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183-052
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, August 20, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Y-09 KUPARUK RIV UNIT 1Y-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/20/2025 1Y-09 50-029-20935-00-00 183-052-0 W SPT 5821 1830520 3000 2550 2555 2555 2555 65 65 65 66 REQVAR P Austin McLeod 7/12/2025 Two year to MAIP. AIO 2B.051. 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 1Y-09 Inspection Date: Tubing OA Packer Depth 1360 3300 3170 3150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250713140349 BBL Pumped:2.8 BBL Returned:2.5 Wednesday, August 20, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 10, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Y-09 KUPARUK RIV UNIT 1Y-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/10/2023 1Y-09 50-029-20935-00-00 183-052-0 W SPT 5821 1830520 3000 2550 2550 2550 2550 60 60 60 60 REQVAR P Austin McLeod 7/5/2023 Two year to MAIP. AIO 2B.051. 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 1Y-09 Inspection Date: Tubing OA Packer Depth 360 3300 3145 3120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230705181633 BBL Pumped:3.8 BBL Returned:3.7 Thursday, August 10, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT IY-09 Insp Num: mitMFH210706135526 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 Y-09 KUPARUK RIV UNIT 1 Y-09 Src: Inspector Reviewed By: P.I. Suprv�� Comm API Well Number 50-029-20935-00-00 Inspector Name: Matt Herrera Permit Number: 183-052-0 Inspection Date: 7/5/2021 , Packer Well 1Y-09 Type Inj w TVD PTD 1 1830520 Type Test SPT Test psi BBL Pumped: 3.3 BBL Returned: Interval' REQVAR 1,P/F Notes: MIT -IA performed to MAIP Per AIO 213.051 Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5821 Tubing 2630 - 2630 2630 2630 ' 3000 IA 855 3400 3270 - 3250 3.1 OA 60 62 62 - 62- P I )- Tuesday, July 13, 2021 Page 1 of 1 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg /��y�q DATE: Wednesday, July 24, 2019 q P.I. Supervisor � �� 1 SUBJECT: Mechanical Integrity Tests (( ConocoPhillips Alaska, Inc. ;PT 1 Y-09 FROM: Matt Herrera KUPARUK RIV UNIT IY-09 Petroleum Inspector 3 4 BBL Returned. 3.3 Ste: Inspector Interval �— _REQVAR Reviewed By: P _— P.I. Supry .J"�� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IY-09 Insp Num: mitMFH190723095035 Rel Insp Num: API Well Number 50-029-20935-00-00 Inspector Name: Man Herrera Permit Number: 183-052-0 Inspection Date: 7/21/2019 Pretest Packer Depth Well — IY-09 . ,Type lnj- -W - TVD 1 sazl T PTD 1830520 -Type Test ;PT Test psi 3000 3150 BBL Pumped: 3 4 BBL Returned. 3.3 65 Interval �— _REQVAR P/F P _— Notes: MIT -IA to MAIP per AIO 2B.051 ✓ Pretest Initial 15 Min 30 Min 45 Min 60 .Min abing 1460 - 2460 2460 2460 -- IA 470 3285 3165 3150 OA 63 65 - { 65 65 - Wednesday, July 24, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 11,2017 TO: Jim Regg P.I.Supervisori, -7('7( 7 SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA,INC. I Y-09 FROM: Brian Bixby KUPARUK RIV UNIT 1Y-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.j92— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-09 API Well Number 50-029-20935-00-00 Inspector Name: Brian Bixby Permit Number: 183-052-0 Inspection Date: 7/6/2017 Insp Num: mitBDB170708102331 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L 1Y-09 Type Inj W • TVD 5821 ' Tubing 2480 2500 2500 - 2500 - PTD 1830520 Type Test SPT Test psi 3000 - IA 670 3280 - 3150 - 3140 BBL Pumped: 3 1BBL Returned: 3.1 ' OA 80 ' 80 - 80 80 Interval REQVAR P/F P ✓ Notes: AIO 2B.051 SCANNED AUG 2 12.017 Tuesday,July 11,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,May 09,2016 Jim Regg P.I.Supervisor Ve470 51041/4, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-09 FROM: Johnnie Hill KUPARUK RIV UNIT IY-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -S-GC..— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-09 API Well Number 50-029-20935-00-00 Inspector Name: Johnnie Hill Permit Number: 183-052-0 Inspection Date: 5/7/2016 Insp Num: mitJWH160508190439 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-09 'Type Inj 1 w' TVD 5821 - Tubing 2440 - 2440 . 2440 - 2440 - PTD 1830520 ,Type Test, SPT(Test psi 3000 - 1 IA 350 3310 - 3185 - 3160 Interval REQVAR LP/F P OA 68 70 70 . 70 _ Notes: Waiver Complance MITIA per AIO 2B.051 to max anticipated injection psi .,, SCANNED SEP 2'7 2016 Monday,May 09,2016 Page 1 of 1 25`lt3 WELL LOG TRANSMITTAL DATA LOGGED 5/5/2O1s M K.BENDER To: Alaska Oil and Gas Conservation Comm. March 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED APR 032015 RE: Leak Detect Log: 1Y-09 AOGCC Run Date: 3/15/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20935-00 SCANNED kik 0 6 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com MALeaotrA54) 6...eAteefie Date: Signed: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg 'if zvjt5 DATE: Wednesday,February 18,2015 �t P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Y-09 FROM: Chuck Scheve KUPARUK RIV UNIT 1Y-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-09 API Well Number 50-029-20935-00-00 Inspector Name: Chuck Scheve Permit Number: 183-052-0 Inspection Date: 2/15/2015 Insp Num: mitCS150215145700 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well l Y-09 Type In j W •TVD i 5821 - Tubing 2325 7 2325 2325 2325 PTD 1830520 IType Testl SPT Test psi'I 3000 - IA 670 t 3280 - 3160 - 3160 _ Interval 1REQVAR P/I-, P ✓ OA 130 138 - 148 158 Notes: Test as required Per AIO 2B 051 ✓ Wednesday,February 18,2015 Page 1 of 1 STATE OF ALASKA - ALA k OIL AND GAS CONSERVATION COM. MON REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther r Install Tubing Alter Casing r Pull Tubing r Stimulate-Frac Waiver Patch r r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 183-052 3.Address: 6 API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-20935-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25646 KRU 1Y-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8052 feet Plugs(measured) none true vertical 6329 feet Junk(measured) 7923 Effective Depth measured 7950 feet Packer(measured) 7354, 7561 true vertical 6252 feet (true vertical) 5821, 5969 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 110 110 . • SURFACE 2350 9.625 2381 2209 PRODUCTION 8008 7 8038 6318 SCAN RECEIVED Perforation depth: Measured depth: 7424-7526, 7540-7544, 7690-7716, 7731-7758 JAN 2 0 2015 True Vertical Depth: 5871-5944, 5954-5957,6062-6081,6092-6112 AOGCC Tubing(size,grade,MD,and TVD) 3.5x2.875,J-55, 7588 MD, 5988 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HB RETRIEVABLE PACKER @ 7354 MD and 5821 TVD PACKER-BAKER D PERMANENT PACKER @ 7561 MD and 5969 TVD NIPPLE-OTIS X NIPPLE @ 1780 MD and 1732 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work. Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXXX_ GSTOR r WINJ j WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 314-658 Contact John Peirce @ 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Wells Engineer Signature / A _ Phone:265-6471 Date 1 /1.911S- /,- i p!1 S // %Wl _ e -� I 1 VTC 1/21//f- RBDMS3 JAN 2 1 2015 Form 10-404 Revised 10/2012 ! �1� Submit Original Only 1Y-09 WELL WORK SUMMARY DATE SUMMARY 11/18/2014 DRIFT TBG WITH 22'x 2.77" DUMMY PATCH DRIFT UNABLE TO PASS 6733' SLM. IN PROGRESS. 11/23/2014 MEASURED BHP @ 7459' RKB. BRUSHED& FLUSHED TBG TO 7450' RKB. DRIFTED TO 7450' RKB W/22'x 2.77" DRIFT. PULLED 25' BAKER KB STRADDLE PATCH FROM 7450' RKB. COMPLETE. 1/15/2015 LRS PUMPED 63 BBL DIESEL, PERFORMED B&F W/3 1/2" BRUSH &2.80"G.RING FROM SURFACE TO BPL NIP @ 7547' RKB, NO RESTRICTIONS. SET PARAGON II PACKER @ 7493' RKB. *JOB IN PROGRESS. 1/16/2015 SET SPACER PIPE (oal 28') INTO LOWER PACKER @ 7493' RKB, SET UPPER PARAGON PACKER W/SPACER PIPE (oal 15')@ 7453' RKB. PATCH OD=2.72", ID=1.61". LENGTH IS 40' SEAL TO SEAL; COVERS LEAKS @ 7461' RKB &7484' RKB. RAN PACKER TEST TOOL TO UPPER PACKER @ 7453' RKB, LRS PERFORMED MIT-T TO 2500#: PASSED. *JOB COMPLETE, READY FOR PWI. s • KUP INJ 1Y-09 ConocoPhillips Well Attributes Max Angle& TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Inol(°) MD(RKB) Act Btm I(tKB) cnrna;Rrakln 500292093500 KUPARUK RIVER UNIT INJ 48.93 6,800.00 8,052.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1Y-09,1/18/20157.31.05AM SSSV:NIPPLE Last WO: 10/15/1992 35.01 4/26/1983 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,729.0 9/22/2014 Rev Reason:SET PATCH hipshkl 1/18/2015 HANGER,195 CE:=1 I Casing Strings Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.9 110.0 110.0 65.00 H-40 WELDED Casing Description ;OD(in) -ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 30.9 2,380.7 2,208.7 40.00 J-55 BTC ,,,,,",,,auauu,,,,""•must________"" urs.Casing Description OD(in) ID(in) Top(RKB) Set Depth IRKS) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.4 8,037.5 6,317.8 26.00 J-55 ETC Tubing Strings Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 3.5"x2.875" 3 12 2.992 19.5 7,587.7 5,988.3 9.30 J-55 ABM-EUE .,,/r_,,.,., Completion Details , CONDUCTOR,30.9-110.0 r• Nominal ID Top(RKB) Top(TVD)(RKB) Top Incl(°) Item Des Com (in) 19.5 19.5 0.06 HANGER FMC GEN IV 5M TUBING HANGER 3.500 NIPPLE.l.760.0 {El 1,780.0' 1,732.4 32.33 NIPPLE OTIS X NIPPLE 2.813 7,304.0 5,785.5 45.16 NIPPLE OTIS X NIPPLE 2.813 7,340.5 5,811.4 44.84 PBR BAKER 80-40 PBR w/10'STROKE 3.000 Y 7,354.3 5,821.1 44.71 PACKER BAKER HB RETRIEVABLE PACKER 3.000 IIL 7,546.9 5,959.0 44.06 NIPPLE AVA BPL PORTED NIPPLE 2.75" 2.750 SURFACE;30.9-2,380.7 7,557.8 5,966.8 44.02 XO Reducing CROSSOVER 3.5 x 2.875"(ID 2.441",6.541,J-55,EUErd 2.875 7,558.2 5,967.1 44.02 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.437 GAS LIFT;7,289.6 7,561.0 5,969.1 44.01 PACKER BAKER D PERMANENT PACKER 3.250 3.250 7,564.6 5,971.7 43.99 SBE SEAL BORE EXTENSION 7,577.5 5,981.0 43.94 NIPPLE CAMCO D NIPPLE NO GO 2.250 2.437 NIPPLE;7,301.0 7,587.1 5,987.9 43.90 SOS BAKER SHEAR OUT SUB.ELMD TTL @ 7590'during IPROF on 2/6/2006 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl PBR;7040.5 Top(RKB) (RKB) (°) Des Com Run Date ID(in) 7,453.0 5,891.7 44.27 PATCH 3-1/2"PARAGON II PATCH(OAL=40').COVERS 1/16/2015 1.610 PACKER;7,354.3 LEAKS @ 7461'AND 7484'RKB 7,546.9 5,959.0 44.06 SLEEVE-C AVA;BPI SLEEVE-CLOSED 6/13/2001 6/13/2001 2.310 7,923.0 6,232.9 42.18 FISH GeoVann SOS Original Completion Tbg release not 5/11/1983 0.000 Shear;Cut-off 8 12'feet below D Nipple INJECTION;7,398.1 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotsM - Top(RKB) Btm(RKB) (RKB) (RKB) Zone Date t) Type Com 7,424.0 7,526.0 5,870.9 5,944.0 C-4,C-3,C-2, 5/11/1983 12.0 