 1,37 0,14 S 1,31 W 1,31 0.53 N 1.,~Z W 1.90 1.19 ~ 1.7~ W 2.20 Z.76 N 1.9~ W 3.38 3.~3 N 2.95 W z,.53 3.8~ N ~,27 W 5,7~ ~,~5 q 5.29 ~ 5.gl 4.52 '~ 6.05 W 7.51 5.24 ~ 5.75 W 3.55 5.B9 N 7.35 W 5.00 N 8.0~ W 10.03 DEPaRTUrE AZIMUTH DE3 MIN ~ 51 35 ~ ~ 47 30 J q 47 8 ~ q 5~ 6 N q 6~ 38 N N 35 25 N S 73 59 ~ S 69 31 ~ S 63 40 J S 79 0 4 S 8~ 1 J N 73 47 ~ q 53 58 N / 35 6 N N 40 43 N ~ 52 36 N ~ 52 10 ~ q 51 19 J / 53 15 ,4 ~ 55 10 ~ N 65 0 ~ q 73 23 N N 15 35 ~ N 32 37 = ~ #~ 37 ~ 3J-9 N3~TH SLOPE,~IL~SK~ C3MPUT~TI]~ Oar~: 13-FEB-~$ DATE OF SJRVEY: i~-3EC.B5 KELLY BUSHINS ELEV&TION: ENGINEER: ~EST 2 7~.00 PT ~NT':R°OL~T63 V&LJES ~OR :VEN lOO FEET O: ME~SURE2 D:PTH TRJE SJ~-$=~ ~E&SURE] V:RTI'~L V:RTI'AL 40DO.OD 3991.$7 3917,47 ~lO0.O0 g085,36 ~012,86 4200.00 41BI,.51 ~107.51 ~30.33 ~3,56.35 ~292.35 DO.DO ~55.~5 ~331.75 4730.00 $535,20 ~551.20 6~30.30 ~725,18 &551.15 4930.03 ~815,B2 ~74!.32 5220.~0 ~905.92 5130.00 ~999.51 ~925,61 5200.00 5093.~2 501~,42 53D0.~ 51~.20 511¢.20 5~00.00 52~3.72 520~.72 5500.30 5379.?1 5305.71 5530.D9 5476.~3 520Z.33 5~00.00 5573.~0 5~30.]3 5671.54 5597.6~ 5~30.30 5769.73 569;.73 5900.00 5869.35 579g.35 51OO.OO 5957.~1 5895.~1 6ZO0.OO 5066.75 599Z.75 6300.00 5156.25 5992.25 ~O0.DO $265.~1 5191.81 )~O.OO 6355.~3 5291.43 ~ O.O3 5~55.10 5391.10 5TOO.O0 556~.~3 549).83 57~0.03 565~.50 55~0.50 CSJRSE V:RTI'AL ]EVI~TI]N ,~ZIMJrq $ECT!ON 3EG MIN DES MIN FE~T 15 11 N 55 11 E 57.90 18 22 N 5~ 35 E 97.23 19 Z5 N 57 &2 E 129.90 22 18 N 50 31 'E 15~.11 25 39 N 50 3~ ~_ 204.57 26 57 N 5~ 5 ~ 259.01 25 ~Z ~ 55 2~ = 335.10 E 379.05 '25 5~ N 55 1 _ 22 %5 N 55 2~ E 451.00 21 11 N 5~ ~,5 5 ~97.7~ 19 20 N 53 55 5 531.63 17 54 N 53 '3~ ~ 562.72 16 34 N 53 5 E 5~1.55 15 57 N 53 12 ~ 61~.86 13 ~6 ~ 52 20 ~ ~43.87 12 18 N 52 44 ~ 665.54 i1 35 N 52 5B - ~ 6~5.65 10 35 N 5~, ~ ~._ 70~.52. ~ 35 N 53 3~ E 72].52 7 10 N 5~ ~1 ~ 733.97 5 58 N 57 ~ ~ 745.13 5 35 ~ 53 23 ~ 755.0a 5 9 N 53 4~ E 754.42 ~ $7 N 51 2~ ~ 773.29 4 Z6 N 50 33 ~ 751.1! 4 7 N 60 +$ ~ ~ 7 N 63 45 : 794.87 DOGLEG RESTANSUL~R CO SEV~IT¥ N3~Tq/S;3Urq E~ DE3/lO3 ~EET ~ Z. 51 ~6. 1.37 54. 2.73 82. 3.3~ 100. 2.85 120. 1.07 143. 1.6'$ 167, 9.4~ I91. 3.2? Z15. Z.45 !39. 1 · 2~ 262. ~.03 ~_83. 1.82 303. 1.53 322. 1.19 3~0. 1.4l 357. 2.01 372. 9.8~ 385. 0.82 399. 1.55 5,10. 1.57 ;20. 2.83 %35. 3.29 3.4i 0.53 3.23 ~52. O.O0 ~56. O.OO ~5'~. 3ROIqATES ST/REST ,_ H]RIZ. DIST, FE:T ~9 N 53.51 : 71.22 35 ~ 77.99 ~ i01.11 53 N 104.52 E 133.25 ~0 N 135.2~ E 163.43 i6 N 170.75 E !08.79 11 N 209.23 E Z53.~9 37 N 2~7.0~ E Z98.~3 18 ~ 283.25 E 3&1.74 ~2 N 319.55 E 385.38 74 ~ 355.35 E ~28.65 38 N 388.~5 E &68.77 B1 N 41~.24 E 506.27 99 N 447.35 E 540.B7 ~5 ~ 473.05 E 572.72 53 q 495.79 E 502.2'9 23 ~ 519.27 E 530,31 ~6 ~ 539.75 E 555,02 51 M 55~.&5 E 57~.3~ ]3 N 573,~2 E 5'99.01 57 N 5B9.43 E 715.3B 59 N 502.57 E 53 ~ 513.72 E 7a8.58 05 N 523.10 E 759.95 21 ~ 631.65 E 769,92 83 N 639.38 E 779,30 98 N 647.53 E 787.~6 98 N 65~.58 E 795,97 $~ ~ 650.98 E ~03.2~ 5~ N 655.6~ E ~09.T~ DEPARTURE AZIMUTH OE3 MI~ ~ 53 28 E M 51 43 E 53 24 ~ 55 37 ~ 55 53 E ~ 55 5'9 q 55 0 q 55 59 ~_ q 55 57 E q 55 54 ~ ~ 55 41 E q 55 3~ E ~ 55 21 E N 55 15 E ~ 53 11 E ~ 55 8 ~ N 55 5 E q 55 4 E q 55 7 -_- q 55 11 E ,q 55 15 E '~ 55 19 E ~ 55 22,_ ~ 55 2~. E KJP~RJ~ N]~TH SLJ~E,AL~SKA DATE: INTE~P3LATEg VALJE$ =gR =VEN 1003 TRU~ SJS-SZA ~E&SURED VERTZ'&L VERTICAL ]EDTq DEDT~ DE~TH 0.09 0.30 -7¢.00 1030.93 999.97 925.97 2330.30 1999.~'7 1925.97 3330.33 Z999.~I 2925.91 ~)3~30 03 3991.~7 391/.4'T 90~9 ~905.~2 ~3~.92 o'000.03 386~.35 579~.33 CDJqS; V'~RTICAL DDS.EG ]~ViITI]~ AZIMdTH SECTIDN SEV:RIT¥ D~G qIN DES MI`4 FE~T OE,3/lO] 0 0 N 0 3 5 O.O0 0 14 N 78 30 W -3.47 0 16 N ¢8 !4 5 -1.37 O !4 N 6~ 5~ W -~.39 15 11 ~ 55 11 E 57.90 ~? ~5 N 55 ~ ~ 461 O0 3 35 N 53 3~ ~ 723.62 4 7 N ,SD ~5 ~ 796.87 0.00 1.09 1.01 !.51 1.2~ 1.57 9.03 1,1E&SJR RE'TAN N3qTH/ FEE O. 0. 5. 45. 262. ~20 · 459. ~GE D~TE 3F SJRVSY: 18-05C-85 KELLY BUSHIN$ ELEVATIDN: ENGINEER: W:ST 3 7~.00 FT 3!JLAR SSUTH T CDDRDI`4ATES EAST/WEST gIST. FEET 0 '4 3 N ? S 9 ,'4 9 N 0.00 E 0.00 0.79 W 1.D1 1.2g ~ 1.37 7. ,35 W 9. ~3 53.51 E 71.22 381{.45 E ~65.77 602.67 E 734.~2 555.6~' ~ ~09.74 ~ZI~UTM q D 0 E S 70 0 J q 51' 19 ~ q 4B 49 E `4 55 57 :-' ~ 55 5 E `455 24 E ~CO ~L~S(a, INC. 3J-9 NDRTH SLD°E~L~S~ DarE: 13-~EB-95 INT=RPOL~T~3 VALJES =3R :VE~ 100 FE:T O= CEJRS= 3SVI~TiEN ]EG qIN 3=~ 0 O N ~ ~ 0 I1 N 5 3~' O, 4 S 40 40 1 0 S ~3 41 0 13 S 23 55 0 11 N ~5 62 0 16 N 1~ 53 0 18 N £~ 37 0 15 ~ 55 39 D&TE OF SJRVEY: 1~-3E3-85 KELLY 5USHIN~ ELEVATION: ~NGIW~R: WEST S:J~-SE~ 3E~TH 0 14 N 1~ 53 0 1~ N 37 39 0 2~ N 2~ 22 0 30 N 3 31 0 55 N 13 0 38 N 15 21 0 ~7 N 53 17 0 38 N 51 17 O ~6 N ~3 35 VERTI'&L OOG EG REST&~ SECTION SEV:RITY N]RTH/ FEET OE~$/103 FEE 0 0 0 6 11 14 O 30 N ~2 1 0 11 S 35 0 25 S 25 15 15 S i~ aZ N ~3 '3~ N 51 35 15 N 55 33 30 x! 55 0.00 O.O0 -0.07 o.19 O.O0 3.40 3.15 ~'~ · 05 -0.47 -3.31 1.23 -9.32 -3.34 3.73 -0.39 3.95 -0.39 TRU~ SJ5-SEA ~EASURE3 V;RTI'~L V:RTi'AL 35PTi DEPTH DEmTH . O.OO 0.00 -7~.00 74.~3 7~.00 O.O0 174.90 174.30 103.00 274.0~ 27~.00 200.00 374.32 374.00 303.00 74 02 47~.00 433.00 · , 74:0Z 574.00 503.00 574.22 67~.00 503.00 774.02 774.30 703.00 ~74.02 874.00 SO].O0 ~74.03 97~.00 903.00 1374.03 1074.90 1303.00 1174.03 1174.00 1100.00 1274.03 1274.00 1200.00 1374.03 1374.00 1303.00 1474.03 1474.00 1400.00 157q.33 1574.00 1503.00 157~.03 157~.30 1503.00 1774.33 177~.00 1703.00 1374.~3 1874.00 I$00.00 1974.]3 1974.00 1933.00 237~.03 Z074.00 ZOO3.O0 2174.3~ Z174.00 2103.00 2274.0~ !274.00 g20O.O0 ?~74.05 237~.00 2303.00 ! 7~.35 2~74.00 .Z¢03.03 __.- 74.07 Z57~.00 2592.00 2674.3~ 267~.00 2503,00 2774.05 277~.00 2703.90 237~.09 287~.00 2303.00 297~.09 2974.00 2903.03 3974.09 3074.00 3003.00 3174.99 3174.00 3100.00 3274.10 3274.00 3209.00 3374.10 3374.00 3300.00 3~74.11 3474.00 3~00.30 357~.11 3574.00 3503.00 3574.33 3674.00 3503.00 3775.5~ 3774.00 3700.00 3~73.31 387~.30 3303.33 -0,33 0.6~ -o.4o t.os -3.55 3.87 -D.60 3.73 -0.59 3.63 -0.75 1.15 -1,01 -1.24 3.2~ -1.51 3.97 -1.38 9.8~ -1.45 0.30 -1.18 1. ~+1 -1.49 -1.24 D.35 -0.69 1.5.~ -i.07 3.93 -2.16 0.55 -2. $8 -3.5~.- 3.31 -¢.02 7~.00 =T -4.83 3.33 -5.23 0.18 - 5 . 66 3 · 4 ~ - 5 · 3 ') 3 · 33 -7.09 3.01 -7.20 3.35 -1.79 5.43 13.61 ~.1~ 35.6'3 3.75 G!JLAR C]]R3IN~TES qERIZ. SOUTH EAST/W=ST DIST. T FEEl FEET 0.00 !q 9.00 E 0.30 0.25 N 0.19 W 0.33 0.37 N 0,15 W 0.~1 0.9,5 ,S 0,19 5 0.20 0.32 S 9.29 ~ 0.59 0.~3 S 0.15 W 0.~5 0.22 .S 3.25 W 0.36 0.35 N 0.40 W 0.'~0 0.24. N 0.5~, W 0.59 0.¢9 ~ 0..5~. W 3.80 0.55 N 0.70 W 0.96 0.78 N 0.'7~ W 1.10 0.77 N 0.93 W 1.21 0.56 N 0.9~ W 1.1~ 0.58 ~ 0,9~ W 1.15 0.39 ~ 1.19 W 1.32 0.20 N 1.19 W !.20 0.12 S 1.30 W 1,31 0.52 S 1.~2 W 1.51 0,54 S 1,23 W 1.3~ 0.55 S 1.34, W 1.$5 0.28 S 1.15 W 1.20 0.39 N 1.50 W !.8~ 1.04 N 1.:~0 ~ 2.08 2.33 ~ 1.79 W 2. 97 3.39 N 2.55 N ~.30 3.57 ~ 3.95 W 5.~0 4.32 N 5.03 W 5.53 4.59 N 5,84 W 7.~3 5.]6 ~ S.EO W '3,31 5.77 N 1.22 W 9.24 5.01 N 7.39 W 9.92 5.BT N 8.27 W lO.l& 5.~5 .~ 8.56 W 13.15 4.¢9 ~ 8.94 W 10.00 3.45 N 9.2~ W 9.37 3.21 N 9.26 W T.13 N 5.07 W ~.75 15.JO N 7.~7 ~ 17.83 2~.21 N 27.27 DEPARTURE ~ZI~UTH OE3 MIN S 67 20 4 S 75 33 ~ ~ 77 48 4 ~ 35 54 d ~ 3~ 1 ~ q 49 20 ~ ~ 51 52 '~ N 52 31 ~ A~ZU ALASKA, I~C. 3J-9 KJP~RJ~ ~3~TH ~L3~E,~L~S~ iNT:RPSL~TEO V~LJES FSR EVEN T~UE SJ3-S~ ~E&SURE2 V=RTIS~L ]SPTfl 3EPTi 3~B1.~ 3974.]0 3909.00 4036.~ ~07~.00 ~00).00 ~293,~2 ~27~,00 ~20~,00 a~3~.53 ~374.00 ~30~.00 20,49 ~47~.00 ~-~32.12 ~574,00 $50~.00 47~3,D~ 4674.00 415~.1~ ~774.00 ~703.00 5272,$~ ~974.00 $93}.00 5179'38 507~.00 5003.00 5!85.05 517~.29 5100.00 5339.35 5274.00 5203.00 5~.35 537~.00 5303.00 5597.50 5474.00 5~0~.00 5730,21 5574.30 5500.00 5832.¢1 5674.00 550D.00 5934.3~ 577~.30 5709.00 6]~5,71 5874.~0 6106.5~ 597~.00 5903.00 5!37.29 5074.00 5003.00 6337.78 $17~,30 5103.00 6~OS.ZZ 5274.00 5200.00 ~598.6] 5374.00 5303.30 ..,"" 39.19 5574.00 5500.00 5790.00 5654,50 5583.60 C]ORS= V~TI'~L 3~Vi&TI3~ AZI~JTH S~CTIgN 35G ~IN 9E3 MIN :EET 15 %? N 55 39 E 63.03 18 11 N 5~ 2% E 93,03 i9 17 N 57 23 ~ 125,32 - = 153,71 2~ 16 N 50 33 ,.: 2.5 50 N 50 23 ~: ~D8.31 25 57 N 57 43 E 253.2~ 25 ~4 N 55 ~3 E 307.15 25 51 N 55 15 E 35¢.56 2.5 38 N 55 4Z E 402.38 23 18 N 55 35 ~ ¢~7.2~ 1 ~2 N $~ 5.9 = 1'~ ~1 N 5% 3 5 52~.87 1~ '7 N 53 35 ~ 55B.21 16 ~3 N 53 3 5 583.75 16 0 N 53 15 ~ 617.24 13 %9 N 52 21 E 5~3,32 12 15 N 5~ 44 = 655 59 11 3a N 52 ~ - 5~5,12 ~9 N ~3 1 E 705.27 3 30 N 53 37 m 721.46 ? 5 N 54 47 ~ 73~.77 5 54 N 57 ~ : 7~5.$8 5 34 N 50 29 = 755.80 5 7 q ~O 55 & 765 15 4 %~ q 51 17_- 77~_,.~1~ 4 ~1 N 63 33 - 731.80 4 7 ~.~ 53 a5 E 739.0b ~ 7 N 50 ~5 E 7)4.~7 1.3-FEB-B5 FE:T OF SEVSRITY DES/IO3 2.31 1.T1 2 B.35 3.9~ 9.65 1.29 1., 79 1.59 1.8] 1.34 1.39 1.17 2.01 3.83 l.Sg 1.54 1.2B 3.65 3.37 3.51 9.6i 3.03 0.03 J~TE 3: SURVEY: K~LLY BUSHING ELE~ATI3N: 5NGI~EER: W~ST FT SUS-SE6 D E ::D T H NSqTH! SIJL~R C33~3I~T6S 5]RIZ, SOUTH EaST/NEST DIST, T F~ET FEET 44,09 61,33 ~1.11 100.20 122,04 1~5.D5 175,33 !01.55 225.73 275.93 ,299.92 320,11 338, BO 356.29 3?2,52 3.~6,5~ 399,3~ %11,13 ~21,I0 $29.10 ~33.%7 440.58 ¢43.18 249,33 ~53,22 ~56.~0 ~59,54 ~9,53 E 55.31 7~,5D E 96,83 102,42 5 130,55 134.~8 E 16~,02 17~.01 E 212,54 217.16 E 262,81 258.7~ E 312.38 298,~ ~ 36D.~9 33~,19 ~ ~0~,11 375.~ E 411.03 E ~95.23 441.75 E 533.95 46~.32 E 563.10 49~.~9 ~ 599.~2 517.9~ E 528,55 53~.31 E 553,~5 537.49 ~ 578.38 574.31 5 599.~9 5~0.05 ~ ?lF.16 503.35 E 735.75 514.39 E 749.%0 623.74 E 760.71 632.32 ~ 770.58 640.52 E 780.03 648.15 E 783.57 555.17 E 795.66 661,55 E ~03,'~4 OED~RTURE aZIMUTH DES HIM ~ 45 19 E N 53 17 E ~ 51 37 E ~ 53 23 E ~ 5~ 57 E ~ 55 42 E ~ 55 55 = 55 o ~ 55 0= q 55 58 : ~55 45 ~ 53 7 : ~ 55 11 ~. q 55 15 ~ 55 19 ,-. ~ 55 ~2 .-. ~552~5 KJP~RJK N]RTH SLD~E,4L~SK6 TOP ,)36SE TOP 3~S= OBT~ ~!JP~R:JK 6 COMPUT~T'I3~ ENT=RPOL~,T=]' VA.JES ~EASJRE2 O5~TH' 5356.90 5~32.00 65B0.30 5790.30 ,D6TE: 13-:='3-~5 'HDS-N HDRIZDNS 51'93.13 5231.95 5297.69 5411.28 5554.50 DRISI~: S J':S- S =4 511'~.13 515T.~5 5223.59 3337.28 5~?0.~8 55:~0.50 D~TE OF SJRVE¥: 18-0:C-85 KELLY BUSHI~S ELE~ATI3N: ?~.00 ENGINEER: WEST SJR~&:E OC4TIDN ~T mSL,56¢' :WL,SEC 3,[I2~,RgE,JM RECTaNGUlAR :ODRDIN~TE'S NDRTH/S]UTq E~ST/~:ST ~!.49 '~ 533.95 ~3.30 N 537.1B ~6.Z2 N 5~2.35 ~50.8D N 550.3Z ¢35.7~ N 55~.72 ~S9.6~ N 555.$~ FT 3J-9 KJ~ARJ:<, Ng~TH 13-FE3-95 D~TE DF SJRVE¥: 1B-D~C-85 K:LLY BUSHINg ELEVATIDN: ENGINEER: ~£ST 7 7~.00 FT T3P BAS,: TOP ~SE P573 'I'D M&RKER <UP~RJK * KU3ARUK C KUP~RJK ~ qEASJRE2 3E~TH 5327,30 5355.33 5~32.00 5545.00 5580.00 5790.30 5193.13 5231.95 5297.59 5411.28 55&&.B8 5554.50 SJ3-S~A 5119.13 5157.95 5Z23.$9 5337.28 5~70.88 5580.50 :SL,5.64' FW REC SJRFa~'E .OCATI~N ~T L,SEC 3, F:iZN,qgE,JM' TANGIJLA~ CgDRDIN~TES RTH/S]UTq E6ST/4EST :INaL ~E~SJRE] DEPTH 6790.03 WE'd_ L3'aTI3N TRJE ~ERTIC~' ]~PTH 665~.50 ~T TD: SJ3-SE~ 55~0.50 H]RIZJNTAL ]EP&RTURE ]!ST6qCE &ZIMJTH ,:6ET ]:G,_ MIN ~39.7~ ~ 55 2~ SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3J-9 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE O0007]ZSS WELL 3J-9 (990' FSL, 564' FWL, S3, T12N, R9E) HORIZONTAL PROJECT ION NORTH 1000 REF O000?~SS 800 soo 400 ~oo -2OO -400 SOUTH -600 SCALE = 1/200 IN/FT -400 -200 0 200 400 600 800 ]000 1200 EP~T WELL 3J-9 (990' FSL, 564' FWL, S3, T12N, R9E) VERTICAL PROJECTION 246. -4oo -2oo o o 2oo 400 soo coo 1ooo 12oo -~--M~-~-~.~-~ ~ ~ : - ~-.~;_ ~ ~ ~ , ~ ~ ~ ~-.~-~-~..~-~-~.L.~.....~4..4-~.~..-L..i...~...~ ....... ~..L..L..;...L.L..L..L.4... ~...~.-L-~..,~..4-.~.-:-.~- .~-~HHH~ 4-~-~-~--+--~;-~---~-~.~--~---~..~--;---~-~4.-~--~-~-- ~--~-~-~-~---~-~4---~-T.4-LL-L.-.-L4--.L4..T4-L.L.; ...... :.--L-L.L..HL.L.;-.; .... --,?~-~-~-r--~ -%-~-~-m+-t-H.-~ -~-~%~- %-~++%~-~--- ~+-el~-~ ~He-+~+-+-+--~.4.-.H--t-+.-fH-4...+-.+ ..... e-.+-..t.-,-.+.+.+-+---* .... -Y~' j ] ] Y'Y~-F~-Y?'F~'-Y] ~'~Tq~F-FF '~?-'~ ] [ [TT":"'-t-tT'F~"'~'t'-t'" "'~-t'"e'k?"~'?+'-wt-?t-'-r-t--'t---t-":-" l'?"t'--~"t'"f"t"-?"t'"~ -'FTT~Y'T~TY' "TT'T~-~'~"~'] ~;-';-;"Z'~'"F"T'"-TT?-Y'F'T-~'¢"-f"~-Y'TT'Y'~'f"~-"'?-'}'l't'"?'"~'"?-?'"? ...... t"t"t"'t-T"f"f"t'"t ..... t"t'"t'"t"t"t'"t'"t'":'" --~"~-'~'?"~?'~?-~ Z-'~"~-~-~" '-~~ ~'?'t~'-~"?-' -'?-'~"~'-~'~"~'"~-?'" 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H~.-H--- ' : : i i , ] ~ : ~ ~ ~ ~ i~[ ~ ~ ~ {i i i :i ~ { ~ : : ,- -, :-: .... !-. .... : .... :--: ,..-: ....... .- ,':'--: ..... :---: ..... : ..... -~:::: ': :' ~:: ~; ~: .g-~--~-:: : : : : -;~i:;::::~ :~ : .~ ~ : : ;~ : :~ ~ ~: : ~: : ~:~' ' ~-~.~.~--~-~.~.-~.-.~--4-.-~::: : : : : ; : : : : ...... ~-.~--~;::: ..... $..-~-.-~..-~,::: ...... ~..~.--~--~:::: ....... ~-..~--.$.--:::: ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~allH] ~~f ~ ~ ~ ~ ~ F ~T 'T"~"T"T-"~ r"T'TT'?7-'7-'T ...... Y'T'-~T"""7'"Y'T"T'" .~_~_~_~.~ ~: ~ ..... ~..;...._.~...~_.~..~ ........... ;...~ ...................... ~..~ ....... ~.; ........... ;...;...,...+ ........... ~ ...... -~-~---bbbH--4-L-.--&~--~--~-~--~-- .~-4--~~- .4--~M-~..~--.~-.~-.-~...H-~--;-~-L.-~-.;...L,...;...~-.-~.-~ ....... ~...~...~...;...t...~...;...~...~ ...... ;...~...;...~...~...~-~...~...~... -4..-~.~.-~..~-~.:.~..---~-~--~4-~..~.- .~4~-~ ~ , ~ -~-~-~--.~L~..4-L.L4...L..--L&4..~.LZ.L.L.~ ....... L4...L.~..+_L_L.L.; ...... L..L.~..L..~.-~-.L-L..L. -b~-H~.4-~4~ ~-~ ~4--~bb'-~.-~--N...~-...4..bH-.+.4...~q.-.~ --~..~-bkb;...;.-~..; ....... ;.-~...;...~ b:4...;...: -..;..~...H...~...;..;-.~..4 ~1'!-~"~ '~'77"I'-~ .... !~~ ~ : ~ ~ ~T'I'" ~'"~T"I-'."~"~- -'~"~T-T"I-~'"i ...... I"~I-I"T"~"T'T"I ...... 7'T"Y'I ....... ,"'~-I"'I-' -~-~-~+'+-'-~-ff---~HH~- ~~ ~-~+- e~ t+~+-' ~+--~+--~H~~': i i -~'*--i-+'~-~-..-;..+-~...HH~...~-..~-e.-.?..~-+-~ ....... ~-.-~-.+.-H. : ; ~ ; i ; ; ; : ~ ~ ; : i { i i : ~ : : ~ : : i i i I : : : : i i i : I i : : : ; ' : : J i i : ; i i i i I ,: i i : : : i i i i i : PROJECTION ON VERTICRL PLRNE GG. - 24G. SO:I. EO IN VERT]CRL BEPTH~ HORIZ SCALE = 1/200 IN/FT ARCO Alaska, inc. Post Office Bo~........,)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: ARCO ALASKA, INC · ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19-85. TRANSMITTAL # 5473 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/~ G3-18-85 Run #1 4570.0-9471.0 ref#' 70997-f~d~F&u~ ~2H-9// 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 ~2H-12 J, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 2U-7// 03-19-85 Run #1 3594.5-8179.5 ref#' 7095~Cc~/~p~? ~'~2v-16/! 