IPERF 5"Atlas Guns;120 deg. PATCH;7,453.0 ❑ - C-1,1Y-09 Ph I IPERF;7,424.67,526.01 U 7,540.0 7,544.0 5,954.0 5,956.9 UNIT B,1Y- 5/11/1983 12.0 IPERF 5"Atlas Guns;120 deg. 09 Ph 7,690.0 7,716.0 6,062.2 6,081.1 A-4,1Y-09 5/11/1983 12.0 IPERF 5"Atlas Guns;120 deg. Ph 7,731.0 7,748.0 6,092.0 6,104.3 A-3,1Y-09 5/11/1983 12.0 IPERF 5"Atlas Guns;120 deg. IPERF;7,540.0-7,5440- Ph - 7,748.0 7,758.0 6,104.3 6,111.6 A-3,1Y-09 5/11/1983 4.0 IPERF 5"Atlas Guns;120 deg. Ph NIPPLE;7,546.9 _A 9 SLEEVE-0;7,5461 - - Mandrel Inserts st a6 on Top(TVD) Valve Latch Fort Size TRO Run N Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SEAL ASSY;7,558.2 - '( 7,289.6 5,775.4 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/3/1998 11- 2 7,398.1 5,852.4 CAMCO MMG 1 1/2 INJ DMY RK 0.000 0.0 7/15/2009 Notes:General&Safety PACKER;7,561.0 End Date Annotation SBE;7,564.6 ,r 825/2010 NOTE:WAIVERED WELL OA x FORMATION COMMUNICATION 10252010 'NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;7,577.5 I SOS;7,567.1 IPERF;7,690.0.7,716.0 IPERF;7,731.67,748.0 IPERF;7,746.0-7,756.0 FISH;7,923.0 PRODUCTION;29.3.8.037.5 age Project Well History File~llver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ~0--~- 05~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: Logs of vadous kinds NOTES: [] Other BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Scanning Preparation _~ x 30 = ~ ~ + BY: BEVERLY BREN VINCENT SHERY~ LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: cou.T MATC.ES .U""BE.,. SC^..,.G PREPARAT,O.: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINC~ARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) TOTAL PAGES NO NO RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General. Notes or Comments about this file: Quality Checked (done) • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 .CEDE October 26, 2011 NOV 0 2 O1 Ataaka nil & Gas Cons. Commission Commissioner Dan Seamount Anchor Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, }. fita/t/Q/7 Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 1A,1B,1C,1D, 1E & 11( PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date _ inhibitor sealant date - _ ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 210" N/A 210" N/A 6 10/16/2011 WSW -03 50029208170000 _ 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 • 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C-174 50029231400000 2030270 7' _ 1.00 8" _ 09/11 /2011 14.8 10/15/2011 - 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11 /2011 , 15.2 10/16/2011 1D-08 50029220266000 1770530 52" 1.20 6" 5/28/2011 3.8 10/15/2011 1D-12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D -41 50029232880000 2051880 16" N/A 16" N/A 3.55 10/15/2011 1 D -123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 10/15/2011 1E-11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 . 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 2:05 PM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 -- message 3 Here is the latest addition to the email trail. kTs---?›-Ps c� 20. 2A -03 - AA 2B.050 issued 6/9/2010. 19. 1Y -10 -AA 2B.041 issued 03/11/2009. Well last injected 01/10.51 INN 4 0 2 Q1� 18. 1Y-09 - AA 2B.051 issued 05/20/2010. 17. 1Y-08 - AA 2B.056 issued 10/22/2010. Well last injected 04/07. Are there plans to return the well to operation? 16. 1Y -05 - AA 2B.0015 originally issued 09/12/06, revised 10/21/08. 2 year RST required (condition 3). Original RST 09/01/08, next RST 07/13/10; report "automatically" submitted by Halliburton. Since the RST is a requirement of the AA, the report should be submitted by Problem Wells. 15. 1Y -04 - Last injected 07/09. 7/5/09 email stated intention to keep on injection for diagnostics and possibly apply for AA. Apparently diagnostic results were inadequate for AA. 14. 1Q-11 - AA 2B.058 issued 11/02/2010. I need to review condition 3 of AA for revision. rom: Maunder, Thomas E (DOA) - • t: Tuesday, January 04, 2011 10:53 AM To: Well Integrity Proj Cc: 'NSK •blem Well Supv' Subject: RE. onocoPhillips Monthly Injector Report - Dec 2010 All, I am continuing to revie e December Monthly Injector report. I am thr•.gh a total of 13 wells. I wanted to send this latest message d _ to what I have found or not found on 10 .2B. As I continue to work through the report, I plan to send interim m- ages as I get 7 -10 new wells r- sewed. Call or message with any question . 13. 1Q-02B - Well name is 1Q-02B. Well I.. inje -d 9/10. I do not show having received any specific notification /request in June, 2010 regarding ti'. well. There is an email in the file from 4/20/10 reporting diagnostics accomplished to that time contai g a s : ement that you intend to return the well to injection and remove it from the waiver report in May. 12. 1 L -05 - AA 2B.054 issued 10 /2010. Well last injecte. ' 10 11. 1 L -03A - Well name is -03A. Permit to Drill # is 199 -037. MI failed 09/25/2010. Well last injected 9/10. 10. 1G-01 - AA :.035 issued 7/30/2008. 9. 1F-16A Well name is 1F-16A. IA DD failed 4/12/2007, but MITs are listed to hav- gassed since. Well last injecte. = 2007. AA 2B.018 was issued in October 2007, but no injection has occurred into e well. Looking at the . -ssure plot, it is shown that the IA pressure appears to have been bled off in October an. ovember. Was 1/4/2011 • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [ mailto :n1617 ©conocophillips.com] `V`).— D- Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 CeII 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 • • ConocoPh i l l i ps Well 1Y-09 Injection Data • Tbg Psi • IA Psi • OA Psi 4000 3500 - 3000 - . 2500 - a a 2000 "ti...a".. .0.40••••••••• 1500 � ..''• • 1000 Ne•••• • • « 4 0,.. ti ■ 500 ■ • • %/FA • • • 0 " -- 09/10 10/10 11/10 12/10 01/11 Date PTD:183 -052 AIO 2B.051 issued 05/20/2010 Reason: Surface Casing Leak 12/15/2009 MITIA passed on 05/20/10 Gyro log performed on 03/17/10 AIO 2B.051 requires any pressure bleeds to be reported monthly. No pressure bleeds have occurred in the past month • • ConocoPhillips Well 1Y-09 Injection Data • Water Injection • Gas Injection I 4000 3500 3000 .2 2500 7) a 2000 t • A 1500 • • • • ••A • • IA 1000 i • • 500 • 0 0 500 1000 1500 2000 2500 3000 3500 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected Pressure (mscfpd) (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 2209 85 78 30- Dec -10 0 0 2182 84 67 29- Dec -10 0 0 2143 84 64 28- Dec -10 0 0 2156 84 71 27- Dec -10 0 0 2116 84 71 26- Dec -10 0 0 2147 84 79 25- Dec -10 0 0 2120 84 79 24- Dec -10 0 0 2118 84 80 23- Dec -10 0 0 2153 85 80 22- Dec -10 0 0 2194 86 80 21- Dec -10 0 0 2167 87 80 20- Dec -10 0 0 2124 89 82 19- Dec -10 0 0 2126 93 84 18- Dec -10 0 0 2095 102 89 17- Dec -10 0 0 2131 327 103 16- Dec -10 1543 0 1921 539 110 15- Dec -10 3185 0 1991 607 112 14- Dec -10 3185 0 2000 519 110 13- Dec -10 3186 0 2032 469 110 12- Dec -10 3185 0 2030 628 113 11- Dec -10 3186 0 2016 588 111 10- Dec -10 3185 0 1993 509 109 9- Dec -10 3185 0 1995 522 110 8- Dec -10 3186 0 2014 569 112 7- Dec -10 3186 0 2005 559 111 6- Dec -10 3186 0 1998 635 111 5- Dec -10 3185 0 2031 653 111 • • 4- Dec -10 3186 0 2030 851 114 3- Dec -10 3186 0 2035 494 111 2- Dec -10 2540 0 1698 223 106 1- Dec -10 1347 0 1104 177 107 30- Nov -10 1341 0 1100 184 106 29- Nov -10 1331 0 1081 174 105 28- Nov -10 1328 0 1065 178 106 27- Nov -10 1337 0 1064 195 107 26- Nov -10 1381 0 1076 206 107 25- Nov -10 1387 0 1073 239 62 24- Nov -10 1373 0 1065 223 13 23- Nov -10 1289 0 1035 219 13 22- Nov -10 1333 0 1044 190 13 21- Nov -10 1354 0 1050 214 13 20- Nov -10 1373 0 1051 175 13 19- Nov -10 1329 0 1034 181 13 18- Nov -10 1397 0 1062 190 13 17- Nov -10 1383 0 1064 208 13 16- Nov -10 1474 0 1090 251 13 15- Nov -10 1457 0 1083 244 13 14- Nov -10 1459 0 1065 260 105 13- Nov -10 1433 0 1055 278 105 12- Nov -10 1453 0 1053 275 13 11- Nov -10 1401 0 1029 303 13 10- Nov -10 1443 0 1032 266 13 9- Nov -10 1375 0 999 241 12 8- Nov -10 1373 0 991 194 12 7- Nov -10 1394 0 986 180 12 6- Nov -10 1547 0 1055 219 12 5- Nov -10 1602 0 1065 218 12 4- Nov -10 1567 0 1049 187 12 3- Nov -10 1613 0 1055 216 12 2- Nov -10 1522 0 1021 556 13 1- Nov -10 1418 0 966 752 13 31- Oct -10 1415 0 961 836 13 30- Oct -10 1553 0 1007 823 12 29- Oct -10 3185 0 1551 278 9 1 28- Oct -10 1661 0 1083 336 11 27- Oct -10 2668 0 1408 254 11 26- Oct -10 2528 0 1362 500 12 25- Oct -10 2628 0 1382 1600 12 24- Oct -10 2304 0 1306 1566 11 23- Oct -10 2181 0 1267 1566 11 22- Oct -10 2252 0 1275 1619 11 21- Oct -10 2416 0 1294 1375 11 20- Oct -10 1706 0 1122 1424 11 19- Oct -10 1687 0 1108 1390 11 18- Oct -10 1668 0 1104 1387 11 17- Oct -10 1701 0 1107 1410 10 16- Oct -10 1692 0 1100 936 9 15- Oct -10 1718 0 1104 876 9 14- Oct -10 1813 0 1128 824 8 • • 13- Oct -10 1883 0 1131 760 8 12- Oct -10 1530 0 1021 903 9 11- Oct -10 1681 0 1067 1373 10 10- Oct -10 1796 0 1104 1626 11 9- Oct -10 1913 0 1135 1652 11 8- Oct -10 1936 0 1133 1594 11 7- Oct -10 1942 0 1114 1584 10 6- Oct -10 1881 0 1083 1485 10 5- Oct -10 1829 0 1039 1272 9 4- Oct -10 1700 0 965 826 4 3- Oct -10 1187 0 718 1096 7 2- Oct -10 0 0 263 411 0 • • Page 1 of 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] ~ ~~ ~~ Sent: Saturday, June 05, 2010 8:19 AM ~ (~t To: Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: KRU Pre AA MIT's Attachments: KRU 2A-03 05-27-10.x1s; KRU 1Y-09 05-20-10.x1s Tom, Attached please find MIT forms for Pre AA MIT's on 1Y-09 (PTD183-052) and 2A-03 (PTD 184-051). AA request will follow in a separate email followed by hard copy. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 '" ~ pa lOiG 6/15/2010 t Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ConocoPhillips Kuparuk River Unit - 1 Y 05/27/10 Colee - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Y-09 ~ Type Inj. N ~ TVD '5,821' Tubing 225 240 240 240 Interval O P.T.D. 1830520 Type test P Test psi 1500 Casing 100 X3,000 3,000 .3,000 P/F P Notes: Diagnostic MIT prior to applying for AA OA 50 150 150 150 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water 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 O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1Y-09 05-20-10.x1s • • ADMINISTRATIVE APPROVAL AIO 2B.051 Ms. M.J. Loveland Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 RE: Request for Administrative Approval KRU 1Y-09 (PTD 183-052) Kuparuk River Oil Pool Dear Ms. Loveland: .~ '~[i^~ 1F ~ 4, '' ai1~ In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Well diagnostics confirm the well has a surface casing leak at a depth of about 192 feet. CPAI does not propose to repair the well at this time however intends to continue to evaluate possible repair/remediation possibilities. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 1 Y-09 exhibits at least two competent barriers - tubing/packer and production casing - to the release of well pressure. As part of the diagnostic testing, the well passed the standard inner annulus pressure test. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 1Y-09 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall limit the inner annulus pressure to 2000 psi and the outer annulus pressure as low as practicable; AIO 2B.051 • • June 9, 2010 Page 2 of 2 4. CPAI shall perform a mechanical integrity test of the inner annulus every 2 years to the maximum anticipated injection pressure; 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is May 20, 2010. DONE at Anchorage, Alaska and dated June 9, 2010. The Alaska Dil Daniel T. Sea ount, Jr. . N 1 Commissioner, Chair Commissioner Conservatio TION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default afrer which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Commissioner ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 5, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ~ RECEIVED JUiv 0 ~ 2010 Alaska Oil & Cap Cen -. Commission Ancher3ge ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 1Y-09 (PTD 183-052) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or Perry Klein at 659-7043, or Brent Rogers /Martin Walters at 659-7224. Sincerely, ~z~ -~ MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk We111Y-09 (PTD# 183-052) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with a known surface casing leak for Kuparuk injection well 1Y-09. Well History and Status Kuparuk River Unit we111Y-09 (PTD# 183-052) was drilled and completed in 1983 as a producer and converted to a service well in March 1989. 1Y-09 was reported to the Commission on 12/15/09 with a suspected subsidence related surface casing leak. Diagnostics were conducted which verified the surface casing to formation leak to is approximately 192' below the surface (conductor shoe is at 110' RKB). A passing MITIA was conducted on 05/20/10. Considering that the leak is too deep to access via excavation, the well will require a workover or an alternate repair technology to remediate. ConocoPhillips requests an AA to continue water only injection until the well can be repaired. Barrier and Hazard Evaluation Tubing: The 3-1/2" 9.3# J-55 tubing has integrity to the packer @ 7354' MD based upon a passing MITIA to 3000 psi on 05/20/10. Production casing: The 7" 26# K-55 production casing has integrity to the Packer @ 7354' MD based upon a passing MITIA to 3000 psi on 05/20/10. The production casing is set at 8037' and has an internal yield rating of 4980 psi. Surface casing: The well is completed with 9-5/8" 36# K-55 surface casing in the upper portion of the hole with an internal yield pressure rating of 3520 psi. The surface casing is set at 2381' MD and was arctic packed in 1983. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including ashut-in of the well. T/IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Well Integrity Supervisor 6/3/2010 • • Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every 2 years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum). 3. IA pressure not to exceed 2000 psi (40% internal yield). , 4. OA pressure will be maintained as low as hydrostatic pressure allows. 5. Submit monthly reports of daily tubing & IA pressures, injection volumes, and any pressure bleeds on any annuli. 6. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification Well Integrity Supervisor 6/3/2010 2 ~'~ ~ KUP ~ 1Y-09 C~V~r IIIIIp S I Attributes An le & MO TD A7~75kd Ill! :: Wallbore AP IIUWI Field hams Well Status Inc! (') MD (RKB) Act Btm (ft KB) . 500292093500 KUPARUK RIVER UNI T INJECTING 48.93 6,800.00 8,052 .0 C omment M23 (pPm) Dab Annotation End Dale KB-G rtl (ft) RIB Raleasa Dab ~'~ SSSV: NIPPLE 0 1/1/2009 Lasl WO: 10/15/1992 35.01 426/19!13 w.n c.n6 ~ ty-09 arzl Scnematw ~ A noos 3 oz os Pm duei Annotallon Daplh (ftKB) End Dats Annotation Laat Mod By End Data _ L ast Tag: SLM 7, 918.0 218/2009 Rev Reason. add 7TL comments ni894 7Ii512009 Casin Strin s ------ - Strlna OD S[ring ID Sat Depth Sat Dspitl (TVD) String Wt Slrlna Caalna Da acrlpllan (In) (In) Top (RKB) (ftk B) (ftKB) (Iba/f1) Grade String Top Thrd coNOUCroR. llo CONDUCTOR 16 15.062 0.0 110.0 110.0 65.00 H-40 SURFACE 9518 8.697 0.0 2,381.0 2,208.9 40.00 K-55 PRODUCTION 7 6.151 0.0 8,037.0 6,317.4 26.00 K-55 NIPPLE. 1.760 Tubin Strin s Slrlna OD String ID Set Depth Sal Oeplh (TVD) Siring Wt String Tubing Deacrlpllon (In) pn) Top (ftKB) (ftKB) (ftKB) (Ibs/R) Grade glring Top Thrd suRFACE. ].361 TUBING 3 112 2.992 0.0 7.360.0 5,825.3 9.30 J-55 ABM-EUE TUBING 312 2.992 7,360.0 7,558.0 5,967.0 9.30 L-80 A8M-EUE GAS LIFT TUBING 2 7/8 2.441 7,558.0 7,588.0 5,988.6 6.50 J-55 EUE BRD . 7 t90 Other In Hole A ll Jewel :Tubin Run 81 Retrievable Fish etc. roP D.Pih (TVD) Top Inc! Top (RKB) (ftKB) (') Osecrlptlon Commanl Run Dab ID (In) 1 780 732 4 1 32 30 NIPPLE Otis'X' NIPPLE (INJ VLV PULLED 10.31.1996) 10115/1992 2.813 NIPPEE. 7,3D+ , , . . 7.290 5,775.7 45.29 GAS LIFT GAMCO/MMG-2/1.5/OMY/RK//I Comment: STA 1 9/3/1998 2.859 7,304 5,785.5 45.16 NIPPLE Otis'X'NIPPLE 8/1517998 2.813 7,341 5,811.6 44.83 PBR Baker'80-00'w/10'Stroke 10115/1992 3.000 7 354 5 821 1 71 44 PACKER Baker'HB' RETRIEVABLE PACKER 10/1511992 3,1700 PBR 7311 , , . . 7,398 5,652.3 44.32 1NJECTION CAMCOlMMG/1.5/DMYIRK/I/Comment: STA2 7/152009 2.859 7,453 5,891.8 44.44 PATCH BAKER 35 KB PATCH OAL=35'-TUBING HOLE Q 7465' 4/132009 1.830 7,547 5,959.1 44.06 NIPPLE AVA BPL PORTED NIPPLE 2.75' 8114/1998 2.750 PACKER r.35+ 7,547 5,959.1 44.06 SLEEVE-C AVA; 8P1 SLEEVE -CLOSED 6/13/2001 6/132001 2.310 7,558 5,967.0 44.02 PBR Baker GBH-22 PBR 10/15/1992 2.406 7,561 5.969.2 44.01 PACKER Baker'D'PERMANENT PACKER 10/15/1992 3.250 7,578 5,981.4 43.94 NIPPLE Camco'D'Nipple NO GO. 8/1417998 2.250 7,587 5,987.9 43.90 SOS Baker 10/1511992 2.441 IN3ECnoN, 7 588 5 988 6 43 90 TTL ELMD TTL @ 7590' during IPROF on 2/612006 10/15/1992 2.441 1 398 , , . . 7,923 6,232.9 42.18 FISH GeoVann SOS Odginal Completion Tbg release not Shear; 5 /1 111 9 8 3 Cul-0fl 8 12'teet Delow D Nipple Perfora tions 8 Slots Shoff Top (TVD) Btm (TVD) Dana PAtCH, 7,053 Top (RKB) Blm (ftKB) (RKB) (RKB) Zone Data (ah- Type Comment IPERF. 7,424 7,526 5,871.2 5.944.0 C -0, C-3, C-2, 5/11/1983 12.0 IPERF 5' Atlas Guns; 120 tleg. Ph 7.+t+-7626 C -1, 1Y-09 7,540 7,544 5,954.1 5,957.0 U NIT B, 1Y-09 5/1111983 12.0 IPERF 5' Atlas Guns; 120 deg. Ph 7,690 7,716 6,062.2 6,081.1 A -4, i V-09 5!11/1983 12.0 IPERF 5" Atlas Guns; 120 deg. Ph 7,731 7,748 6,092.0 6,104.4 A -3, 1Y-09 5111/1983 12.0 IPERF 5' Atlas Guns; 120 deg. Ph IPERF, 7sa.7,s++ 7,748 7,750 6,104.4 8,111.7 A -3, 1Y-09 5/1117983 4.0 IPERF 5' Atlas Guns; 120 deg. Ph NIPPLE.? 511 SLEEVE C. 1517 PBN, 7,55tl PACKER, 7.581 NIPPLE, 7.578 SOS, 1.581 Tn 7ses ~ IPERF, 690-7.716 IPERF, 7,731-7,118 IPERF, 1.1/6-7.756 FISH, ] 923 « PRODUCTION, 8.031 TO. 8.852 Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ConocoPhillips Kuparuk River Unit - 1Y 05/27/10 Colee - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Y-09 Type Inj. N TVD 5,821' Tubing 225 240 240 240 Interval O P.T.D. 1830520 Type test P Test psi 1500 Casing 100 3,000 3,000 3,000 P/F P Notes: Diagnostic MIT prior to applying for AA OA 50 150 150 150 Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water 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 O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1Y-09 05-20-10.x1s • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, December 15, 2009 2:51 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Kovar, Mark Subject: KRU 1Y -09 (PTD# 183 -052) Report Of Surface Casing Leak Attachments: 1Y -09 Wellbore Schematic.pdf; 1Y -09 TIO Plot.pdf Jim/Tom /Guy, Kuparuk WAG injector 1Y -09 (PTD# 183 -052) is suspected of having a surface casing leak based upon results of a survey using an echometer and OA gas injection. Additional troubleshooting will begin as soon as feasibly possible. The well will be shut in and placed on the monthly report. Attached is a wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 0 JAlki CP 2" Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/4/2011 Well Name 1 Y -09 Notes: End Date 1/1/2010 Days 120 Start Date 9/3/2009 Annular Communication Surveillance 3000 — __. �_ _ �. -- 160 WHP IAP OAP 140 2500 — WHT 120 2000 IP - 100 LL Q 1500 - - 80 ' - 60 1000 - - - – 40 500 – 20 • 0 0 Sep -09 Oct -09 Nov -09 Dec - 3500 - • •DGI 3000 2500 �PWI E. 2000 .• SWI e 1500 ••••BLPD 1000 Y 500 Sep -09 Oct -09 Nov -09 Dec -09 Date WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 3, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1Y-09 Run Date: 9/30/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y -09 Digital Data in LAS folmat, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 20935 -00 Injection Profile Log ANNE; NO tf 2 7 2009 1 Color Log 50- 029 20935 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. US it3 —C6 oQ Anchorage, Alaska 99518 t 9 a S Office: 907 273 -3527 Fax: 907-273-3535 rafael.barreto@halliburton.com NOV 706 Date: Signed: ~ ~ MEMORANDUM TO: Jim Regg r--~ P.I.Supervisor ~~p,~ '1(a,~~V~ "~ l FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 30, 2009 SUBJECT: Mechanical Integriry Tests CONOCOPHILLIPS ALASKA INC 1 Y-09 KUPARiJK RIV UNIT 1Y-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L 5uprv ~y~,~g:~- Comm Well Name: KUPARiJK RN LTNIT 1Y-09 API Well Number: 50-029-20935-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG09o703121133 Permit Number: 183-052-0 / Inspection Date: ~/3/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Y-09 ,Type Inj. ~'~' T~ 5gz~ ~ j.