06-03-85 Run #1 2973.0-7168.0 ref# 70952-f~p ~3A-10Y! 11-09-85 Run #1 3179.0-7014.0 ref# 70960 ~3A-11~, 11-16-85 Run #1 3208.0-7330.0 ref# 70989 3A-12// 11-23-85 Run #1 3797.0-8006.0 ref# 71003 '~3A-13;/ 12-01-85 Run #1 1800.0-7597.0 ref# 71047 ~3A-14'/ 12-09-85 Run #1 0144.5-7818.0 ref# 71073 ~- 3C-9 ~ 07-10-85 Run #1 3920.0-8332.5 ref#_70996--~ 3F-8~! 11-09-85 Run #1&2 0115.0-7040.0 ref# ?9994 3410 0 3F-9/~ 11-17-85 Run #1 .0-7770. ref# 70990 ~'~3F-10/~ 11-27-85 Run #1 1800.0-6631.0 ref# 71037 3F-11~ 12-05-85 Run #1 0148.0-8618.5 ref# 71061 3J-9~/ 11-24-85 Run #1&2 0~91.0-6789.0 ref# 71034 3J~10-/ 12-08-85 Run #1 0096.5-7348.5 ref# 71074 Receipt Acknowledged: ARCO Alaska. Inc. ~s a Subs~dia~ ot Allant~cRlchl~el~Com~en~ Date: NEW PROJECTS ENGINEERING TRANSMITTAL # 0716 TO: Wm VanAlen DATE: December 17, 1985 FROM: H. D. wHITE/P. S. BAXTER WELL N_h3fE:~3C-4_______.2Z-WS-1 TRANSMITTED HEREWITH ARE THE FOLLOWING: One Copy of Final Blueline & Sepia for each: '~3J-9 2" Dual Induction SFL-GR -~3J-9 5" Dual Induction SFL-GR ~3J-9 2" LDT-CNL-NGT (Porosity) ~'~J-9 5" LDT-CNL-NGT (Porosity) ~-3J-9 2" Natural Gamma Spectroscopy ~'-~J-9 5" Natural Gamma Spectroscopy ' "~3J-9 2" Long Spacing Sonic - GR ~3J-9 5" Long Spacing Sonic - GR ~3J-9 2" LDT-CNL-NGT (Raw Data) 11/9/85 run 1 11/9/85 run 1 11/9/85 run 1 11/9/85 run 1 11/9/85 run 1 11/9/85 run 1 11/9/85 run 1 11/9/85 run 1 11/9/85 run 1 ~-3J-9 5" LDT-CNL-NGT (Raw Data & 25" HI-RES) 11/9/85 run 1 -~-~3J-9 5" Dual Dipmeter - GR 11/9/85 run 1 ~3J-9 5" & 25" Electromagentic Propagation 11/9/85 run 1 ~3J-9 Cyberlook 11/9/85 run 1 PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: P. Susanne Baxter, AT0-527 ...... -- P. Oo Box 100360 Anchorage, Alaska 99510 ARCO Alaska, Inc. Posl Office Bo. 0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 198'5 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports / ~ / Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells' 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED Al~ska ~Jii d, Gas Cons. Cornrnisslor~ Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfieldCornpany. .- STATE OF ALASKA ALASKA O,.~AND GAS CONSERVATION COk._,llSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I1. Drilling we~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-249 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21466 4. Location of Well atsurface 990' FSL, 564' FWL, Sec.3, T12N, RgE, UM (approx.) 5. Elevation in feet (indicate KB, DF, etc.) 74 ' RKB 6. Lease Designation and Serial No. ADL 25630 ALK 2563 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3J-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0430 hrs, 11/7/85. Drld 12-1/4" hole to 3461'. Ran logs. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" to 6320'. Cored f/6320'-6604'. Cont'd drlg 8-1/2" hole to 6790'TD (11/22/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 6680'. Secured well & RR @ 1630 hrs, 11/26/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 110'. Cmtd w/171 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3436'. Cmtd w/1010 sx AS Iii & 295 sx Class "G". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 6764'. Cmtd w/356 sx Class "G". 14. Coring resume and brief description Core #1 f/6320' - 6351'; cut 31' Core #2 f/6351' - 6395'; cut 44' Core #3 f/6395' - 6413'; cut 18' Core #4 f/6413' - 6428'; cut 15' Core #5 f/6428' - 6438'; cut 10' , recovered 30' Core #6 , recovered 42-1/2' Core #7 , recovered 17' Core #8 , recovered 14' Core #9 , recovered 9' f/6438' - 6459'; cut 21', recovered 15.6' f/6459' - 6507'; cut 48', recovered 47' f/6507' - 6567'; cut 60', recovered 41' f/6567' - 6604'; cut 37', recovered 0.' 15. Logs run and depth where run DIL/GR/LSS f/3461' - 114' Density/EPT/CNL/GR f/3461'-1682' & 3461 '-2870' Dipmeter/GR f/3461 ' - 1682' DIL/FDC/CNL/GR f/6776' - 3430' LSS/GR f/6776' - 3406' SHDT/GR f/6776' - 3430' RFT/GR f/6776' - 3430' DST f/6750' - 225' 6. DST data, perforating data, shows of H2S, miscellaneous data None Anchomqe 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repc0ft on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRH/MR59 Submit in duplicate MEMORANOUM TO: ~IRU: State- of Alaska Ch~~ / Lonnie C. Smith !~'':''''' Commis s ioner TELEPHONE NO: DATE: November 19, 1985 FILE NO: D.HPJ4.94 FROM: Harold R. Hawkins ~x_d/'f-'- ~' P et r o 1 eumIns p e c t or X/~;-- SUBJECT: BOPE Test ARCO KRU 3J-9 Permit No. 85-249 Kuparuk River Field Sunday, November 10, 1985: I left Sohio's Pad H location, subject of another report, t~-ARC'0~'S-'K.R.U. 3J-9 to witness a BOPE Test. Monday, November 11, 1985: Standby for BOPE Test on 3J-9. Tuesday,._November 12, 1985: I witnessed the BOPE Test on AP. CO's 3J-9 K.R.U~, there were two failures. I filled out an A.O.G.C.C. Report which is attached. In summary: The BOPE Tests were performed satisfactorily when completed, with the one exception, ARCO is to call our office when the choke valve is repaired and tested. Attachment Thursday, November 13, 1985: John Cui!lary called, the choke valve w~as rePaired'-an'd ceSt~'0ka~. 02-00IA(Rev. 10/79) O&G 5184 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ' Well / 'Mud Systems Trip Tank Pit.Gauge Flow Monitor Gag Detectors Operator /~./~A~O . A. IXA Well .? ILff,v' Location: Sec Z ~/2~ R.~'C~M Drilling Contractor ~LL//$/L~ Ri Location, General ~ Well Sign~ C .er Z Uo ..kee ng ~ Visual Audio BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures RePresentative ///~, ~sentative d~-O~Ltc) ACCUMULATOR SYSTEM Full Charge Pressure ~_? y O Pressure After Closure /~O~ Pump incr. clos. pres. 200 psig . Full Charge Pressure Attained: Controls: Haster Remote C/~ Blinds switch cover~/~ Kelly and Floor Safety Valves Upper Kelly Test Pressure ~~ ' Lower Kelly Test Pressure Ball Type Test PreAsure Inside BOP Test Pressure Choke Manifold Test Pressure No. flanges Adjustable Chokes ~~ 0/~ Hvdrauically operated choke ~L~ Test T~e'' hrs. :. psig psig ~ minMj sec. /// rain ~ sec. ~Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Remarks: ~/ /~ ~ I/",~ fizz ,~/Tf/9/f'F /~f /{/M/F~,Z,/_,) F/~/~ ,, ~ ~ ~ t~ L~-/~/~//~/~ /- ·, - . - . - . . / *~ , - t Distribution orig. - AO&GCC cc - Operator cc - Supervisor October 22, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3J-9 ARCO Alaska, Inc. Permit No. 85-249 Sur. Loc. 564:F~IL, 990'FSL, Sec. 3, T12N, R9E, Btmhole Loc. 1328'F%~L, 1324'FSL, Sec. 3, T12N, R9E, U~-~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~tru~p_urs, C. V. Chatterr*n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o .encl. Department of Environmental Conservation w/o eric! Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B0x'~"~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3J-9 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3J-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on October 22, 1985. If you have any questions, please call me at 263-4970. ~t(egional/ Drilling Engineer JBK/HRE/lt PD/L11 Enclosures RECEIVED 1 19g5 A~asKa 0~ & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AflanticRichfieldCompany la. Type of work. 2. Name of operator STATE OF ALASKA ALASKA 0¥L AND GAS CONSERVATION CO)~VIlSSION PERMIT TO DRILL 20 AAC 25.005 DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL []~X DEVELOPMENT GAS [] SERVICE [] STR ATI G R AP~|:,C'~ SINGLE ZONE ]~ MULTIPLE ZONE ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 564' FWL, 990' FSL, $ec.3, T12N, RgE, UN At top of proposed producing interval 1318' FWL, 1319' FSL, Sec.3, T12N, RgE, UN At total depth~ 1328' F~'L, 1324' FSL, Sec.3, T12N, RgE, UN ! 5. Elevation in feet (indicate KB, DF etc.) RKB 74' PAD /+5' , 6. Lease designation and serial no. ADL 25630 AU( 2563 12. Bond information (see 20 AAC 25.025) Type Statewide Suretv and/or number '?_~., 9. Unit or lease name Kuparuk River Unit 10. Well number 3J-9 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Federal Insurance Company #8088-26-27 Amount $500~000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 3952 feet 3J-8 well 75' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 6800' HD, 6649' TVD feet 2560 10/22/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2892 psig@ 80CF Surface KICK OFF POINT 3554 feet. MAXIMUM HOLE ANGLE 31 o I (see 20 AAC 25.035 (c) (2) 33:)0 psig@ R/~/~c)- ft. TD (TVD) 21/~'//~'/~' 'J'-~'~'~6~/~'~' Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 29' I 29' 109'1 109' + 200 cf ' I BTC 3425' 29' 29' 3454'I 3454' 1010 sx AS III & IgtlY'-:' ¢~//~ ¢ Z&~ ' I 295 sx Class G BLEND ~8-1/2" , 7" 26.0# -55/HF-E~W BTC 6772' 28' Ii 28' 6800'1 6649' 300 sx Class G BLEND 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6800' MD (6649' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2892 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. The Kuparuk formation will be cored. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3J-9 will be 75' away from 3J-8 at SURFACE. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) -- 23. i hereby cFf~ify~hat the foregoing is true and corFect to the best of my knowledge DATE CONDITIONS OF APPROVAL Samples required Mud log required F-lYES C~,.N O []YES [~O Permit number Approval date 85-247~ ., ./.9 .~ 0/.2 2 ~/8 5 (LWK) PD/100 Directional Survey required E~YES []NO APl number 50- 029-21666 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 22, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3J-9 (cont'd) Upon completion of the disposal process~ the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing, Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be instal]ed and tested upon conclusion of the job, After the workover rig has moved off locations this well will be fracture stimulated. KUPARUK R1' VER UNIT 20" .D~ VERTER $CHEMAT ~ C DE SCR I PT I ON I. 16' C~CTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER OUICK-C~CT ASSYo 5. TAhI<O UPPER QUICK-CONNECT ASSY. 6, 20" 2000 PSI DRILLING SPOOL W/lO' OUTLETS. 7. i0' HK3R BALL VALVES W/lO' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF Abaci. AR PREVENTER. 8. 20" 2000 PSI AhX~JLAR PREVENTER. MAI NTENANCE & OPERAT I ON I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOS~ AhI~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE Ah~JLAR PREVENTER IN THE EVENT THAT- AN Ih~LUX-OF ~ELL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE AhD CLOSE APPROPRIATE VALVE TO ACHIEVE DONNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES. A~aska 0il & Gas Cons, Anchora9~ ' ~,m~m,e~O~ R4 -?',,, v J IQR~' '7 6 "g. h -> 5 KILL LIhES 13-5/'8' - .5000 PS! 13~-5/8" - 5DC~ PSI I. 16" -~DO0 '[ 2. I1' ~. 11' - 3~:03PSI 4. ID-5/8' - 5O03) 5, ! ~-5/8' - 533:) A~ATOR- CAPACTTY .T~$T I. O-~C~ AhD FILL AC~O, JVLLATDR R~SE~OIR .'rD PRO:9~ LEVEk WITH HY~IC FLUID. 2-- A,~ 99-tAT AC~TC~ P~ IS ~ ~I ~TH ~. ~ TI~ ~ ~ ~ ~TS SI~T~Y 4 : 15-5/8" BC:P s"rA TEST - LII~ VALVES AD.,IAO~,rr 'tO BCF:' S'TAO<. ALL OTt-ER 4. -~ UP TO 2.50J~i~i~:~:L~-~L.D FIR 10 14ZN. IN- ~ ~ T0~ HO.D FCR i0 I~N. BI m:'t'3 ~ TO 0mPSI; LIhE VALVES. O_OSE TOP PIP~. P~ AND NC~ VALV:'~R ON KILL AND CHOKE 6.-TES~. TO ~ PSI A~D(~_ IN STEP 8.-~ TCP P3.F~ ~ AND O. OS~ BOTTC~ PZI~ TEST BOg-f~h~ PIPE ~ TO 250 PSI AhD 3000 PSI. - Fg_U2D. ~ ALL VALVF. S 2N DR2L.~N3 'r'~'-STAhI)PIPE VALVES, K'~ i Y, ~ ~ Y CIX:~, ~ILL -- . ~PI-PE SAFETY VALVe, AhD Ih~I~ ~ TO 2...90 PSI AhD {5. .l~(Z~ TF_ST IhF'O~TI~DJ CN BLi~VCIJT Pi~-9/E~?t~ 'T~ 'FO:~,, SION,, AhD SE3;D 'TO ~ILLIhi3 S~ISCR. ViE~Y 'F~E3~E. AF'T~:~ F-L~I~hlALLY O=9~RA~ l~ DAILY, Alaska Oil & Gas ~¢e 510084001 REV. 2 -' .MAY 15. I DEE ............... .... .... _'_". ' ' ' BASE PERMAFROST" TVD=1679 ' - · TOP' UONU SNDS" TVD=2274'_ ............... ' ........... c2 ..... 4000_ i .......... BUILD .-3..DE ........ :. ............................................... ' .... w- 30~~.27 ........... - ......... ...... : ................... EOC (BEOI-N-ANOL-E-'-DROP) ..... TVD=4543 TMD=4594 DEP=276 .......... : .... : .............................. TD-.:CL'OO-:PT)-;L- T.VD=6649'-:-THD=6800 -DEP=8$.4~--~---: .... ....... ........................... . .~.~ .... ., ;KUPARUK FIELD.-. NORTH 'SLOPE.. ALASKA .......... .. TVD-6389 : . .... , .... ~ ;.; ;:--::' .-?-:' ': :_..';'~ :--:: .:-N: :66;:DEG ;25 :~MIN -E: ~:;?~a~':~;_~ ' , ; ___ k :_ - ..... '- i ; i _ ........ * _!~4~' . . __;_ L ......... · _ ............................ . . ~ _ _ ~. ... it ..... . _ .. I I ' ;"! .... "'"' ....i' .......... ~,':., . ~ ' ' ~ ' ' t" ~ ' I : ! ; i ~ ' t ' ' ' ' :,, ; ., j . ' ! t ! ~ i. ' ~ I . / : ; : ~ ' ." 't ,' ~ i- .; :.1. . , , ,~ ~ ........... ~ ............. ~ - ~ ~ , ~ , , , ' ' ' ,. ~ , ;, ~ I . ' ~ ' I ; ' . .... I , ' ~ "-"~- : ..... ~ ........ ~-~ J 4_,._ ~ ; · . ' :"'. ~ ' ' '. ' . / : : I ' ' i , : , t .... "~ : i' ' J ; ; ~ : ....... r ........ ~ ........ ;--: ......... : .... :._ ', : ' · : ', ,: 1' ~; , ~ :.,, I ; :~' . ~ , . : · . , , ' ·~ :. ~ . .~ i ~ . I : ' ' t ~ t , ' ~ ' ;J, , ' i · , · ~ . ' . ~ ' ~ ' ~ .......... i ' · ] . , , . ' ' ~ ~ /. / ...... ~ , , ~, , .1. , - ............. ,,, ~ . : I .I .... '.,. . , l- I . . '"-;-t--" "'" " '""'" "' , ,,' I .,'' , ....... ' ~., .... ...... ~-!......,, :,, ~ 4610 " ; . : . ] ................ ~ ............... : .... ' ' ' ' " : ' ; ~ ' ' J i I ' ~ :' ' : ~ ~ ~ ~. . ~ ~ . j t . ~ . i , ' . ~ I : TM ........ ~'T"'~" ~" ' ' -- i : ~ ' : ~ ' ' ' - ____~ ~ · . ..... ,.. ~ . ~ I , . . ~ , ; v~ I ~ ~ ' : · ' ~ ; : I , ~ ~ ~ ~ ,~ ...~ . lop , ~ . ~ , ~ 1 ...... ~- '':''~ ....... I.-L'__L:.=.L.'. f~ 3~ 4048 :!" . ]!~ t , t~:' ' , ' ' ~ ~ ' , I , ' ; ! ~ : : ,' ; ~ , : ' ,""'"'~ .......... I ' : t ' ; ' ' . ; . ' //_~ ' i ' ! ~ : I ~ ~ i. ~ i, 1~~ ~ I . I ~ ~ , ' ~ I ~ .~ I ' ~ ~ ! , , .~ I ' ' ' / ' ' I" ..................... ~ ' t' ' ~ ' :' ~ ' ~ I ~ ~ I ~'~ I I~ ~. ~ ! ' ~ [ ~ : ~ . ', . , ~ I ' ~ ~ t ~ ~"~'"','-~'';"'r",'t' ~ .... ' '-' ; ..... 1. :-;')~'.u~,u ' ~ ' ! , i ~ ~ . ~ ' ~ '~ i ' ' i ~ ' ' t : ' ' ' ; ' ' . . ~ ~g, ~ ~ i~ ~ ~ ~. ; ~ i' ; ' ' 'i~ . ;, t.).TEND EIOND :THis' v'IE:w;'' ],i .~ "~ ~. I ~ ~. . t I ~ , . ,, , , ....~ ...... .......... 1' ..... ........ , ~' ' I~ '~ i ' ','' ~ '~ ~ ~ ] ' I : : J"~ ' ,, ~ . , ~ ...... ~ ~ ~ ~ ' _,....,...=.:...; ....... i O0:ti r ' ~ , t , '~ : ~ r " ....;' ', . . , , , . . ARCO Alaska, Inc. Post Office 100360 Anchorage, ~[T~ska 99510-0360 Telephone 907 276 1215 August 20, 1985 Mr. C. V. Chatterton · Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3J Pad Wells 1-16 Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU11/L07 Enclosure If RECEIVED AUG2 I B5 Alaska Oil & Gas Gons. Commission Anohorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ I1 Il · .11 .$ I, CCX)RDINATES ARE A.S.RtZONE 4 2. SECTION LINE DISTANCES ARE TRUE. 3 HORIZONTAL POSITIONS BASED ON THE D.S.-~d NORTH- WEST. & SOUTHWEST WINDOW CORNERS PER ER.E &ASSOC. 4. VERTICAL POSITIONS BASED ON TBM 85-7-27-1 PER LHD & ASSOC. 5. O.G. ELEVATIONS tNTERP~)LATED FROM S/C DWG. CED - RlXX --3,060 rev. ,ek RECEIVED AUG 2 ~!965 - _- -- I ill_ r'~ i i i _CONDUCTORS_ I-16 · 1- ¥- 6.002,L22.6~ X- 519,5A~.~0 553 FYk, 2- ¥= 5,002,~7.6~ 5~3 r~L, t65~ 3- Y- ~,002,~2.5~ X= 563 F~L, 790' FSL, 56~ F~L. 815' 5- ¥- 5,002,522.57 $6& FYL, SaO' X. 7- ¥= 5,002,572.6! Xo 519,54,,67 56~ FWL, B' Y- 5,002,597.S7 X- 11- Alaska Oil & Gas Cons. Commissioj~_ Anchorage I HEREBY CERTIFY THAT lam PROPERLY REGISTERED AND LISCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA~THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF JULY ~O~ 1985. LOCATED IN PROTRACTED ~,EC. 3, T12 N~ RgE~ U.MER. LAT. 70e25'O&.020~ , LOI~. 1~°50~2~.870 rSL, OG. L1.3. PAD LAI. 70°25'0~.2~# LONG. lag°50'25.a&~ FSL, OG.~i.0,.PAD LaT. 70°25'04.-$12 LONG. OG~ ~0,9, ~O LAT.'70025.~O~.758, LONG, OG. ~0.8, LAT. LONG· ~a9°50*26.66[ 0~, &O,g PAD LAl.-70e25*05.250 LONG. [~g°50~25.8S9~ FSLo OG. ~1.0, PAD LA1· LONG. I49050~26.855 FSL, OG. ~1.1, PAD. LA?. LONG. 56~ FWL, 915 rSL, OG, '~l.2, PAD. a5.3 Y- 5,002,672.53 LAT. 7D°25'O~,&79*' X= 51~,5~4.74 LONG. 1~9°50~26.8~" 56~J rYL. 9~0~ FSL, OG. ~[.0, ~0 ~5.5 Y= 6,002,597.65' LAT. 70eZ5~06.725'' X= $19.5~,.7~, LOI{. l&9°50'26,i&5 5~5' FWL, 1015~ FSL, 0G, &t,0, PAD Y, 6,002,722.5~' LAT, 70°25'O6.gTt'' X- 519,5~&.73 LON6, 1~9~50'26,8~3" 565~ FWL, 20~0~ FSL, 0G. ~0,7, PAD Y- 6,002,7~7.52 LAT. '70°25'07.217" X= 519.5~a.78 'LONG. 1~°50~25.8~0'' 355' PWL, IOEs'rsL, OG, ~0,.7, PAD a5,5 13- Y= 5,002,772,57 LAT, ?0°25'07.&~3" X- SIB.~.?B LONG. 1&geso'26.$37~ 563' FWL, 1D90~ FSL, OG. ~O.q, FAD Y= 6.002.797.5~ LAT. ?0~25'07,?08'' X. 519,'5~q.76 LONG.lag°50'25.836" 563' FWL', 1115' rSt, 0G. LO.3, PAD ~5,5 ¥- 5.082,8~2.§0 Lal, 70°~5'O?,gS&" X- 51g,5~.80 LONG. 149050'26,533 S6~'FWL, 11~0~ FSL, OG, ~0.1, PAD qS.O Y- 6,002.~7.58 LAl. 70~25'06.200'' X- 519,5~.80 LONG· )~9°50'25.831 565* rWL. ll6§'FSL, OG. LO.O. P~D..~$,~ ri'Hi8 mm ,a ti,,. A DRILL SITE 3J CONDUCTOR AS- B U I LT LOCATIONS Date:Aue.~ I~.~' Sell~ I" ' $O0' Drafted, by: ~ D~. I~, #IlK 85 - I$ '-?:. ', :....,.. (2).Loc'.~-: ' 7~' Is well to be loc ted in a defined pool ....... , .................... __- ~ th~ 8) ~3."- ~'::: Is well located, proper distance from property line ................. ...... ~.';..'.4;' Is. well located proper distance from other wells ........... ' ' .... ~':Is sufficient undedica~ed acreage available tn this pool '~.~.]~.~]~~' ' ' Is' operator the onlT' affected part7 -. Can pe~it be approved before ten'day wait .................. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed · - Is the lease number appropriate 13 Is conductor string' provided ' · ..e®®eeeol®e®e®eeeleeeeeeeeeeeeeee.eel®e · 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in~ surface and intermediate or production strings . .. 16. Will.cement cover al2 known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... 18. Will all'casing give adequate safety in collapse,, tension and burst.. 19. Is this well to be kicked off from an existing wellbore ............. 20. Is old wellbore abandonment procedure included on 10-403 ............ 21 Is adequate wellbore separation proposed , · .®eemeeele®eeeeeeeeme.eeeeee (3) Admin (4) Cas g ~' (13 thru 21)' 26) 22. 23. 24. 25. 26. 27. Is a diverter system required / ~ Are.necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to~',~90 psig .. ~. Does the chOke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ~ .eooJe®.oe®o®eee.eeeeeeeeeeeeeeoe Additional requirements ............................................. /4' 0 I-3 HO Additional Remarks: Geol0g~: EngiDeerin~: rev: 03/13/85 6.011 INITIAL ~GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , q~,~oo /~ ~ /-~'~ {'9 ,.) ///(, o / o ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history_ file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , ~----SCHLUMBERGER----~ LIS TAP~] VERIFICATIDN LISTING i'~VP 010 HO2 VERIF.ICATiO,~! Li.,.IING PAGE ! COHr~.ENTS SCHLU~BERGgR LOGS iNCLUDE[) ~ITH THIS MAGNgTIC TAPE: * DuAL INDUCi~ION SPHERICALL~ FOCUSEO hUG (OIL) * OATA AVAILABLE: 3456' TO 114' ~ L[]NG SPACED SONIC LOG (~SS) * DATA AVAILABLE: 34~7' TO 1~4' * hlTHO DENSITY COMPENSATED LOG (BDT) * COMPENSATED NEUTRON bBC; ([,DT) * DATA AVAILABLE: 3459' TO 1682' * ELECTROi~'~AGNETIC PROPAGATION TOOL CEPT) * DATA AVAI.I.,AS[,E: 3440' TO 1682' * ~ATURAb GAMJqA TOO6 (NG'r) * DATA AVA.I~A~LE: 3404' TO 1682' ************************************************************************************ , SCHLUMBERGER * ALASKA CO~P(J'£ING CENTER *************************************************************************************** COi4PANY = ARCO ALASKA INC .~/ELL : 3,.]-9 RECEIVED Anchorage LVP OlO.H02 VERIFICATION LISTING PAGE 2 F I ELD COUNTY STATE KUPARUK ~qORTH SLOPE BOROUG~ ALASKA JOB NUMBER AT ACC: 7103~ RUN #2 DAT~ LOGGED: 23 NOV 1985 5DP: H(hWARD BOLAM CASING ~[YPE FLUID DENSITY VISCOSITY PM FbUI D bOSS ~ATRIX = SAND 9,625" 8 3436.0' - BlT SIZE : 8,5" TO 6790,0' LSND P[iLY~4ER 10,30 LB/G RM : 2,340 @ 66,0 DF 38.0 S RMF 2.260 ~ 61.0 DF 9,5 RMC : ! 790 ~ 64 0 DF 5,2 C] RM AT BHT : 11162 ~ 146' DF ***** THIS DATA HAS NUT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ***** ******************************************************************************* **NOTE** ~ERGE POINT = ~440.0' ON BOTH THE DUAL INDUCTION AND LOMG 8PACED SONIC LOGS, ****************************** , * SCHLUMBERGER hOGS INCLUDEO ~ITH THiS MAGNETIC TAPE: * * DUAL INDOCTIDN SPHERICALLY FOCUSED bOG, (OIL} RECEIVED DEC ?, 0 1985 Alaska Oil & Gas Cons, Go~!nission- Anchm'age bVP 010.H02 YERIFICATION LISTING * DATA AVAILABLE: 6770,0' TO 3448,0' * bONG SPACED SONIC bOG ([,SS) * DATA AVAIbAk~I.,E: 6762,0' TO 3448,0' * FURMATI[)N ~ENSI~Y CON~PENSATED bOG (FDN) * CO,~PENSATED NEUTRON LOG (FDN) * DATA AVAILABLE: 6744,0' TO 3448,0' ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE EN~rRY 2 1 66 0 4 1 66 1 8 4 73 60 9 4 65 ,lIN 16 0 1 66 0 SPE;CIFICATiON BLOCKS SERVICE SERVICE UNI?' AP1 AP1 API API FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO, DEPT FT O0 000 O0 0 0 4 SFLU [,)IL OHMM 00 220 O1 0 0 4 ILM OIL OHMM O0 120 44 0 0 4 lbD DIL O~aa O0 120 46 0 0 4 SP DIL ~v O0 010 Ol 0 0 4 GR DIb GAPI O0 310 01 0 0 4 SGR I.,DT GAPI O0 310 01. 