~ 410 2500 2370 2360 P.T.Di ~83oszo TypeTest SPT i Test psi zsoo ~ OA as ~ 6s 6s 6s Interval a~TST p~ P ~ Tubing »oo - i ~69o i~oo i~oo ~ Notes: 2.9 bbl's pumped, good four year test. - ~~~ ~ ~~~- P,~~~vw~ 1~~ Fs; ,a " •~ ~ = e f ~jt~~rG' . ~ ... ,~ / :: ._ „.Rx:t ~~,.a, __ •tf~ Thursday, July 30, 2009 Page 1 of 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~D~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Install patch _ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 183-052 / - 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20935-00- 7. KB Elevation (ft): - 9. Well Name and Number: RKB 96' 1Y-09 ' 8. Property Designation: 10. Field/Pool(s): ADL 25646 - Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8052'. feet true vertical 6328'- feet Plugs (measured) Effective Depth measured 7950' .feet Junk (measured) 7923' true vertical 6252' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 2351' 9-5/8" 2381' 2209' PRODUCTION 8007' 7" 8037' 6317' Pertoration depth: Measured depth: 7424'-7526', 7540'-7544', 7690'-7716', 7731'-7758' ~~ ®p~, ~•/ (~ true vertical depth: 5871'-5944', 5954'-5957, 6062'-6081', 6092'-6112' ~~y Tubing (size, grade, and measured depth) 3.5" & 2-7/8", J-55 & L-80, 7360', 7588' MD r~j~~j~8 ~j~ ~ ~8S COfIS ~ P k & SSSV h t & d d ' ' ' ' ' , ® Anch,~ra a mmissian ' ac ers ( measure ) ype ept Baker HB permanent pkr @ 7354 retrievable pkr, Baker D , 7561 Otis 'X' nipple @ 1780' 12. Stimulation or cement squeeze summary: I r,~ ,,~{' ~ _..A , ~1! (9~ ~, ~ (f '}y Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na 2211 -- Subsequent to operation na 2151 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ " Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 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: 309-045 Contact John Peirce @ 26 5-6471 Printed Name John Peirce "~ Title 6471 Ph 265 ' Wells Engineer t Date ~'' ~~'-~ Signature / Z + _ one: - 2 ~ 'f -~.. ~--- Pre aced b h n Allsu Drake 263-4612 __ , ., - ~ ~ ~~~ p~ ~ goo Form 10-404 Revised 04/200 Submit Original Only ConocoPhilGps aiiitiw..A jrX:. ... _._._..._-- _._ 411. _ ~.._9 4,(22!$Q 110 NIPPLE, 1,780- -- SURFACE, 2,381 GAS LIFT, ].290 NIPPLE, 7.306 PBR, 7.301 PACKER. 7,356 INJECTION, 7.398 PATCH, 7.653 - IPERF, ~ ].626-],526 __ _ IPERF, - 7,510-7,546 NIPPLE, 7,547 - SLEEVE~C,_~ __. 7,547 PBR 7 558 - , . PACKER, 7,561 NIPPLE, 7,578 SOS. 1,587 -- TT 7 568 L, , IPERF, r+ 7,690-],716 IPERF, 7,768-],758 FISH, 7,923 -- PRODUCTION, _ 8,03] \ TD. 8,052 KUP 1 Y-09 e APVUWI ~Fieltl Name N 32093500 '~,KUPARUK RIVER UNIT It nt K2S (Pwnl'Date NIPPLE 0 II 1/1/2009 .Ion (Depth (ftKB) Entl Date (Annotation IMaz Angle & MD !TD lus ~ Prad/Inj Type Inc! (°) MD (ftKB) Act Bim (ftKB) ING ~~PWI 48.93 6,800.00 'I 8,052.0 notation,End Data 'KB-Grtl (N) (Rig Release Dat st WO: 70/15/1992 35.01 4!26/1983 27/81.. 24411 7,558.--..-7,588.0( 5988.61 6.SO~J-55 IEUE 8RD -_~ 7,341 1 Description Comment Run Date ID (in( '.30 NIPPLE ~ Otis'X' NIPPLE (INJ VLV PULLED 10.31.1996) 10/15/1992 2-813 ~.29. I GAS LIFT CAMCO/MMG-2/1.5/DMY/RK/// Comment STA 1 9/317998 2.859 i.16l NIPPLE _ Otis'X'NIPPLE _ 8!15/1998 2.813 ~.83~ PBR Baker'80-40'w/10'Stroke 70/15/1992 3.000 ~.71 PACKER Baker'HB' RETRIEVABLE PACKER 10/15/1992 3.000 ~.32 INJECTION CAMCOlMMG/1.5/DMY/RK/// Comment: CLOSED STA 2 10/15/1992 2.859 7,558 5967.0 ~i 44021 PBR Vcy i Baker GBH 22 PBR yLVJCV V'I,ILyy1 10/15/1992 12.406 7,561 S 969.2 ~ 44.01 ( PACKER Baker'D' PERMANENT PACKER 10/15/1992 13.250' 7,578 5,981.4 ~ 43.94 NIPPLE Camco'D'Nipple NO GO. - - 8/14/1998 12.250' 7,587 5,987.9.( 43.90 SOS Baker 1 0/1 511 9 9 2 i 2.441 7,588 5,988.6 43.90 TTL i -- _ -- -- 10/15/1992 2.441 7,923 6,232.9 ~~ 42.18 FISH GeoVann SOS Original Completion Tbg release not Shear; 5/1111983 Cut-off 8 112' feet below D Nipple Perfora tions & -- Slots (snot _.. - _.__.__ _.. _ I, ToP (TVDI Btm (TVD) Dens Top (ftKB) I Btrn (flK6) (ftKB) (ftKB) Zone Dale (sh... Type Comment 7,424 7,526 5,871.2 5,944.0 C-0, C-3, C-2, 5/11/1983 12.0 IPERF 5" Atlas Guns; 120 deg. Ph C-1, 1Y-09 ~ 0 09 6 7,690 7,7 6I 6 062.2 6,087. 1 iA-0 1 -09 5111/7983 12.0 IPERF 5"Atlas Guns; 120 deg. Ph 1Y-09 Well Work Summary DATE SUMMARY 2/8/09 TAGGED @ 7918' SLM, EST. 1ATHOLE. LOGGED CALIPER SURVE~ FROM 7600' SLM TO SURFACE. READY FOR E/L LDL. 4/10/09 BRUSH & FLUSH TBG FROM SURFACE TO 7500' SLM. CONCENTRATING ON AREA FROM 7400' TO 7500' SLM. DRIFT TBG WITH 26' X 2.78" DMY PATCH TO 7500' SLM.'`*''NO TIGHT AREAS ENCOUNTERED***. 4/13/09 SET BAKER 35 "KB" STRADDLE PATCH FROM 7453'-7473' COVERING TUBING HOLE AT 7465'. 4!14/09 TEST UPPER STRADDLE PACKER @ 7453' ELM TO 1500 PSI. HELD SOLID FOR 15 MINUTES, JOB COMPLETE. 4/24/09 PULLED DV @ 7398' RKB. SET HFCV WITH 1/4" PORT @ 7398' RKB. COMPLETE. • • ProActive Diagnostic Servi.Ces, Znc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) G59-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTl`) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road .~:,.~N~~~ ? ~ ~~ ~; ~~~~ Suite C Anchorage, AK 99518 Fax. (907) 2458952 '1~er Report 08-Feb~09 1 Y-09 1 Report / EpE 50-029-20935-t)0 ~ 2] Caliper Report 07-Feb~09 1 C}03 1 Report / E~ 50-029-2040_8-0/0 v1 ~ ~~3 - oSa ~ l~s~ i -~ -. -~ ° ~ E. ~. ~, Signed : Date ..~_,,. Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8981 FAX: (807)245-88952 E-MAIL : I~~s~~a~Pa®r~U~(~Jm~rr~©~t~~g.corra WEBSITE : wwrra.~r;~a~j~Ifl~ n? C~1Documenls and Settings\Owner\Desktop\Trancxnit_Conoco.docx e•'7 • • o d a ~ o SARAH PALIN, GOVERNOR ~-7IfiA OII, AI1TD GAS 333 W. 7th AVENUE, SUITE 100 COI~TSL'`RQA'I`IO1~T COMl~'IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Group Engineer ~~ ~~_~.,h ~,.~ +~ a ~ ... ~ ;, . - ConocoPhillips Alaska, Inc ~ ~ u.- PO Box 100360 Anchorage AK 99510 ,~ ~ ~ ~J ~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1Y-09 Sundry Number: 309-045 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered tamely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, T v Daniel T. Seamount, Jr. Chair DATED this ~ day of February, 2009 Encl. ~i~ STATE OF ALASKA r 6~ ALASKA OIL AND GAS CONSERVATION COMMISSI N a ~~~ ~b APPLICATION FOR SUNDRY APPRO A ~ ~~~~ a` A~s~C)1 ~ a 20 AAC 25.280 s Cofrs. Co-lunission 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ ~«~ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Install patch . Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 183-052 3. Address: Stratigraphic ^ Service O 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20935-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS ^ NO ~ 1Y-09 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25646 RKB 96' ~ Kuparuk River Field /Kuparuk River Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8052' ~ 6328' 7950' 6252' 7923' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 110' 110' SURFACE 2351' 9-5/8" 2381' 2209' PRODUCTION 8007' 7" 8037' 6317' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7424'-7526', 7540'-7544', 7690'-7716', 7731'-7758' 5871'-5944', 5954'-5957', 6062'-6081', 6092'-6112' 3.5" & 2-7/8" J-55, L-80' 7558', 7588' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'HB' retrievable pkr, Baker'D' permanent pkr @ 7354', 7561' Otis 'X' nipple @ 1780' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work; Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat February 18, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Group Engineer Signature ~f'~ Phone 265-6471 Date ,~ - L~ -~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ v Pl I P T M i T i ^ ~~ ~~~5'`~~ ntegrity ^ BO ug est ^ echanical Integr ty est ^ Locat on Clearance ~~~ Other: ~g~ Subsequent Form Required: ~~ APPROVED BY ~/ )~ Approved by: COMMISSIONER THE COMMISSION I Date: r Form 10-4(evisei~~06/200bF t 's t'~~ Submit in Duplicate ~o~ ~b ~- • s.a9 ~„~ a o r; ~ ~ ~ ~~ • • 1Y-09 Proposed Tubing Patch Installation A 2/6/06 IPROF indicated that 85% of total produced water injection was entering the C sand through a tubing leak at 7461' RKB. This leak will be isolated with a 20' retrievable tubing patch to halt all injection to the C sand and to achieve `A sand only' injection. Procedure: Slickline Brush & flush the 3.5" tubing at 7435 - 7485' RKB in the area where the tubing patch is to be set. 2. Run a Caliper log from the tubing tail to surface. 1Y-09 has 17 yr old 3.5" tubing. Tubing condition will be verified OK for a tubing patch before making a final decision to run the patch or not. E-line Install a 20' OAL Retrievable Tubing Patch: 3. RIH with a retrievable straddle packer for tubing patch. Set the lower tubing patch straddle packer in the 3.5" tubing at 7471' RKB. Slickline 4. RIH with run #2 assembly to complete a tubing patch consisting of ~20' of spacer pipe and an upper straddle packer. Sting into the lower straddle packer set at 7471' RKB, then set the upper straddle packer at 7451' RKB to complete the tubing patch at 7451 - 7471' RKB (seal to seal). RIH with test tool and set the test tool in the top packer to pressure test. PT the tubing to verify packer set integrity. Pull test tool. Return 1Y-09 to injection and obtain a valid injection rate. Note: A down hole choke may be set in GLM #2 at 7290' RKB following the patch job should it be determined that a controlled PWI rate to the C sand is needed in the future. JWP 2/4/2009 `~-~ KUP ~ 1Y-09 Well Attributes Max An le & MD . TD Conc~~Ph~ilips ~ '~ __ __ s ~`tiµ Wel^DOrre APIIUWI F'bN n cn WeII Status (Prod/Inj Typa Incle(°)' MD (kKeBl nn Act Btrn (ftK8) ' Sling OD ~ String ID I Casing Description (in) (in) (CONDUCTOR ~ 1611 15.062 F Top (ftK8) 0.0 Set Dapth (ftK8) 110.0 Set Depth (ND) ~~ String Wt String (ftK8) (Ibslft) Gratle $irir~TOp Thrtl 110.0 ~ 65.OOH-00 IS CE 95/8j 8697 0.0 2,381.0 2,208.9 40.00 K-55 P RODUC110N 711 6.151 0.0 8,0370 6,31 Z41 26.OO~K-55 Tubing Strings ' String OD I String ID Sat Depth Set Depth (ND) String Wt String ~~ Tubing Descri ption (In) (in) Top (ftK8) (ftK8) (ftK8) (Ibs/ft) Grade ~ SVing TO Thld TUBING 31/2 2992 00 7,360.0 5825.3 9.30 J-55 '.ABM-EUE TUBING 31/2 2.992 7,3600 7,558.0 5,9670 9.30~L-80 ABM-EUE TUBING ~ 2 //A 2.441 7,558.0 7,588.0 5,988.61 6.501)-55 '(EUE 8RD Other In Hole All Jewel : Tubin Run Sr Retrievable Fish etc. Top Depth ', (TVD) Top Inc! Top (ftK8) (ftK8) (°) Description Comment Run Date SID (in) 1,780.0 1,7324 32.30 NIPPLE Otis'X' NIPPLE 10/15/1992 I~ 2.813 7,290.0 5,775.7 45.29 GAS LIFT CAMCO/MMG-2/1.5/DMY/RK!// Comment: STA 1 9/3/1998 ' 2.859 7,304.0 5,785.5 45.161 I NIPPLE Otis'X'NIPPLE I 8115/1998 2.813 7,341.0 5,811.8. 