0 0 4 CAbI LOT Im O0 280 01 0 0 4 a~Oa LOT G/C3 O0 350 02 o 0 4 ORHO LDT G/C3 O0 356 O1 0 0 4 NRAT LDT O0 420 O1 0 0 4 RNRA LOT 00 000 O0 0 0 4 NPHI bDT PU O0 890 O0 0 0 4 PEF LOT O0 358 O1 0 0 4 NCN[, LDT CPS O0 330 31 0 0 4 FCab LOT C~S O0 330 30 0 0 ~ ~SS LDT O0 000 O0 0 0 4 a L 5 b O T 00 0:00 00 0 0 4 GR LSS GAPI O0 310 Ol 0 0 4 0 T L S S U $ / F 00 520 ~ ? 0 0 4 OTb [,SS US/F O0 520 80 0 0 4 GR FON GAPI 00 310 O1 0 0 4 CAbI Fr) N iN O0 280 Ol 0 0 4 RHOB FDa G/C3 O0 350 02 0 0 4 PROCESS CODE (OCTAb) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 uO000000000000 68 00000000000000 68 00000000000000 bVP Ol(i,H02 VERIFI. C~TI3i~'~ GISTIbtG PAGE 4 DRHO N R A T R~RA ~PHI FCNL FI) N FDN F D N FDt'~ G/C3 O0 35b O! 0 00 420 0 i 0 O0 000 O0 0 PU O0 890 O0 0 CPS O0 330 31 0 CPS O0 330 30 0 ** DATA DEPT SP gPHI DTb DRHO .~CNL DF. PI SP RHOB DTh DRHO ~CN h OEPT SP RRO~ NPHI DTL DRMU DEPT SP NPHI DTh ORHD DEPT SP RffOB ~PHI QSS DTL DRHD 6789 -23 -999 -999 -999 -999 0 2359 6700 -22 -999 -999 -999 97 0 2309 O0 6~27 -999 -999 -999 i06 0 2039 -999 -999 -999 90 0 2771 6400 -37 -999 -999 285? ,0000 4951 2500 2500 2500 2500 0981 5000 .0000 .3857 .2500 ,2500 .2500 2773 i0522 5000 .0000 .9170 2500 2500 2500 2773 2070 6875 0000 5820 2500 250 O 2500 .500u 0000 6133 250O 2500 25 o o '2773 . ,.1108 ,5000 SFLO GR DRHO PEF GR NEAT FCN b D R H 0 PEF GR NRAT FCNL S F [.~ U GR D R H £] P EF G R NRAT FCNL D R H 0 PEF GR N R A T FC N L SFLU GR DR HO P EF GR m K A T F C N L 2 lo2 -999 -999 -999 102 3 678 3 105 -999 -999 -999 105 3 561 2 100 -999 -999 -999 100 3 526 9 82 -999 -999 -999 878 10 86 -999 -999 -999 86 107~ 1858 7148 2500 2500 2500 7148 2854 3125 3635 7773 2500 2500 2500 7773 1292 8125 9006 8398 2500 250O 2500 8398 .7639 3125 4648 250O 2500 2500 4648 8948 3125 9941 6523 2500 2500 2500 6523 526 875 IbM SGR NRAT NCNb GR CALl RNRA I b~ NRAT NCN5 GR CAhI RNRA SGR NRAT NCN[, GR CAb i R NRA NRAT NCNL CAhI R N R A SGR NRAT N C i'~ b GR CabI RNRA 0 4 0 4 0 4 0 4 0 4 0 4 1,9337 -999.2500 -999.2500 -999,2500 -999.2500 8.8848 3.4768 2.7874 -999.2500 -999.2500 -999,2500 88,2773 92129 3~4885 2 948 -999 ~500 -999~ 500 8'1i~4891 752 7.4:304 -999.2500 -999,2590 -999~500 79.2148 9,1660 3'1545 7.6882 -999'2500 ~ ) ~999,2..~0C. -999,2500 80.4023 9322.3 2~6604 1 68 1 68 I 68 1 68 CALI RNRA FCNL RHOB NPHI IbD CAhI RNRA FCNb O? NPHI I ,b 0 C A b I R~iRA FCNL 01' NPHi ILD C A 1~ I R N R A FCNb OT NPHI bO Ab I RNRA OT RHDB N P H I 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 1.6~09 -999.2500 -999.2500 -999.2500 -999.2500 2,433~ 38,6719 . 2,6487 999;2500 :999'2500 999,2500 96,902~ 2,4788 35,3516 2.2424 -999 2500 -999 2500 -999 2500 lOb 1523 2 4846 45 b055 7,20'78 '999,2500 -.999;2500 -999'2500 89,7773 2,~182 31,494I 7,6726 -999"2500 -999."2500 -999;.2500 8~,:.7773 .4553 27,6855 R. ECEi'VED D C ';'; 0 !9 S 5 A~aska Oil & Gas Cons, Commlssio~ A,,~'h~rSne ~.,.,-.' ..... bv'P 010.H02 VERIFIC.~TION LISTINCI PAGE 5 DEPT 6300 SP -48 RHOB -999 NPHI -999 ~S$ -999 DTL 84, ORHO O. NCNb 2317, 0000 SFLU 1445 GR 2500 DiiHO 2500 PEF 2500 OhS 0273 GR T 0571 NRA 5000 FCNL DEPT 6200.0000 SP -47.8320 RHOB -999.2500 NPHI -999.2500 OSS '999.2500 D'rb 118.2773 ORHD 0,0625 NCNL 1758.6875 DEPT 6100 0000 SP. -25i1201 RHOEt -999 2500 NPHI -999.2500 ~SS -999,2500 OTb 1!3,0273 DRHO 0.0620 NCN[,, 1929,6875 RHOB -999 NPHI -999 QS$ -999 OTb 110 DRHO 0 NCNb 2016 DE.PT ~900, SP -36, Rf{OB 999. NP8I -999 QS$ -999 OTb 10~ ORHO NCNb 2713 0000 4482 500 5OO 2500 2773 0381 6875 0000 8945 250O 2500 2500 2'173 0625 5000 OEPT 5.802~, 0000 SP ,~826 RHOB -999, ~,500 ~Pt~I -999,2500 QS$ '999,2500 O~ 106 i 0273 ORHO 0,0522 NCNb 218515000 SFLO G R PEF GR NRAT GR DRHO GR NRAT FCNb GR DRHO PEF GR MRAT FCNL SFbU GR DRHO PEF QLS GR NRAT FCN D SFL U GR DRHO P EF QLS GR NRA T FCNI, 3.1038 130.6875 -999.2500 -999.2500 -999.2500 130.6875 3.2268 6'76,3125 2 008! 106,5898 -999.2500 -999.2500 -999"2500 106.5898 3.8245 419,3906 2.1096 117 .2773 -99922500 "999,2500 '999.2500 7 ~773 '114:593 476,:390~ -999 2500 -999 2500 -999 2500 161i6875 3 4202 556.3125 5.4343 90,~398 -999. 500 '999 2500 -999 2500 952 8125 :999 ,2500 999 ~500 -999 500 103 773 3 ~420 622 125 SGR NRAT NCNb GR CAbI RNRA SGR NRAT NCML GR CAbI RNRA I L,S NRAT N C N b GR CALl RNRA I [~ t4 NRAT NCN[, GR CALl R~qRA I b M NRAT GR AhI NRA I[,M NRAT NCNL GR CALl RNRA 3 5959 -999:2500 -999.2500 -999 2500 120:0273 11.1035 3.4260 1.5313 999.2500 999.2500 999,2500 100.6523 10.6973 4,1921 1.8936 :999,2500 999.2500 -999,2500 107.8398 10,6113 4.0476 2 5.413 -999 2500 -999 2500 =999 2500 158 6875 10 9629 3.6252 5,3640 '999,2500 '999.2500 500 -999. 273 85. 1~.2676 .8459 I 8868 -999 2500 -999 25OO -999 2500 98 9023 10 8066 3 5081 ILD CALl RNRA FCNL Dr RHUB NPHI ILO CALI RNRA FCNL DT RHOB NPHI ILD CAbI RNRA FCNL RHOB NPHi CAbI RNRA FCNL OT RHOD NPHI I CAbI RNRA FCNb OT IhD C A b I RNRA FCNL RHOB NPHI 3 6428 -999:2500 -999,2500 -999.2500 89,7773 2,4514 34.7168 1,4483 -999,2500 '999,2500 '999,2.500 118 2773 2:3264 45,8496 1 8,262 -99922500 -999,2500 -999~2500 113.2773 2,~811 50, 441 2.4534 -999,2500 -999 2500 -999 2500 110 2773 2 ]713 38 301 5 -999 ~921 50O -999 2500 103 52 2 4866 29 248O -999 250~ -999 250 36,9629 Alaska Oil & Gas Cons, Oommissioa GYP 01.0.H02 VERIF'IC.ATiOi'~ LISTING PAGE 6 R lq ['} B 99: 2500 DRH'q -999, 19PM1 -'999 2500 PE?' -999. '~S$ -999.2500 Qb$ -999. OTb 100,7'17J GR 90. 9RHO O. 0229 NRAT 3. NCNL 2535,5000 FCNb 762. DE:PT 5600 0000 SFLU 2 SP -3311445 GR 92: RHOB -999.2500 DRHO -999. NPHI -999. 2500 PEF -999. QSS -999,2500 QL$ -999. 0'.[' L 100,2773 GR 92. O~So o.o:3o3 NaA~~ 3. '~CNL 2309,5000 FCNL 690. OEPT 5500. 0000 SFLU 3 SP -35,8945 GR 98 RHOB -999.~;500 ORHO -999 NPHI '999,~500 P~'~F '999 (}SS -999.25(30 QLS '999 OTb 97,2773 GR 98. DRHO 0,0361, NRAT 3, NC~[, 227'1.5000 FCNb 730, OEPT 5400,0000 SFLU 2. SP -39,6758 GR 82, RHOB -999,2500 DRH[3 -999, NPHI -999.2500 P .[,] F -999. QSS -999 2500 QL$ -999, OTb 70 1523 GR 82, DRHO 0 0039 NRAT 3, NCNb 2737 5000 FCNL 785. 5~,00 00OO 41 1:445 -999 2500 ,,,999 2500 -999 2500 99 2773 0 0254 2539 5000 DEPT RHOB NP,HI OTb DRHO S~'LU GR D R H 0 PEF QLS G~ NRAT FCN b DEPT 5200,O000 SFLU SP -44,1133 GR RHU8 -999,2500 DRHO ~PH1 -999,2500 PEF 500 ODS ~SS '999,' OTb '50. 383 GR ORHO 0.032'1 NRAT NCNL 2377.5000 FCNb 2 -999 -999 -999 81 3 69'~ 1 89 -999 -999 -999 89 3 661 5979 1523 2500 2500 2500 1523 1077 3125 1799 0898 2500 2500 2500 0898 3323 3125 1624 5898 2500 2500 2500 5898 1487 3125 ,4319 839a 500 500 250C) 8398 2483 3125 3440 52'13 2500 2500 .~500 273 3245 8125 250O 2500 2500 8398 4573 8]~5 SGR NRAT NCNb CALI R~4RA IbM SGR NRAT NCNL GR CAbI RNRA SGR NRAT NCNL GR CAbI R!