44.83 PBR Baker'80-00' w/ 10' Stroke 10/15/1992 ~ 3.000 7,354.0 5,821.1'1 44.71 PACKER ~18aker'HB' RETRIEVABLE PACKER 10/15/1992 3.000 7,398.0 5,852.3) 44.32 INJECTION CAMCO/MMG/1.5/DMY/RK/!l ComrrlenL CLOSED STA 2 10/15/1992 2.859 7,547.0 5,959.1 44.06 NIPPLE ~AVA BPL PORTED NIPPLE 2.75" 8/14/1998 2.750 7,547.0 5,959.1 44.06 SLEEVE-C JAVA; BPI SLEEVE -CLOSED 6!1312001 6/13/2001 2.310 7,558.0 5,967.0 44.02 PBR Baker GBH-22 PBR 10/15/1992 2.406 7,561.0 5,9692 44.01 PACKER 18aker'D' PERMANENT PACKER 10/15/1992 3250 7,578.0 5,981.41 43.90 NIPPLE ICamco'D' Nipple NO GO. 8/14/1998 2.250 7.587.0 5,987.91 43.90~ SOS Baker - 10!1511992 1 2.441 7,588.0 5,988.6 43.90 TTL ~' 10/15!1992 2.4411, I 7,923.0 6,232 9 42.18 FISH GeoVann SOS Original Completion Tbg release not Shear; 5/11/1983 Cut-off 8 1/2' feet below D Nipple • Memory Multi-Finger Caliper Log Results summary Company: Conocophillips Alaska, Inc. WeN: 1Y-09 Log Date: February 8, 2009 Fiekf: Kuparuk Log No.: 7299 State: Alaska Run No.: 1 AP1 No.: 50-029-20935-00 Pipet Desc.: 3.5° 9.3 Ib. J-55 ABM-EUE / L-80 ABM-EUE Top Log lrrtvl: Surface Pipet Use: Tubing Bot. Log Intvl: 7,563 Ft. (MD) Pipet Desc.: 2.875" 6.5 lb. J-55 EUE-8RD Top Log tntvl: 7,553 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl: 7,588 Ft. (MD) Inspection Type : Corrosive b Mechanical Damage lnspection COMMENTS This caliper data is tied into the end of the tubing tall at 7588' (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate a hole in joint 236 (7,465'). A 3-D log plot of the caliper recordings across this hole is included in this report. The remainder of the 3.5" tubing appears to be in good condition with respect to internal corrosive and mechanical damage, with no other significant wall penetrations, areas ofcross-sectional wall loss or 1. D. restrictions recorded. The caliper recordings indicate slight buckling from 4,180' to 7,500'. MAXIMUM RECORDED WALL PENETRATIONS Hole! (100%) Jt. 236 t~ 7,465' (MD) No other significant wall penetrations (> 7%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 6%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. ~~~d~~~~ ~~~ fx ~ ~QV Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. (P.O. Box 1369, Stafford, TX 77497 Phone; {281} or {888) 565-9085 Fax: {281) 565-1369 E-mail: PDS~memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 v= C ~ 4s3 -~~ ~~~s'9 ~ • • PDS Multifinger Caliper 3D Log Plot _ . ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1Y-09 Date : February 8, 2009 Description : Detail of Caliper Recordings Across Hole (7,465) in 3.5" Tubing o° so° ~ so° 2~0• o° -~, ~I • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (9.3' - 7563.1') Well: 1 Y-09 Pipe 2 2.875 in (7563.1' - 7588.0') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 8, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehole Profil e 25 778 50 1556 75 2340 100 3121 L ~ 125 3907 ~ z .~ ~ ~ a- o p 150 4689 175 5464 200 6251 225 7038 GLM 1 IN) 2 238.9 7588 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degrees) Bottom of Survey = 238.9 • I ~, ~" r Well: 1Y-09 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA PDS Report Overview Body Region Analysis Survey Date: February 8, 2009 Tool Type: UW MFC 24 No. 218183 Tool Size: 1.69 No. of Fngers: 24 Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & thread Nom.ID Nom. Upset Upper ten. Lower (en. 3.5 ins 9.3 ppf L-80 ABM-FUE 2 992_ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (%wall) ~ penetration body ,~ metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 250 pene. loss 11 238 0 123 127 0 0 0 1 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hde Number of'oints dama ed total = 1 0 0 0 0 1 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n (-:1 AA 1 Inj. # 2 Bottom of Survey = 238.9 Analysis Overview page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1Y-09 Kuparuk ConocoF'hillips Alaska, Inc. USA February 8, 2009 Joint No. Jt. Depth (Ft.) I'cn. Upset Ilns.) Pen. Body (Ins.) I'en. %~ ~Ic~t,~l I ass "~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 9 O 0.02 7 I 2.94 PUP 0 12 (? 0.02 G (? 2.90 1.1 44 t J 0.00 1 1 2.90 P U 1.2 5 ti 0.00 1 n 3 PUP 58 U 0.01 5 I 2. 9 3 (? .01 4 86 4 120 U 0.01 i i 2.91 5 152 U 0.01 5 +? 2.91 6 18 O .01 ~ .90 7 5 ? 0.01 4 .90 8 (? 0.01 5 2.89 9 277 ~ 0.02 G u 2.90 10 08 0 0.01 4 .92 11 40 0 0.01 6 2.9 12 370 t1 0.01 5 I 2.9 13 2 l1 .01 ~ 2.89 14 433 l) 0.01 6 i 2.90 15 46 U .00 1 1 2.92 1 96 (? 0. 1 5 2.92 17 5 7 (? .01 5 I 2. 2 18 559 (? 0.01 4 .91 19 590 l) 0.01 5 2.88 t e osi 21 U 0.01 5 1 2.91 21 652 U 0.02 ~ 1 2.90 (~ .0 5 > 90 23 715 (? 0.01 5 ? 2.91 4 7 6 U 0.01 b ~ .91 25 778 U 0.01 5 1 2.90 26 U 0.01 V ' 2.91 2 7 841 U 0.01 4 2.92 28 872 U 0.02 6 1 2.89 29 904 U 0.01 2 ; 2.91 30 935 U 0.01 2 1 2.90 31 967 (? 0.01 6 I 2.91 996 U 0.01 i 2.92 33 1026 a 0.01 (, _' 2.93 3 105 (? 0.01 5 I 2.92 35 1087 (1 0.01 ~ 2.92 36 1119 U 0.01 5 2.9 37 1150 0 0.01 2 .' 2.92 3 11 t? .01 4 ' .90 39 1213 U 0.01 5 7 2.91 40 144 U 0 1 4 i 2.92 41 1276 U 0.02 7 l1 2.91 4 1307 (? 0.01 ~ I 2. 43 1337 n 0.01 ? I 2.91 1369 ~,? .O1 ~ .90 4 1400 (? 0.01 6 I 2.90 4 1431 (? 0.01 4 U 2.92 47 1462 !1 0.01 4 1 2.91 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 ABM-EUE Well: 1Y-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 8, 2009 Joint No. Jt. Depth (Ft.) I'c~n. Ul,cr~ (Ins.) Pen. Body (Ins.) Pen. °~ Mc~t,,l I ~,~~ ~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 149 ! > 0.02 .91 49 15 5 t ~ 0.01 5 U 2.91 5 1 56 U 0.0 (~ 1 5 1 8 U 0.02 6 I 2.91 5 618 a 0.01 4 I 2.9 1650 ~! .01 f~ 1 .92 54 1679 ~ ~ 0. 2 E, 2.91 55 1710 l ~ 0. 1 4 I 91 6 174 ~ ~ 0.01 4 .95 5 1 77 (~ 0 t) U N A X Ni e 5 177 l i 0.01 4 1 58 1807 t1 0.01 3 ? 2.9 59 1 38 (~ 0. 1 4 2 95 0 1870 t ~ 0.01 4 ~ ~ .92 61 190 ~ ~ 0.01 2 2.94 1931 U 0.01 4 I 3 6 1962 ~ ~ 0.02 6 2.90 64 1994 l ~ 0.02 i I .9 6 2026 (1 0.02 7 2.90 66 2057 ~~ 0.0 6 1 .8 67 2 u 0.01 6 1 2.9 68 1 0 l1 0.01 4 ' .94 69 2151 t1 0.02 7 3 2.9 70 2183 ll 0.01 2 2.91 4 ~~ 00 4 t 72 2246 ~ ~ 0.01 4 1 2.96 2 7 a 0.01 5 a 2.88 74 2309 ! ~ 0.01 5 1 2.95 75 2340 U 0.00 1 U .90 76 2370 l) 0.01 5 3 2.90 77 2 ~~ 7 4 0 78 2434 ~l 0.01 4 2.90 79 2465 ~~ 0.0 7 2 93 80 2496 U 0.01 2 1 2.90 81 28 ~~ 0.02 ~ 2.9 82 2559 I! 0.01 5 ~' 2.92 83 2 90 U 0.01 4 O 2.91 84 2622 ~) 0.01 4 1 2.90 8 26 U 0 01 5 ~~ 2 91 86 2684 i ~ 0.01 6 2.91 87 716 ~? .02 7 3 .89 88 2747 ~~ 0.01 2 1 2.91 9 2778 ~~ 0.01 6 .93 90 2810 ~ ~ 0.01 4 ' 2.92 1 841 ~) 0.0 5 .89 92 2871 i ~ 0.01 5 _' 2.94 9 29 3 h 0.01 4 _' 2.91 94 2934 i ~ 0.02 7 ? 2.90 9 2966 i ~ 0.01 ~ 2.90 96 2998 i! 0.01 6 I 2.90 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 ABM-EUE Well: 1Y-09 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 8, 2009 Joint No. Jt Depth (Ft.) I'~~n. IJls~~t (Ins.) Pen. Body (Ins.) I'e~n. %, ~k~t,il Ins °4~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 30 t~ 0.01 5 ' 98 3060 t ~ 0.01 U ~ .88 99 3090 t ~ 7 2.87 100 3 21 a 0.01 4 U 2.90 101 3151 a 0.0 ~ ~' 2.8 102 3183 t! .01 4 tt 2.91 103 3214 a 0.01 4 ~ 2.92 104 324 U 0.0 U _' 2.92 105 277 t~ 0.01 (; .91 1 6 3309 t l 0.02 i I 2.91 1 341 t ~ 0.01 4 _' 2.92 108 33 u 0 01 4 a 2.89 109 3403 U 0.01 5 ' 110 343 U 0.01 6 _' 2.90 111 3466 t ~ 0.01 4 ~ 2.90 112 498 t 1 0.01 6 2.90 113 3529 t~ .01 4 2.89 114 3560 (~ 0.0 U 9 11 3592 (~ 0.0 4 .94 116 624 i~ 0.01 2 ' 11 3655 U 0.01 4 .90 118 3 7 n 0.0 7 l) .93 119 3719 U 0.01 6 i 2.91 120 3750 t~ 0.01 4 I 2.91 1 3 8 U .0 90 122 3813 (~ 0.01 4 2.91 2 844 U 0.0 i 2.9 124 3876 t) 0.01 6 I 2.91 12 3907 U 0.01 6 2 126 3938 a 0.02 7 ~ 2.88 1 7 3970 (~ 0. V 2.91 128 3998 (~ 0.01 5 2 2.89 1 9 4029 n .O1 4 ' 2.9 130 4061 t 1 0.02 U 2.91 131 4092 (~ 0.01 6 2.91 132 4123 a 0.02 6 U 2.88 13 41 t~ 0.02 7 t~ .90 li ht Buc in 134 4186 t ~ 0.01 6 1 2.95 135 4 18 U 001 U .91 136 4249 ci 0.01 (i I 2.93 137 4 81 U 0.02 7 1 2 0 138 4312 It 0.01 i 1 2.91 9 4344 (~ 0.01 ~1 I 2. 1 140 4376 (~ 0.01 2 1 2.92 4 4407 t) 0.01 4 .90 142 4439 t ~ 0.02 2.89 14 4470 ~ ~ 0.01 ~ 2.90 Sli ht BucMin . 144 4501 t) 0.01 2 _' 2.90 4532 t~ 0. 5 3 .8 146 4563 n 0.02 7 (~ 2.91 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 ABM-EUE Well: tY-09 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 8, 2009 Joint No. Jt Depth (ft.) I'c~i,. 111 s<~t Ilns.l Pen. Body (Ins.) Pen. %, :~1et.~l I cxs ,,, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 147 4 94 i ~ 0. 4 I 2.9 1 2 n 0.00 1 I 2.9 149 4657 a 0.01 4 I .92 150 4689 c 1 0.01 5 i i 2.91 151 4721 ~ ? 0.02 i _' 2.90 152 4752 a 0. 1 5 I .88 li ht Bu in . 153 4783 a 0.02 1 2.90 1 4814 U 0.01 5 u 3 1 5 4846 t i 0.01 5 U .89 156 4877 O .01 4 1 2 92 1 7 4908 U .O1 6 1 2. 1 158 940 U 0.01 5 I 2.9 5 4972 U 0.01 6 t 1 .92 1 0 5003 U 0 01 5 I 90 161 503 (1 0.01 ? 8 C De s' 162 S064 U 0.01 b 2.91 Sli ht BucMin . 163 5096 U 0.01 5 U 2.90 1 4 51 7 U 0.01 6 I .92 1 5 S 15 U 0. 1 4 .91 166 5189 t ~ 0.02 - 9 1 7 5 0 t t 0.01 (~ a 91 li t Bu i 168 5252 c ~ 0.01 5 2. 0 69 5284 t) .O1 4 _' 2.91 170 5313 t ~ 0.01 5 ll 2.91 7 34 u D 7 ? .8 e i 172 5370 U 0.01 5 2 2.89 Sli ht Bucklin . 173 5402 t ~ 0.01 Z 1 .91 174 5433 U 0.01 6 3 2.91 175 5464 U .01 2 1 2.9 176 5495 t ~ 0.02 ~~ 3 2.90 177 5527 t) 0.0 4 U .91 Sli t B kli 178 5558 t ~ 0.01 6 ? 2.91 179 5 90 U 1 9 180 5621 U 0.01 =1 3 2.93 1 1 5 5 a 001 ' .92 18 5685 t~ 0.01 4 ~ 2.94 Sli ht Bucklin . 183 5716 U 0.01 5 1 184 5748 (~ 0.02 ~ ~ 2.89 185 5779 t i 0.01 5 u 2.91 186 5811 t) 0.02 6 <' 2.91 187 5842 t~ 0.01 ~ ~ 2.90 SI' ht Bu kl' 188 5874 t) 0.01 _' ! ~ 2.91 189 9 3 a 0 0 - .90 190 5935 t~ 0.01 5 u 2.90 19 5 6 U .01 5 .92 192 5997 tt 0.01 5 1 2.93 Sli ht Bucklin . 193 6029 (~ 0.01 2 1 .93 194 6061 i ~ 0.01 5 .93 195 6093 t i 1 4 I 9 196 612 5 +'~ 0.01 5 I .94 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1Y-09 Kuparuk ConocoPhillips Alaska, Inc USA February 8, 2009 Joint No. )t. Depth (Ft.) I't~n. t tl,~c~t (Irn.l Pen. Body (Ins.) Pc~n. % V1c~t,rl I c, ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 7 1 tt 0. 1 5 I 2. 4 (i t cklin . 1 8 61 9 U 0. 1 U 90 19 21 n 0. 1 6 1 1 00 6 51 t t .01 ; 1 .92 1 6 81 a 0.0 6 91 20 6 1 t t 0.0 ' 2.92 203 6343 t t 0.01 -1 I 2.93 SI~ ht Buckli 204 75 tl 0.01 4 I .93 0 6407 t t 00 1 1 .9 06 643 t t 1 I 3 07 6470 t t 0 ' I 2.91 0 6 0 It 0.0 2 1 . 4 li ht Bucklin . 09 6534 t ~ 0.01 i ~, 2.91 10 6565 i r .0 -1 I 2.93 211 6597 u 0 01 4 u 2 94 212 6629 r~ 1 5 ' .92 213 666 a 0. 1 4 I .94 S!i ht B cklin . 1 693 a 0.00 1 1 2.9 215 724 a 01 Z 1 .9 16 6756 U 0. 0 1 1 217 788 l? .0 (~ tt 93 21 68 0 t1 0 0 7 r I 2.91 li ht Bu klin 219 6851 t t 0. 1 ~' I 2.9 220 6882 a 0.01 ~ ,' 2.90 1 912 U 0. 1 ~ 1 222 6943 t t 0.01 4 1 2.90 223 -975 U 01 4 9 .93 Sli t ckli 224 7006 c t 0.01 5 ' 2.89 22 7 tt 0.01 4 1 2.9 226 7069 (1 0.02 6 U 2.91 7 7100 U 0. 1 4 tl 2. 3 228 7132 tt 0.02 7 1 2.91 Sli ht Bucklin . 22 7163 tt 0.01 4 _' 2.91 230 7194 r t 0.01 (~ t t 2.90 231 7225 tt 0. 2 7 .89 232 7256 It 0.01 -1 _' 2.92 Sli ht Buckli 2. 72 7 t) 0 1 ~' t t .91 PUP 23 7294 tt 0 t) U N A GLM 1 Latch ~ 10:30 3 02 l) 0.01 5 I .94 P P 232.4 7308 n 0 u t i 2.81 X Ni le 233 7310 tt 0.01 1 I .95 33.1 7342 tt 0.01 5 I 2.91 PUP 23 7345 t ~ 0 l) U N Ba ker ' ' P R w 0' Str e 233.3 7355 it 0 l) U N A Baker'HB' Retrievable Packer 2 4 7 6 U 0 02 7 1 2. 1 SI~ h c in . 234.1 7397 tt 0.00 I ~' 2.93 PUP 4.2 7404 11 0 11 u N A In'ection M drel # Lac 1 :3 234.3 7411 tl 0.01 3 u 2.92 PUP 5 41 U 0.01 5 I .91 Sli h u ~n . 236 7449 tt 0.42 I t?u (~ 2.90 Hole! _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf J-55 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1Y-09 Kuparuk ConocoPhillips Alaska, Inc USA February 8, 2009 Joint No. Jt. Depth (Ft.) Ne•n. 1lpser Ilns.) Pen. Body (Ins.) Nc•n. °4~ ~k•I,il I ~>,~ ~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 237 7481 t~ 0.0 4 I 2.91 Sli t Buckli 23 7 1 a 0. 