~RA IbM SGR NRAT NCNL GR CAbI RNRA ibm SGR NRAT NCNb CAbi IbM NRAT NCNb GR C A b I RNRA 2.226~ :999,2500 999.2500 -999,2500 90.9023 9.6113 3,3245 1 8653 -999~2500 -999 2500 '999' .2500 88,5273 9,9863 3,3440 2.531.5 :999 2500 999:2500 -999'2500 86.1523 9,6270 3,1174 2 3264 -999 2500 -999 2500 -999 2500 80 2148 9 8926 3 4846 2 2. 112 -999,2500 -999.2500 -999 ~500 10,~ 1 3. 389 2 0198 -999 2500 -999 2500 '999 2500 81 902J 10 7676 3.5920 ILD CAbI RNRA FCNL NPHI lbo CALI RMRA FCNL DT NPHI I LO CAbI RNRA F C N L OT NPHI CAbI RNRA FCNL OT RHOB NPHI lbo CAb I R;~RA FCNb RHOB NPHI CAbI R N R A FCNL D T NPHI 2 0432 999,2500 '999,2500 99,1523 2.3733 34.3262 1,7676 -999.2500 -999,2500 -999.2500 99 9023 2:3538 37,8906 2.4670 999 2500 : o:2soo -999 2500 2,3303 35,1074 2 1956 -999 2500 -999 2500 -999 2500 1 5001 3b 52 2 1565 -999 2,500 '999 2500 '999 .2500 98 9023 2 4065 37,1,582 1,9981 -999,2500 -999,~500 -999. 500 104.5273 2.3948 39.0625 bVP 010.HO2 VERIFICA1]ION LISTING PAGE 7 DgPT 5100,0000 SFLb 2 SP -48 3321) GR 94~ RMOB -999:2500 DRHO -999 ~PHI -999.2500 PEF -999, ~SS -999 2500 Oi, S '999. OTb 107:5273 G~ 94. DRHO 0.0518 NRAT 3. ,VCN[, 2341,5000 FCNL b23, DEPT 5000.0000 SFLU 3, SP -53.4570 GR 110. RHOB -999.2500 DRHU -999 ~PHI -999.2500 PEF -999 ~SS -999 2500 OLS -999 DTL 101:0273 GR 110 OR,I] 0,033'1 NRAT 3 .~CNL 2643,5000 ~CNL 727 OEPT 4900.0()(.)0 SFLU 2, SP -52,6445 GR 96. RHOB -999,2500 DRHO 999 ~PHI -999.250,3 PEr' :999 QSS -999,2500 Q.[,,S -999, OTb 95,2773 GR 96, DRHO 0,0195 N'RAT :3. +~CNL 2653.5o0o FCNb 831. DEPT 4800 SP -55 RHOB -999 NPHI -999 QS8 -999 OTb !)6 ORHO O, NCNb 2891. OCPT 4700 SP ~21 RHOB -999 NPHI -999 QSS -999 OTb 105 DRHO 0 ~CNL 2~25 0000 SFLU 2 , 7070 GR 103, .2500 DRHO -999, 2500 PEF -999. 2500 OhS -999 2773 GR I03: 0112 NRAT 3, 500() FCNL 822. 0000 SFLB 2451 G R 2500 D R H 0 2500 PEF 2500 aLS G R 02 $ 3 N R AT 500 () F C N lb 2 109 -999 -999 -999 I 710. 1292 4023 2500 2500 25O0 4023 4573 3125 3225 0898 2500 2500 250O 0898 2112 3125 7483 4648 25O0 250O 2500 1.819 3125 8479 1523 2500 2500 2500 1523 2952 3125 4788 b523 .2500 25OO 2500 95 3125 OEPT 4600,0000 SFLU 2,5510 SP -22.6514 GR I00.5898 RHOB -999,2500 DRi,,tO 999,2500 NPHI -999~25o0 P'gF : . 999,2500 QSS -999,2500 Oi~S -999,2500 DTL 107,0273 GR 100,5898 ORMD 0..0317 NRAT ),4.729 SGR NRAT NCNb GR CAhI RNRA SGR NRAT NCNb GR CALl RNRA Ibg SGR NRAT NCNL GR CAb! RNRA SGR NRAT MCNL GR CAbI RNRA IbM SGR NRAT NCNL GR CAL.,I RMRA IbM SG.R NRAT NCNb RNRA 2,1584 -999.2500 -999.2500 -999.2500 81,4023 11.3145 3.7561 3.3655 -999.2500 -999.2500 -999.2500 106,7773 11,2832 3.b331 2.9709 -999.2500 :999i2500 999 2500 96 5898 10,2832 3.1897 2 8401 -999 2500 -999 2500 -99g 250O 91 4648 10 5566 3 5159 2,~252 ~999. 500 '999.2500 '999,2500 99.1523 11,1270 3,4,I43 5 tt O .3 -99~ 25OO -999 250o -999 2500 89 2148 12 205I 3.67~0 CALl RNRA O~ RHOB NPHI CAbI RMRA FCNb DT RHO6 NPHI ibD CAbI RNRA FCNb NPHI CALl RNRA FCNh OT NPHI !Lb CAbI RNRA FCNL D T NPHi LiD A b I RNRA FCNB OT RHOB P H I 2 1428 -999:2500 -999.2500 -999.2500 105,7773 2.392~ ~8.B184 3.3323 -999.2500 '999.2500 -999.2500 100.2773 2,3948 34,3262 2,9202 999,2500 :999,2500 999,2500 94,0273 2,3889 34,"I168 2,8010 -999,2.500 -999,2500 -999.250O 87,1523 2.3694 ~6.3770 2 6975 -999 2500 -999 2500 -999 2500 105 0273 2 3635 35 6934 2 5'784 -999 2500 -999 2500 -999 2500 105 7773 2 3323 38 6719 ~VP OlO.H02 VERIFICATI[lr< LISTING PAGE RHOb -999,2500 NPHI -999. 2500 PEF QSS -999.2500 OhS DTL 110.5273 GR ORHO 0.0078 NRAT NCNb 2~55.5000 FCNb OEPT 4400.0000 SFbU SP -29.1514 GR RHOB -999.2500 ORHO NPH! -999,2500 PEF OS8 -999 2500 OL, S DTL 113:2773 GR ,)RHO 0 0566 i, RAT tqCN[, 2079:5000 FCNL OEPT 4~00 o000 SFLO SP -31:4014 (jR RHOB -_999 2500 DRHO MPHI -999~2500 PEF QSS -999 2500 ~LS OTb 110~5273 GR ORHO 0 0254 NRAT NCNb 2253.5000 FC. Nb DEPT SP NPHI USS OTb ORMU NCNb OEPT SP RHOB OTb MCNb OEPT SP RHOB NPHI OTb ORHO NCNb 4200 0000 -31 5889 -999 2500 -999 2500 -999 2500 108 0273 0 0674 2349.5000 llO~ O00O -3 9258 999 2500 -999 2500 -999 2500 11~ 5273 1328 282'7 5000 400~ 0000 -,3 9258 -999 2500 -999 2500 -999 2500 106 7773 0 0435 2263 5000 SFbU GR DRHO PEF NRAT FCNL SFL. U GR DRHO PBF NbS NRAT FCNL S F L U G R O ~ H 0 P GR NRAT FCNb 2 105i -999 -999. -999. 105. 3. 622. 2. 98. '999 . -999. -999. 98. 3 547~ 2. 106 -999 -999 -999 2 9o -999 -999 -999 90 3 599 2 88 -999 -999 -999 2 95 -999 -999 -999 95 3 649 4045 2773 2500 2500 2500 2773 5120 3!25 1643 0898 2500 2500 2500 0898 7190 8125 9670 9023 25OO 2500 2500 9023 5725 3125 9163 4648 ~500 25OO 2500 4648 4944 3125 7678 398 ]500 2500 25O0 .]398 909 8125 9749 2773 2500 2500 ,2 5 o 0 2773 27 IBM NRAT NCNb GR CAbI RNRA ibm SGR NRAT NC~L GR CAbI RMRA IL, M SGR NRAT NCNb GR C ALI R~qRA IbM SGR NRAT NCNb GR AbI N~A SGR NRAT NCNb GR CAbI RNRA N R A T NCNb GR CAbI RNRA 2.519~ -999.2500 99.250~ 92.9648 11.3770 3.6233 2.4026 -999.2500 -999 2500 -999:2500 91.77'13 12.0488 3.7952 3.0413 :999,2500 999.2.500 -999 2500 99'7148 10,9785 3.79'71 3 0667 -999 2500 -999 2500 -999 2500 87 5898 11 0332 319t82 3 ~354 -999~ 500 -999 2500 -999 2500 77 9648 -99~ i357{)0o -999 2500 -999 2500 86 4648 11 8613 3 4827 ILl) CALI RNRA FCNb OT RHOB NPHI lbo CALI RNRA FCNL RHOB NPHI CAbi RNRA FCNL DT RHOB NPHI RNRA FCNb OT RHOB NPHi I'bD CAbI RNRA FCNb DT NPHI ILO CAbI RNRA FCNb R ~108 N,P~I 2.5374 -999.2500 -999.2500 -999,2500 109.5273 2.3108 39,7949 2,4.~5~ -999.2500 -999.2500 -999,2500 110.7773 2.3225 4],2617 J.0471 i999,2500 999,2500 999.2500 109.7773 2,3362 41.0645 3 1409 -999 2500 -999 i~O0 -999 00 106 152] 2 3010 39 0484 3 1741 -999 2500 -999 2500 -999 2500 103 5273 2 3713 38 7695 3,2288 -999.2500 -999,2500 -999,2500 108,6523 2,2932 35,8887 .bvP OIO.H02 YERIFTCh'rlO}"I LISTING PAGE 9 OEPT !~PH I aSS O T b ORHO SP R~OB NPH1 OSS OTL ORHO MCNL OEPT DTb ORHO OEPT SP R~IOB NPHI ORHU OEPT RH(]B NPHI OTb D R H [] NCNb SP RHOB NPH I D T L ORMO 3900.0000 SFI.,IJ -37.4258 GR -999.2500 '999,2500 PEF '999.2500 ~05,5273 0.0488 NRAI 2511.500U FCNL 3800 0000 SF'LU -42:4570 -999,2500 -999,2500 PEF -999,2500 117.2773 GR 0 0854 1696:6875 FCNL 700,0000 SFLL1 ~41.8945 GR 999.251)o DRHO -999,2500 PEF 999,2500 OL8 115,5273 GR T 0,0483 NRA 785.6~75 FCNb 3600 0000 -38 1758 -999 2500 -999 250O -999 2500 121 02'73 0 0703 1598~6875 500,0000 -41,61.33 999,2500 -999,2500 -999.2500 152"1,6875 3400 O00o -65 7227 2 2131 44 5801 0 ~176 1.22 ,273 -999,2500 '999,2500 SFLU GR OMHO PEF GR NRAT FCNL SFLU DR MD GRAT FCNL $ F L U GR DRHO GR NRAT FCNL 2 982'1 83:1523 .-999,2500 -999 2500 -999:2500 83.1523 3.1213 771.3125 3.1272 89.7773 2999 2500 999:2500 -999..2500 89,7773 3,8967 401.6406 2.9807 88 7773 -999 500 -999'2'500 88,7773 4.1804 388.3906 1 5811 86 0898 -999 2500 -999 2500 -999 2500 8~.0898 4,2234 352.,3906 1292 6 4648 -999 2500 -999 2500 · -999 2500 50 394,3906 3,9534 75'2148 0 0044 3:0510 -999. o0 '999,2500 '999,2500 ILM SGR NCNb GR CAL, I IhM SGR NRAT NCNb G~ CALl MRAT ChbI RNR~ I SGR NRAT NCNb GR CALl ~NRA SGR NRAT N CN b GR CA~I RNRA ibm SGR NRAT NCNb GR CAbI RNRA 3.7190 -999'2500 :999.2500 999,2500 87.7773 9.0488 3.2542 3.2913 -999.2500 -999.2500 -999.2500 85.5898 15,2441 4.2234 2.9026 -999 2500 '999i2500 -999 2500 88 7773 16,2236 4.5945 2,0471 -999.2500 -999 2500 -999 2500 86 0898 18 0830 4 5359 2 6096 -999 250O -999 250O -999 2500 69 4648 4 028t 102 27'13 3 7932 1864 6875 75 2148 -999 250O -999.2500 ILD CALl RNRA FC,~ b DT R :'iDB NPH i ILD CALl RNRA FCNL OT RHOB NPHI CAhI RNRA FCNh D? 