1 i I 2.9 38. 7544 tt 0.0 2 I 2.86 PUP 238. 7 51 t ~ 0 c) t ~ 31 Slidin Sle ve 3 7 5 a 0.01 2 2.91 P P 238.4 7 63 U 0 0 U 41 B -22 PBR 38.5 7568 t ~ 0 U t ~ 3.2 Perma ent Packer 38.6 757 U 0.00 1 t) 2.44 PUP 38.7 7579 ~~ 0 U t l D Ni le N 238.8 7582 (~ 0.02 8 1 9 PUP 23 .9 758 u 0 u n N A TT ,Penetration Body Metal Loss Body Page 6 ~ PDS Report Cross Sections Well: lY•09 Survey Date: February 8, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: l4 Tubing: 3.5 ins 9.3 ppf L-80 ABM-EUE Analyst M. Lawrence Cross Section for Joint 236 at depth 7464.53 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 95 Tool deviation = 46 ° Finger 11 Penetration = 0.424 ins Holei 0.42 ins = 100% Wall Penetration HIGH SIDE = UP ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ! ~ i Cross Sections page 1 KUP 1Y-09 ~OI'IOCOP~'11~~Ip5 WeNAtt tYlbare ri6ute s eld a W I Max I Ie6MD TD B AI. r,..,l hi 500292093500 KUPARUK RfVER UNIT INJ PWI 48.93 8,800.00 8,052.0 4b _~. SSSV: WR DP IPPnO 175 7112008 Last WO: 70115!1992 35.01 f9Y elease 426/1983 Last T : RKB 7,928.0 1/1412009 Rev Reason: TAG FILL 1!2212009 i Strin s n MI MI Top W ~ del ~ 1 pncel WeaO p'+~ T lartl coNOUCTOR. CONO OR 1 6 15.062 0.0 1 10.0 110 0 85.00 H-40 tto SURFACE 95/ 8 8.897 0.0 2.381.0 2,208.9 40.00 K ODUC N 6.1 1 0.0 8.037.0 6.317.4 2 .00 3 NIPPLE.,7eo Tubt stri s srero tlt ^ he fvlptlo n M) MI To ptlce) ep Opal dtxBl (6Mq tirade ToP Tfrd UBING 312 2.992 0.0 7,380.0 5,825.3 9.30 J36 AB - UE suRFACE 1.38, TUBING 312 2.992 7,380. 7,568.0 5, .0 .30 L-80 ABNI-EU TUBING 27/ 8 2.441 .0 .0 5,98.6 8. J35 UE BRD SAS ter, Other In Hole All Jewel : Tubhr Run 8 Re trletnrble Fish etc. rzw aP IIVq Top Yta TuP w ~1 ('1 a c ommertl R,n ore o 1, 80.0 1,7 4 32.30 NI lis' NI 0/7611992 2. 1 NIPPLE, ~ as 7,290.0 7 304 0 5,775 785 5 .7 5 45.29 45 1 G N AS U CA /M Otis'K' NIPP 1. !/ C(rrxrtertt: A 1 91311998 8/ 6J7998 2.859 813 2 , . . . . . 7,341. 5.81 .8 44. PB R Belzer' 0' w/ 10' Slydte 10/15) 992 .000 .0 5.821 .1 44.71 PA CKER Baicar'HB' RE T ENABLE P KER 1011 992 3. 7 398.0 852 5 .3 44. IN JECTION CAMCOlNtlAG I1.57D /RK N/Comrtlent CL D STA2 10!1571992 2.859 P~7.7~a, , 7 54 . 9 5 1 44 06 NI PPLE AVA BPL D NIPPLE 2 7 1411 750 2 , . , . . . . 7,547.0 5,959 .1 44.06 SL AVA PI - LOS ED 6/ 32001 &132001 1511992 2.370 06 PACKER, 7 351 ,7 7, 7 0 5,96 5 969 .0 2 44.02 44 01 P P ACK Bales GBH- Belzer D' PER R NE PA C 1 10/15/1992 2.4 3.250 I t , . , . . 7.57 .0 5,981 .4 43. NI PPLE Camco YY Nip ple NO 811 /1 2.250 7,587.0 5, .9 43.90 S Balser 10!15/1992 2.441 7,598.0 sas s 4.90 1 7517 2 .oat 7,923. 6,232 .9 42.14 FI SH Nam SO S - - al g r sze rbt Shear, 6!17!19 IN,ECTION. Cutoff 8 12' feet below D Nipple ].398 Perfora tlons ~ mil eea t~l °°^~ eea Qecli InKB) Zone Dre leh-- eern ntertl IPERF. 7,424.0 7.526.0 5,871.2 5,944. -4. G3, G2, 611 !1983 12.0 IPERF 5' C4trrta; 1 deg. Ph 7424-1,516 C -1, 1Y-09 7,540.0 7, .0 6,954.1 5,957. U Nff B, tY-09 57118983 72.0 IPERF Gus; t deg. Ph .690.0 1 6.0 6,0622 6, 1.1 A te, tY-09 5!11!1883 12.0 1 RF Atlas ; 12 0 deg. IPERF, ] 731 0 7 74 8 0 6 092 0 6 04 4 -3 tY-09 11/1983 12.0 IPE F 5' A Gute; 720 dep. Ph 7.5/0a,s44 , . . . , . , . , 7,748. 7, .0 6,7 A 6,117.7 A , 1Y-09 1117983 1.0 IPERF A Guts; deg. Ph NIPPLE, 7,517 SLEEVE C, 7547 PBR,7$58 t. I PACI(ER. 756, t I NIPPLE. 7,ST8 SOS. 7.567 ~ TTL, 7588 IPCitF, P,B90-1,7,6 IPFRF, 7,131-7,748 a'ERF 7 74B-1,758 FISH, 7.913 eA PRODUCTION. 8.037 7D, s.osz 02/21/06 Schl umberger t\ \,,/' ~\'~ 1$., l ,_n r:í.: 0 (.. \." , ' 1: <- ,~ t'·\~·"!."·(':;..-' r;;;'VIi"\.\' \;', ;¡ \;,;'i NO. 3691 ¡C'·.Ü, j Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 FEB 2 Z 2006 ~...", """i,,), "IJIWIH:,SlOI, ?JlclYJrage Field: Kuparuk Well BL Color CD Job # Log Description Date 1 B-17 ¡q4 - CA5' 11216283 SBHP SURVEY 02/18/06 1 1 E-36 /98-':;r~ 11216282 SBHP SURVEY 02/18106 1 3H-07 /9>7-07'ì 11217023 LDL 02/11/06 1 3H-07 " /, 11166757 STATIC SURVEY 01/20/06 1 2A-09 If 'J/o-(() I 11154126 PRODUCTION PROFILE 02/09/06 1 1A-10 I -lId) 11213710 INJECTION PROFILE 02/08/06 1 2M-14 ¡c, - /J/ n; 11154127 INJECTION PROFILE 02/10/06 1 1 E-05 I fY)- D5r; 11166747 PRODUCTION PROFILE WIDEFT 12/25/05 1 2H-12 IPf5-,:)(¡;" 11154128 PRODUCTION PROFILE WIDEFT 02/11/06 1 1 C-21 11154131 PRODUCTION PROFILE W/DEFT/GHOST 02/14/06 1 3G-18 /q()- /!J5' 11154129 PRODUCTION PROFILE WIDEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 1B4-~'f{p 11166753 PRODUCTION PROFILE 01/14/06 1 1Y-09 183-~ 11213128 INJECTION PROFILE 02/06/06 1 1 E-1 05 11162832 MEMORY INJECTION PROFILE 01/28/06 1 2C-08 IB=?r0Cì5 11141255 INJECTION PROFILE 01/28/06 1 2C-02 /R~- r:R!!J 11213129 INJECTION PROFILE 02/07106 1 1C-25 ¡QQ-C>31 11144074 GLS 02/02/06 1 2C-14 1/34 - nt fO 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 /8-'/-:;) It 11144067 PRODUCTION PROFILE 01/26/06 1 1A-18 /CJo-5 ,~ 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 1~-()8?; 11213709 INJECTION PROFILE 02/07/06 1 1D-32 tlOO-/73 11141252 LEAK DETECTION LOG 01/25106 1 2C-12 /81-tlao 11141260 PRODUCTION PROFILE 02/02/06 1 2C-15 /84 - :)Ó;¡., 11141254 PRODUCTION PROFILE 01/27/06 1 1J-154 N/A PRODUCTION LOG W/TRACTOR 02/05/06 1 1E-104 11217024 INJECTION PROFILE 02/12/06 1 e e Please sign and return one copy of this transmittal to Beth at the above address or fax to'(907) 561-8317. Thank you. ~~ MEMORANDUM TO: Dan seamount~ CommisSioner THRU: Blair Wondzeli .~'~ P.I: Supervisor FROM: John Cds~ Petroleum InspeCtor State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 11, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1Y Pad 01,09 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pre.te. st Initial 15 Min. 30 Min. J "Notes: P:T'D'I 1830500 ITYpeteStl P I Testpsil 1473 I CasingI 660 1160011550115501 P/FI P"I , WellI 1Y-09 P.T.D.I 1830520 Notes: WellI ' P.T.D.I Notes: I Type,,j.J S ~.v.o. I~,~ I Tubi'ng 12550 12550 I 2550 I ~,o J,nte~,a,I 4 Type testIP I Testpsi'I' '1455 ICasi'n'gI 67,5 I ~600 I 1575 I 1575 I P/FIE' I Type,nJ l' ] I I ' II I ITypetestl ' ITestpsil I Casingl ' I I I I P/F ] Notes: ' P.T.D.I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. ; S = SALT WATER INJ. N = NOT INJECTING : No failures witnessed. No problems-encountered. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Intemal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details .I.T.'s performedi .2 Attachments: Number of Failures: g Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (desoribe in notes) Total Time during tests: ,1 hr. CC.' MIT report form 5/12/00 L.G. MIT KRU 1Y 9-11-00jc.xls 9113~00 FROH~ RRCO CPF1 ARCO Alaska, Inc Date; August 28, 1998 FRX N0.: 987 6597749 Subject: From/Location: C. L, Crabtree NSK-06 Fax Correspondence File Code: 88-28-98 04:12P P.O1 KRU Well 1Y-09 Update on Surface Casing Repair Operations on KRU 1Y-09 Telephone: To/Location: 659-7493 Blair Wondzell- AOGCC Telephone: 279-1433 Fax: 276-7542 Blair: Attached is a final summary of actions completed on 1Y,-09 and a point forward plan of action, We will contact the slope inspectors for witnessing a 7" MIT once the well is back on injection. Cliff cc: Farmer/Morris W. Patterson NSK-06 NSK,-06 AUG 28 1998 A~asla 0il & Gas Cms. Commi,~k~ ARCO Alaske Inc. In a subsidia~ of ~,tle. n~ic RiChfield AR,3B.6001 -A FROH~ RRCO CPF1 Page 2 FRX NO.: 987 6597749 88-28-98 04:12P 1Y-09 Surface Casing Repair P .02 History: On the evening of August 12, 1998, a circumference weld in the Kuparuk Injector 1Y-09 surface casing parled. The 7" casing subsequently pushed the wellhead and attached surface piping upward two to three feet. The Drillsite Operator (Harrison Richardson) found the well in this condition during the evening wellhouse inspection. The Drill Site Lead Tech (Ken Powers) was called and the well was shut in. The Drillsite Supervisor (Mike Morris) was notified by Ken Powers. Mike Morris contacted the Troubled Well Supervisor (Mark Chaney) of the GKA central wells group and the Drillsite Engineer (Cliff Crabtree). The site was inspected by these individuals at approximately 22:00 8/12/98. The inspection revealed the surface casing of 1Y-09 had parted, allowing the 7" casing to push the wellhead and attached surface piping upward two to three feet. The wellhead and tree were leaning approximately ten degrees, apparently as a result of lateral stress from the displaced surface lines. The flowline was bent and all associated valves instrumentation etc. were moved from the normal position. It appeared the movement occurred suddenly, as there was damage to the top of the wellhead house from the needle valve & gauge on the tree cap impacting the wireline doors located in the roof, and an abrupt bend in the injection flowline. We hypothesized that had the movement been gradual, the wellhead would have simply lifted lhe shelter and the surface piping off the foundation and/or pipe supports, without inducing the impact or bending damage that is evident. Inspection of the casing and wellhead revealed a welded connection, completed while drilling the well, had failed in tension (as of 8/17/98 the reason for the weld failure is still unknown, further analysis will be done by the AAI corrosion engineering group to determine the root cause). In this well, the 9-5/8" surface casing was placed in tension as a result of the 7" production casing undergoing thermal cycling into compression. The compressive force in the 7" production casing resulted from longitudinal metal expansion induced by a temperature change from ambient at completion, to the higher in-service produced water injection temperature. The compressive force in the 7" casing may have been exacerbated by landing the production casing at less than buoyant string weight. The production casing was stuck off bottom while reciprocating during the primary cement job which required the use of the "emergency" casing slips and packoff instead of the typical mandrel hanger/packoff combination. A review of the drilling files indicated the surface casing weld was the result of a repair effort undertaken during well construction on April 19 & 20, 1983. While drilling ahead at 4100' on the production hole, a 10-3/4" to 9-5/8" pup/casing c~.~.~9/'.~j~i~eJ;z[l~ty separated from the FMC generation II starting head. The 9-5/8" surface 9-5/8" x 10-3/4" pup/casing crossover dropped downhole approximate,, ~.l~8~A_" ,~,T~' ell was drilled during the period when AAI converted from a l o-3/4 to a'~-5/u' ~rr~ce casing design at Kuparuk. The crossover was used to adapt~~u~.~s,~;.