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PT R H O [! O?,h ORHO NCNb DEPT SP RHOB NPHi DTL ORHO 010,H()2 VERIFiCaTION 2700 0000 SFLU '47: 89,%5 GR 2 2327 DibHO 46:8'750 PEF 0.0137 ODS 132 5525 GR -999:2500 NRAT -999.2500 FCNL 2600 OO00 SFLU -52~6758 GR 2 0667 DRHO 44' 1406 PEF 0~O127 QL$ 130,8125 GR 25oo '-999:2500 FCNL 2500 0000 -50 4570 1 9539 48 0816 -0 0029 141,3125 -99g,2500 -999,2500 SFLU DRHO O G~ N R AT FCNb 2400,0000 SFbU -64,0977 GR . PEF 0 0034 9hS 150,5625 GR '999,2500 NRAT -999.2500 FCNh 2300 0000 -60 3945 2 0413 44 2383 0 0088 129 ~1.25 -999 500 -999 2500 220~ 0000 -5 42.58 2 0042 47 9980 0 0122 133 0625 -999 2500 -999 2500 S F L U GR DRHO PEF OhS GR N R A T FCNL FbU DRHO PEF GR NRAT FCNL LISTING 8 70 0 2 -0 999 999 999 6O 6O 0 2 -0 -999 .-999 999 .0645 .9648 .0122 .9924 .0278 .250O 25O0 :2500 3867 7930 0034 1663 0151 2500 2500 '2500 . 13, 61. -0 -0 -999 -999 -999, 20 40'. -0 2 -0 -999 -999 -999 20 41 -0 2 -0 -999 -999 -999 22, 45. 2999. ~99. 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RNRA NRAT NCNb GR CALI RNRA IBM SGR NRAT NCNb GR CALl R i~l R A 8.9629 77.3398 3.9221 1802,6875 70.9648 '999.2500 -999.2500 5~ 8867 62:4805 3,7717 1924,6875 60 7930 -999:2500 -999.2500 12.2363 71.5273 4 0164 1646~6875 61.4805 2soo 999:2500 22.9111 42,1367 1972, 40,7617 -999,2500 '999,250.0 2:1 7549 45 1992 3 7737 .7305 -999 2500 -999 250O .5361 .1367 3.976'8 1863 6875 45:1055 -999.2500 -999.2500 I [, D CALl R!~RA FCN~ DT RHO8 CALl RNRA FCNb Dr RHOB NPHI ILO CAbI RNRA NPHI ILO CALl RNRA FCN[, RHOB N~HI IbD CAbI RNRA FCNb DT R H O B NPH I ILO CA bi RNRA FCNL D T igi~Ob NPHI PAGE 9 7207 12:2520 4,3562 413,6406 132,5625 99:2500 1674,6875 12,2676 4,2351 454 3906 130~5625 -999,2500 -999,2500 13,5957 12 1426 4 1960 392 3906 141 5625 -999 2500 -999 2500 23,5049 li,2598 ',7776 52'2,3125 146,3125 -999.2500 -999,2500 22 1611 10 438 3906 130 3!25 -999 2500 -999 2500 26,2080 1~,0254 ,4812 415,8906 135,~ 1Z5 -999, 500 -999,2500 11 5VP OlO,H02 YE'.RIF]iCATIOr~ LISTING PAGE 12 DEPT 2100 0000 SP -60i3~33 GR RHOB 1 9942 DR~O ~PHI 44,6777 PE~' ~S$ 00029 OTb 135:8125 GR DRHO -999.2500 NRAT NCNb -999,2500 FCNL DEPT 2000 0000 SFLU SP 60' - ,4258 GR RNOB 1,8682 DRHa NPH1 50.7813 PEF ORaL -999,2500 NRAT NCNb -999,2500 FCNL DEPT 1900 RHOB 1. NPHI 48 ass o DTb 135 DRHO -999 NCNb -999 DEPT 1800 ~PHI 37 Q$$ o D?b 134 DRHO -999 ~CNL -999 DEPT 1700 SP -54 ~,PHI 4~ DT[, 132 DRHO -9~9 NCNb -999 DEPT I~00 Sp -53 R.HOB -999 NPHI -999 055 -999 LTL I01 DRHO -999 NCNI., -999 0000 SFLU 4570 GR 9249 OReO 7305 PEF 0400 QL$ 0625 Ga 2500 NRAT 2500 FCNb 0000 SFLU 1602 GR 8906 PEF 25 GR 500 NRA?' 500 FCNL 000 t) S F L U 3052 PEF 0034 0625 GR 250O aRAT 2500 FCNb 0000 6133 GR ~500 2500 2500 5~73 GR ~500 2500 B..Nh 20. 99~ -999. 12, 50, 2, -0 '999i -999 -999, 0 43 0 3 -0 -999 -999 -999 35 47 -0 2 -999 -999 -999 27. -999 -999 -999 21, -999, -999, -999, -999, -999, '999, 25~9 3242 0!27 6487 0161 250O 2500 25O0 9473 5742 0239 3752 0122 2500 2500 2500 3799 4492 0181 .0159 0293 ,2500 2500 2500 3867 867 015 049 10 ,2500 2500 .0205 3867 0176 02 ~2500 2500 ,25O0 ~ 125 680 2.500 · .2500 25OO 2500 .2500 2500 SGR NRAT NCNb GR CAbI IbM SGR NRAT GR CALl RNRA 5GR N RAT GR CAb! R ~iR a IbM SGR NRA T aCNL, GR CALl R~RA I L M 8GR NRAT C A [~ I RNRA SGR NRAT NCN:L GR CALl' RNRA 20.9,t24 55 ~367 3.7971 1919,6875 50.3242 -999.2500 -999,2500 16 1611 56!2617 4 I335 1807 6875 50.5742 -999.250o -999,2500 25.3799 49,0055 4,0710 1515,6875 43,4492 -999,2500 -999'2500 39 5742 52 5430 3 4514 1644 6875 47 1861 -999 50o -999 2500 28.1924 168$:68v5 . 60,3867 999,2500 '999.2500 46 8555 -999 2500 -99~ 2500 -99 2500 36 -999 25 ~ -999 2500 CAbI RdRA FCNL DT RHOB NPHI ILO CALl RNRA FCNb O~ RHOB NPHI CAbI FCNb RHOB NPHI CAbI RNRA FCNL OT IbD CAbI RNRA FCNL OT RHOB NPHI I bO CADI RNRA FCNb DT R }-IDB NPHI 22 4893 12:1035 4,0828 470,1406 135,8125 '999,2500 '999,2500 19,8330 12,2285 4,1453 435,8906 -999,2500 27 4893 14 0410 4 58 8 330 6406 136 5625 -999 2500 -999 2500 44,9805 13,0566 3 5510 462 8906 135 ~§25 m999 500 -999 2500 30 56'14 1] 4082 ,9612 · 425 ~906 126 -999 ~7300 -999 2500 83 8398 -999 1500 -999 500 -999 2500 100 2773 -999 2500 -999 .2500 bVP OlO.H02 VERIFIC~TI.O['~ [,I$']'I~G PAGE: OEPT ~500!O000SFLU SP ~52 8945 GR RHOB 999 25(;0 DRHO NPHI -999 2500 SSS -999125110 9TL 79 5273 GR DRHO -999 2500 NCNb -999,2500 FCNh OEPT 1400.0000 SELU ,. DTL 118 7773 g~ DRHO -999 2500 NRAT N'CNL -999.2500 FCNL DEPT 1300 sP -53 RHDB -999 NPHI -999 USS -999 OTL 115 DRHO -999 NCNL -999 DEPT 1200 SP -4.8 RHOB -999 NPHI -999 ~S$ -999 DTL 99 DRHD -999 NCNL -999 OEPT 1100 SP -57 RHOB -999 NPHI -999 ~$S -999 DTb 100 DRHD -999 NCNL -999 DEPT 10.00 SP 52 RHOB -999 NPHI -999 (}SS -999 DTb 96 D R a 0 ,,, 999 NCNI~ -999 0000 SFLU 6758 GR 2500 ORHO 2500 PEF 25O0 OLS 7773 GR 2500 NR~T 2500 FCNL 0000 SF'LU 2070 2500 DRHO 2500 PEF 500 273 GR 00 NRAT ~ 00 ~CNL 0000 SFLU 6'158 GR 2500 ORHO ,2500 PEF 2500 QLS 0273 2500 ~RAT 2500 FCNL 0000 SFLU 6758 GR 2500 DRHO 2500 PEF 2500 OL$ 5273 GR 2500 NRAT 2500 FCNL 1720.6875 31,3486 -999 2500 -999~2500 -999.2500 -999,2500 -999.2500 -999.2500 56,2930 32.5117 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 32:~242 61 680 -999 i500 -999i 500 -999 500 -999.2500 -999,2500 -999.2500 76 2148 47 7305 -999 2500 -999 .2500 -999 '2500 -999 2500 -999 2500 -999 2500 105 0898 50 8242 -999 250O -999 .2500 -999 2~00 -999 2500 -999 2500 -999 2500 109.~898 50, 055 '999,2500 '9~9.2500 '999 2500 '999'2 , 500 '999,2500 '999.2500 SGR [( RAT NCNb GR CALl RN RA I LM SGR NRAT GR CabI RNRA Ib~ SGR NRAT ~CNL GR CAbI RNRA IbM SGR NRAT ~CNL GR CALl RNRA MGR. mRAT ~CNb GR ChbI RNRA SGR NR. 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JM LENGTH : FILE TYPE : .qEXT FILE ~tA~E : ,001 1024 ** TAPE TRAILER SERVICE NAM~i :EDIT DATE ~85/12/ 5 ORIGIN 0986 IL~q 6992 SGR 2500 NRAT 2500 NCNL 25OO Gm 2500 C~hI 2500 Rr~RA 2500 3906 IbM 3018 8GR 2500 NRAT 2500 NCNb 2500 GR 2500 CALI 2500 RNRA 250O 5884 IL~ 8799 5GR 2500 NRAT 2500 MCNL 2500 GR 2500 CAb.I 25(,)0 RNRA 2500 5825 IbM '8486 SGR 2500 NRAT ,~500 NCNL 500 GR '2500 CALI , 2500 RNRA '2500 . 14.61.91 -999,25OO =999.2500 -999,2500 40.6992 -999 2500 -999:2500 70.4648 -999 2500 -999 2500 -999 2~00 23 3018 -999 2500 -999.2500 I 8790 -999 2500 -999 2500 -999 2500 22 8799 -999 2500 -999 2500 1 9854 -999 250O -999 25OO -999 ~500 20 486 -999 2500 -999 2500 CAGI RNRA FCNh OT RHOB ,NPHI ILO CAbI RNRA ~'CNL RHO.~ NPHI IbD CAbI RNRA FCNL DT RHOB NPHI CAbI RNRA FCNb DT RHOB N~HI 24.4268 -999.2500 999 2500 93.0273 -999,2500 =999.2500 32~.~906 -999.2500 -999i2500 -999 2500 61,2617 -999.2500 -999,2500 2000 6875 -999 2500 -999 2500 -999 2500 1792 6875 -999 2500 -999 2500 2000 6875 -999 2500 -999 2500 -999 2500 402~ 7~ 2500 -99 -999 2500 hVP 010.H02 VE. 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