~rface casing to the 10-3/4" BTC threads on the available wellhead. Anch0ra~e mrnlss~or~ After setting a bridge plug at 900' MD and nippling down BOPs, it was determined the surface casing had dropped downhole and also that the surface casing cement top had FROM: ARCO CPF1 Page 3 FAX NO.: 907 6597749 08-28-98 04:15P P.05 dropped to 116' MD. The repair required a 10-3/4" casing pup be welded to the pup/casing crossover to establish proper BOP stack height. Following the weld repair of the casing, a cement top job was circulated in through 1" pipe from 116' to surface. With these things complete the BOPs were reset and drilling continued. Repair Sequence: 1. Straighten and shore up the wellhead with guide cables, supports, etc. . RU slickline. Make a gauge run to the D nipple at 7582'. Make a slick tool gauge run to the X nipple at 7308' MD (above the top packer). Make a subsequent gauge run to the AVA nipple at 7551' sleeve if deemed necessa~/. , RIH and pull the ported AVA at 7551'. RIH and set an isolation sleeve in the AVA to isolate the C sand. RIH and set an equalizing plug in the D nipple at 7582' to isolate the A sand. Pressure test the tubing, Following this set a 2.812" equalizing plug in the X nipple at 7308' MD, 4. RIH and pull the '1.5" DV above the top packer at 7294' MD. Circulate the tubing and casing with filtered 10.8 NaBr/NaCI brine (note: freezing point = -18°F). This leaves an underbalance differential of approximately 950 psi across the packer elements since reservoir pressure is estimated at 4300 psi based on a fluid level measurement on 6/18/97 taken after 29 hours S! time. Note: to balance a 4300 psi BHP will require 14+ ppg fluid, we anticipate that slickline work could not be accomplished in fluids of this weight/viscosity. = Vacuum out cellar. Steam clean the wellhead and cellar box area, Plan to sleeve the surface casing to shore up the wellhead. Details of this will be finalized after a "clean" inspection is conducted. Part of the repair could be to circulate hot brine down the tubing and up the casing while conducting the welding operations to keep the pipe in an expanded condition. For this reason the mandrel at 7294' MD will be left open until repair plans are finalized, 6. FMC service technician tested 7 x 10-3/4" packoff to 3000 psi, OK. Tested Tubing 3.5 x 7" packoff on tubing hanger to 5000 psi, OK. Note: Steps 1-6 were complete on or before 8/16/98. 7. After a structural engineering review, we found a split pup joint butt-welded repair was structurally superior to a sleeve repair, We moved ahead with this design. On 8/17/98 we completed measurements and ordered the materials. ]998 oil & Gas Cons. C0mrn/ss 0n FROM:~ ARCO CPF1 Page 4 FAX NO.: 907 6597749 08-28-98 04:13P P .04 . On 8/21/98 we establish fire suppression in 7" x 10-3/4" and 10-3/4" x 16" annulus, Following this we cut off the TANKO divertor head and a section of 16" conductor to provide access to the surface casing separation point. The TANKO head will not be replaced, as its only purpose is to secure the divertor while ddiling the surface hole. . On 8/23/98, we commenced circulating heated brine down the tubing and up the annulus, This was continued for 24 hours to warm the wellbore to a normal operating temperature (approximately 150° F). The 7" casing and 3.5" tubing slowly extended to a "neutral" height after about 9 hours of circulation. We vacuumed the arctic pack off the 7" x 10-3/4" annulus to 6' below the separation point, and established an inert gas fire suppression blanket in 7"x 10-3/4" annulus. 10, On 8/24/98 we installed a split butt-welded casing pup on the surface casing while maintaining the wellbore at the "in service" temperature, Following this, we ceased circulation and cooled the wellbore, On 8/25/98 the welds were inspected and magnafluxed. On 8/26/98 we pressure tested the repaired surface casing x production casing annulus to 1000 psi and visually checked the exterior for leaks. The annulus held pressure without any loss. Note: standard operating practice dictates the production casing x surface casing annulus be maintained at 1000 psi or lower during normal production operations. A 1500 psi pressure test of the 7" production casing confirmed production casing, wellhead and downhole plug integrity. The test showed no pressure loss. Note: Steps 11-13 are forthcoming. The order will depend on equipment availability. 11. Stabilize the surface casing in the cellar by filling the cellar with cement grout. 12. Install height modified surface piping. 13, Circulate diesel into the casing as a packer fluid. Remove isolation plugs and return well to injection, 14. Conduct a state witnessed MIT, STATE OF ALASKA ~ OIL AND ~ CONSERVATION COMMIo,'51ON REPORT OF SUNDRY WELL OPERATIONS , Stimulate Plugging ~ Perforate Pull tubing Alter casing Repair well Other 6. Datum elevation (DF or KB) 1. Operations Performed: Operation Shutdown 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 568' FNL, 1252' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1554' FSL, 1273' FEL, Sec. 2, T11N, R9E, UM At effective depth 1301' FSL, 1532' FEL, Sec. 2, T11N, R9E, UM At total depth 1253' FSL, 1581' FEL~ Sec. 2, T11N, R9E~ UM 12. Present well condition summary Total Depth: measured 8 0 5 2 true vertical 6328 RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-09 9. Permit number/approval number 83-52 10. APl number so-029-20935 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) None feet Effective depth: measured 7 9 5 0 true vertical 6252 feet Junk (measured) 7923' (Tagged 10/13/92) feet Casing Length Size Structural Conductor 7 3' 1 6" Surface 2344' 9 5/8" Intermediate Production 8 0 0 6' 7" Liner Perforation depth: measured 7424'-7526', true vertical 5870'-5943', Cemented Measured depth True vertical depth 251 SX AS II 73' 73' 1000 AS III & 2379' 2209' 250 SX AS I 535 SX Class G 8037' 631 7' 7540'-7544', 5953'-5956', 7690'-7716', 6062'-6080', 7731'-7758' 6091'-6111' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7364', 3.5", 9.3#, L-80 @ 7364'-7562', 2.875, 6.5#, J-55 @ 7562'-7592' Packers and SSSV (type and measured depth) PKR: Baker HB @ 7358' & Baker "D"~ 7565'; SSSV: MACCO Injection Valve .~ 1784' 13. Stimulation or cement squeeze summary R~'CEIVED Converted well from water injection to MWAG injection on 10/10/92. Intervals treated (measured) N/A JUN 2 5 1993 Treatment description including volumes used and final pressure N/A Alaska 0il & ~s L,u~s. ~u,,,n~ss~u,' 14. Representative Daily Average Production or In!ection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Sub-_~9_cluent to operation - 0 - 3800 -0- 1500 3400 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service MWAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE KD~S MORNIN~ WELL REPORT DRILLSITE 1Y PAQE 1 PRODUCTION WELL STATUS ~AS LIFT STATUS S/I IMPACT W Z S E 0 T L N A L E T 7" 10" TP TT WC H2S CSQ CSQ PSI CHK DEQ % PPM PSI PSI SI CN QAS IN`] AH TEMP METER VOLS LI DEQ READINQ MSCF EB C H M 0 R I D EPL S N E BBLS 3 B PR 4 A PR 5 B PR 6 B PR 14 A TS 16 A PR 25 B PR 26 B PR 29 B PR 30 B PR 32 B Pr 188 176 124 50 174 176 69 2 184 176 149 75 193 176 148 90 191 100 87 10 171 176 90 4 187 176 129 62 196 176 143 70 50 1180 850 75 1460 180 50 1310 1220 65 1110 380 50 800 700 40 1640 660 50 1140 600 &5 1300 990 1735 12 96 75. 68 2100 180 211 176 140 78 80 1360 800 217 176 128 80 70 1200 960 82 0 241 0 48 0 662 0 98 0 2289 0 78 0 598 0 64 0 491 0 62 0 428 0 0 0 0 0 62 0 1016 0 0 0 0 0 0 0 0 0 0 0 106 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 TOTALS: 5831 0 IN`]ECTION WELL STATUS IN`]ECTION VOLUME S/I W Z S E O T ALLOW I N A IN,] L E T PSI ACT 7" 10" INd TT CSQ CSQ PSI DEQ CHK PSI PSI INU INd METER VOLS VOLS READINQ BBLS MMSCF C H M 0 R I D S N E 1 B PW 2500 1467 150 12 1480 880 2 B MI 4000 3334 107 100 70 0 7 B MI 4000 3488 107 100 0 120 89~ M.~I _ ~OoO 3377 107 lOP 50 20 MI 4000 3456 106 20 o 0 10 B PW 2500 2188 111 10 400 300 11 B SI 2500 1192 62 0 1350 500 12 B PW 2500 2166 152 176 1760 750 13 B PW 2500 2151 180 100 720 240 15 B PW 2500 2153 147 100 1940 500 0 3296 O. 000 0000 0 0 0 17. 931 0000 0 0 0 4. 629 0000 0 0 0 13. 977 0000 0 0 0 2. 606 0945 3~ 0 5705 0.000 0 0 0.000 0 4865 0.000 0 3716 0.000 0 8029 0.000 0000 0 2400 70 0000 0 0000 0 0000 0 TOTALS: SW I: 0 + PWI: 25611 = 25611 39. 143 RECEIVED JUN 2 5 199;~ Oil & Gas Cons. [.;ommission ~nchorage STATE OF ALASKA ALASKA OIL AND GAS ~ERVATION ~MI,5o~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic Service X 4. Location of well at surface 568' FNL, 1252' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1554' FSL, 1273' FEL, Sec. 2, T11N, R9E, UM At effective depth 1301' FSL, 1532' FEL, Sec. 2, T11N, R9E, UM At total depth 1253' FSL, 1581' FEL, Sec. 2, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 8 0 5 2 true vertical 6328 feet feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-0~ 9. Permit number/approval number 83-52/92-249 10. APl number 50-029-20935 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) NOlle Effective depth: measured 7 9 5 0 true vertical 6252 feet feet Junk (measured) 7923' (Tagged 10/13/92) Casing Length Size Structural Conductor 73' 1 6" Surface 2344' 9 5/8" Intermediate Production 8 0 0 6' 7" Liner Perforation depth: measured 7424'-7526', true vertical 5870'-5943', Cemented 251 SX AS II 1000 AS III & 250 SX AS I 535 SX Class G Measured depth True vertical depth 73' 73' 2379' 2209' 8037' 6317' 7540'-7544', 7690'-7716', 7731'-7758' 5953'-5956', 6062'-6080', 6091'-6111' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7364', 3.5", 9.3#, L-80 @ 7364'-7562', 2.875, 6.5#, J-55 @ 7562'-7592' Packers and SSSV (type and measured depth) PKR: Baker HB @ 7358' & Baker "D" @ 7565'; SSSV: MACCO Injection Valve_@_1784' 13. Stimulation or cement squeeze summary Ran MACCO injection valve on 10/23/92. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A JUN 2 5 1993 Alaska Oil & Gas Cons. ~;ommissio 14. Representative Daily Average Production or In!ection Data Anchorage Oil-8bl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -0- -0- -0- -0- -0- Subsequent to operation -0- -0- 5000 1300 2200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Suspended Service MWAG In!ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~" ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL ~-oq CONTRACTOR REMARKS JPBDT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME Cn~"~ pl~-~ IDAYS DATE CC', 'j- Z_o, I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReportTemp. °F Chill Factor0FJ Visibility miles I Wind Vel. Alaska Oil & uas [;ohs. Corlimissio~ General Purpose Worksheet File = . IPage No. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate __ Plugging __ Pull tubing X Alter casing __ Repair well__ Other Perforate 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 568' FNL, 1252' FWL, SEC 1, T11N, R9E, UM At top of productive interval 1554' FSL, 1273' FEL, SEC 2, T11N, R9E, UM At effective depth 1301' FSL, 1532' FEL, SEC 2, T11N, R9E, UM At total depth 1253' FSL, 1581' FEL, SEC 2, T11N, RgE, UM 12. Present well condition summary Total Depth: measured 8052' true vertical 6328' 5. Type of Well: Development ~ Exploratory _ Stratigraphic Service ~ ~/~ feet Plugs (measured) feet Effective depth: measured 7950' feet Junk (measured) true vertical 6252' feet 6. Datum elevation (DF or KB) RKB 96'. PAD 67' 7, Unit or Property name Kuparuk River Unit 8. Well number 1Y-09 9. Permit number~pproval number ~-~-'~'~ ~ 83-52(C~nserv Order No. 261)_ 10. APl number 50-029-20935 11. Field/Pool Kuparuk River Oil Pool 7923' Tagged (10/13/92) Casing Length Size Cemented Measured depth True vertical depth Structural 73' 1 6' 251 SX AS II 73' 73' ' Conductor Surface 2361' 9-5/8' 1000 SX AS III 2381' 2209' Intermediate & 250 SX AS I- Production 8017' 7 ' 780 SX CLASS G 8037' 6317' 13. Liner Perforation depth: measured 7424'-7526', 7540'-7544', 7690'-7716', 7731'-7738',7748'-7758', @ 12 SPF, 7738'-7748' @ 4SPF M D true vertical 5870'-5943', 5953'-5956', 6062'-6080', 6091'-6096', 6104'-6111', @ 12 SPF 6096'-6104' @ 4 SPF TVD Tubing (size, grade, and measured depth) 3-1/2' 9.3# J-55/L-80 @ 7360'/7558' & 2-7/8' 6.5# J-55 @ 7588' Packers and SSSV (type and measured depth) BAKERHBRETRPKR@7354',BAKERDPERMPKR@7561',OTIS3.5''X'N,~,~~F~FiVEn____ . _ Stimulation or cement squeeze summary Intervals treated (measured) N0V ~ 9 I1~ Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. ~.ra~iss[0.~ 14. Pdor to well operation Subsequent to operation ReDresentative Daily Average Production or Injection Data ......... OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _~X 16. Status of well classification as: Water Injector __ Oil _ Gas Suspended Service MI / WATER INJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Area Drilling Encjineer D a t e /,/,/~/~'~.- SUBMIT I~1Dt,IPLICATE ARCO~ ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1Y-09 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-20935 83-52 DAILY OPERATIONS PAGE: 1 ACCEPT: 10/09/92 02:10 SPUD: RELEASE: 10/15/92 12:10 OPERATION: Workover DRLG RIG: NONE WO/C RIG: NORDIC 1 10/09/92 (1) TD: 8052 PB: 7950 10/10/92 (2) TD: 8052 PB: 7950 10/11/92 (3) TD: 8052 PB: 7950 PULL BPV 7"@ 8037' MW: 0.0 MVE RIG F/3N PAD TO 1 Y PAD. MOVE RIG ON 1Y-09 WELL. RIG ACCEPTED @ 02:30 HRS 10/09/92. RU HARD LINE. 2-1/16" 3000# GATE VALVE ON TBG HEAD WILL NOT CLOSE, HAVE 1200 PSI IN ANN. PU 2-1/16" 3000# GATE VALVE F/KCS TOOL HOUSE. INSTALL VALVE & LUB. PULL VR PLUG. RU CHOKE LINE. POH. LD 3-1/2" TBG 7"@ 8037' MW:ll.7 NaCl/Br PULL BPV. RU KILL LINE. TEST SAME TO 3000 PSI. TEST HARD LINE TO 500 PSI. BLEED OFF GAS F/TBG & ANN. CIRC SW AROUND THROUGH CHOKE @ 2.5 BPM. MONITOR WELL. WEIGHT UP 430 BBLS 11.2 PPG BRINE TO 11.7 PPG. CIRC 11.7 BRINE AROUND THROUGH CHOKE. MONITOR WELL-NO PRESS BOTH IN TBG & ANN. SET BPV. ND TREE. NU BOPS. NU CHOKE & KILL LINES, FLOW NIPPLE. PULL BPV. SET TEST PLUG. FULL TEST BOPE TO 3000 PSI. MU LANDING JT. PULL TBG FREE W/ll0K. PULL HGR TO FLOOR. LD TBG HGR. CIR BU THROUGH CHOKE. SLUG PIPE. POOH. LD 3-1/2" TBG. RIH W/SBR TOOL.PU 3-1/2" DP'S 7"@ 8037' MW:ll.7 NaCl/Br SERV RIG. FUNCTION TEST BOPE. CONT LD 3-1/2" TBG & SSSV. MU BAKER STORM PKR. SET IN 25' BELOW WELLHEAD. ND FLOW NIPPLE & 11" BOPS. ND FMC GEN II TBG HEAD. PULL PACKOFF. INSTALL NEW PACKOFF. TEST SAME TO 3000 PSI. NU FMC GEN II RETROFIT TBG HEAD. NU 11" BOPS & FLOW NIPPLE. TEST FLANGES TO 3000 PSI. PULL BAKER STORM PKR. LD SAME. POOH. LD 3-1/2" TBG & COMPL JEWELRY. LOAD 3-1/2" DP'S & 4-3/4" DC'S INTO PIPE SHED. STRAP SAME. PU CAMCO OEJ SBR PULLING TOOL, B/S, OIL JARS & 12 X 4-3/4" DC'S. RIH ON 3-1/2" DP'S. RECEIVED NOV 1 9 1992 Alaska Oil & Gas Cons. OommissiOt~ Anchorage WELL : 1Y-09 -OPERATION: RIG : NORDIC 1 PAGE: 2 10/12/92 (4) TD: 8052 PB: 7950 10/13/92 (5) TD: 8052 PB: 7950 10/14/92 (6) TD: 8052 PB: 7950 RIH W/6-1/8" BIT & CSG SCRAPER 7"@ 8037' MW:ll.7 NaCl/Br SERV RIG. FUNCTION TEST BOPE. CONT RIH W/CAMCO OEJ SBR PULLING TOOL. PU 3-1/2" DP'S. LATCH "J" SLOT O/S ONTO PBR MANDREL. JAR PKR FREE W/95K OVER. REVERSE CIRC THROUGH CHOKE. PULL 3 STDS, PKR VERY TIGHT. HOLE SWABBING. WORK PIPE, CIRC. POOH SLOWLY. MONITOR WELL. WORK THROUGH TIGHT SPOT AS NECESSARY. LD CAMCO OEJ MANDREL, HRP-lSP PKR, 9.8' PUP JT 3-1/2" TBG. CAMCO D NIPPLE & 8.57' TBG CUT-OFF(FISH LEFT IN HOLE UPON ORIGINAL COMPL=TBG CUT-OFF, GEOVAN TBG RELEASE, GEOVAN REV CIRC VLV-8.41' TOTAL). LD CAMCO OEJ PULLING TOOL. PU 6-1/8" BIT & CSG SCRAPER. MU BHA. RIH 2 STDS DP. SLIP & CUT 50' DRILLING LINE. CONT RIH W/BHA #1 ON 3-1/2" DP. RIH W/BIT & CSG SCRAPER 7"@ 8037' MW:ll.7 NaCl/Br CONT RIH W/6.125" BIT & CSG SCRAPER ON 3-1/2" DP. PU KELLY. CLEAN OUT F/7734'-7923'. CIRC HOLE CLEAN. BLOWDN KELLY. STAND BACK SAME. SLUG PIPE. POH. LD 3-1/2" DP. LD BHA #1. PULL WEAR BUSHING. RD DP EQUIP. RU SCHLUMBERGER E-LINE EQUIP. TEST LUB TO 500 PSI. PU & RUN 6.05" GAUGE RING/JUNK BASKET. HANG UP @ 7429'. PULL JUNK BASKET FREE W/4500~. MAKE SEVERAL ATTEMPTS TO PASS THROUGH 7429',UNSUCCESSFUL. POOH. PU 5.95" GAUGE RING/JUNK BASKET. RIH. WILL NOT GO THROUGH 7429'. POOH. RD SCHLUMBERGER EQUIP. FIN LOADING 3-1/2" TBG INTO PIPE SHED. INSTALL SEALS RINGS. TALLY PIPES. PU 6.125" BIT, CSG SCRAPER, B/S, OIL JARS, 4 JTS 3-1/2" DP'S. PU & RUN ON 3-1/2" TBG. RIH W/COMPL STRING 7"@ 8037' MW:ll.7 NaCl/Br SERV RIG. RIH W/BIT & CSG SCRAPER ON 3-1/2" TBG. PU KELLY @ 7359'. WORK THROUGH TIGHT SPOT @ 7420'. SINGLE IN W/KELLY TO 7618'. SMOOTH PAST 7420'. BREAK & BLOW DN KELLY, STAND BACK. POOH 5 JTS TO 7420' & WORK THROUGH TIGHT SPOT. STILL PULLING 8-18K# OVER, DRAGGING DOWN WHEN POOH. POOH & STAND BACK 3-1/2" TBG. LD BHA. RU SWS WIRELINE. MU 5.81" GR & JUNK BASKET, TEST LUB TO 500 PSI. RIH TO 7654', NO SIGN OF TIGHT SPOT. POOH & MU TBG TAIL(2-7/8") ON BAKER D PERM PACKER. RIH & SET PKR @ 7565'. POOH. RD SWS, RU FOSTER TONGS & PREP TO RUN TBG. RUH W/3-1/2" COMPL STRING. RECEIVED NOV 1 9 199; ;~nchorag~ WELL~ : 1Y-09 OPERATION: RIG : NORDIC i PAGE: 3 10/15/92 (7) TD: 8052 PB: 7950 RIG RELEASED 7"@ 8037' MW:ll.7 NaCl/Br SERV RIG. SPEAR INTO PERM PKR W/SEAL ASSY. SPACE OUT STRING W/PUPS. MU TBG HGR & LAND SAME. RILDS. PRESS TBG TO 2500 PSI TO SET PKR. HOLD 10 MIN & PRESS ANN TO 1000 PSI F/10 MIN TO CHECK SEAL-OK. BLEED DN & BOLDS. HOLD 1250 PSI ON TBG & SHEAR PBR @ 96K#. RELAND HGR & RILDS. PRESS TBG & ANN TO 2500 PSI-LOST 60 PSI, OK. PRESS TBG UP TO 4500 PSI, BALL WILL NOT SHEAR. ATTEMPT TO SURGE DN TBG TO REMOVE ANY TRASH AROUND BALL. PRESS TBG TO 4500 PSI W/2500 PSI ON ANN-NO SHEAR. CYCLE PRESSURES, BALL STILL WILL NOT SHEAR. PULL LANDING JT. INSTALL BPV. 3/4" CV LEAKING IN GLM #2. RD FLOW RISER, ND BOP STACK, NU FMC TREE. TEST SEALS TO 5000 PSI, TEST TREE TO 500 & 5000 PSI. RU CAMCO WL. RIH & PULL 3/4" CV, REPLACE W/DUMMY. TEST TBG TO 2500 PSI-OK. RIH W/BLIND BOX TO SHEAR OUT SUB. PRESS TBG TO 4500 PSI & ATTEMPT TO BEAT OUT BALL W/NO SUCCESS. (MAY BE FILL/TRASH ON TOP OF BALL). PULL DV. DISPLACE 11.7 PPG VISC BRINE W/107 BBL SW BUFFER & DIESEL. BLOW PACKING IN RIG PMP & REPAIR. CONT CIRC DIESEL AROUND-TOTAL 264 BBLS DIESEL. SHUT WELL IN. RD PMP LINES. CLEAN PITS. SECURE WELL. RELEASE RIG @ 24:00 HRS 10/14/92 (0:00 HRS 10/15/92). 10/16/92 ( 8) TD: 8052 PB: 7950 SECURE WELL 7"@ 8037' MW:ll.7 NaCl/Br MIRU 1.75" CUT(2.1" JET NOZZLE). PT TO 5000 PSI. CONDUCT SAFETLY MEETING. INITIAL WHP=250 PSI. INITIAL 7" PRESS=0 PSI. RIH W/CT. CIRC @ .5 BPM TO VERIFY FULL RETURNS. CONT RIH-WHILE MAINTAINING 500 PSI WHP. TAG @ 7561' CTM. RKB. INCREASE RATE TO 2.0 BPM(NEAT DIESEL). HAOLD BACK PRESS OF 500 PSI. WASH DN TO 7579' CTM, RKB. ON BTMS UP, DIESEL RETURNS VERY DIRTY(SOME SOLIDS EVIDENT). CONT CIRC UNTIL CLEAN DIESEL RETURNS EVIDENT @ SURF. INCREASE 7" PRESS TO 2000 PSI. SHUT IN WELL. INCREASE WHP TO 3100 PSI. SHEAR OUT. SUB SHEARED. CONT RIH TO 7760' (BOTTOM PERF @ 7758') CIRC OUT VISC BRINE. POH WHILE PUMPING CLEAN DIESEL @ 1.5 BPM. POOH @ 1745 HRS. FLUSH OUT FLOWBACK LINE. RD CTU. SECURE WELL. SIGNATURE: DATE: ARCO Alaska, Inc. : Post Office Bo^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 6, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1Y-09 Waiver October 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering cc:,vj,J S. P. Hoolahan ATO-1226 ir/ P. A. Lindberg ATO-1417 KOE 1.4-9 (w/o attachments) (w/o attachments) (w/o attachments) RECEIVED OCT - B 1992 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCo~npany STATE OF ALASKA 0 R I G IN A I. ALAb~A OIL AND GAS CONSERVATION COMMI~x~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance ,~_ Perforate _ Other 2. Name of Operator 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 568' FNL, 1252' FWL, Sec. 1, T11N, R9E, UM Attop of productive interval RECEIVED 1554' FSL, 1273' FEL, Sec.2, T11N, R9E, UM At effective depth 1301' FSL, 1532 FEL, Sec. 2, T11N, R9E, UM 00T -8 1992 A~, total depth 0il & Gas Cons 60mm~s¢ 1253 FSL~ 1581' FEL, Sec. 2, T11N, R9E, i~ska ' 12. Present well condition summary Ancn0rage Total Depth: measured 8052' feet Plugs (measured) true vertical 6328' feet None Effective depth: measured 79 5 0' feet (measured) true vertical 6252' feet None Casing Length Size Structural Conductor 5 3' 1 6" Surface 2361 ' 9 5/8" Intermediate Production Liner Perforation depth: 8017' measured ,1 7424'-7526', 7540'-7544', 7690'-7716', 7738'-7748' @ 4 SPF' true vertical 5870'-5943', 5953'-5956', 6062'-6080', 6096'-6104' @ 4 SPF' Tubing (size, grade, and measured depth) 3 1/2" J-55, tbg w/tail @ 7364' Packers and SSSV (type and measured depth) Camco HRP pkr @ 7333' & TRDP-1AE SSSV @ 1952' 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-09 9. Permit number 83-52 10. APl number 50 -02~J-20935 3~1. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 251 Sx AS II 73' 73' 1000 AS III & 2381' 2209' 250 Sx Top job w/AS I 780 Sx Class G 8 0 3 7' 6 31 7' 7731'-7738', 6091'-6096', 7748'-7758' @ 12 SPF 6104'-6111' @ 12 SPF ', 13. Attachments Description summary of proposal X Recomplete as selective sin~lle, replace SSV with injection valve 14. Estimated date for commencing operation October 1992 Oil __ 16. If proposal was verbally approved i O/~ / 2. Name of approver ~'$ bOl4,~j~ Date approvedl~' / 17. I hereby certify that the .fo.regoipgVis true and correct to the best of my knowledge. Sit, ned C- ~1~.. ~ Title ~'~'"~3~1~1~ FOR COMMISSION USE ONLY Detailed operation program _ BOP sketch 15. Status of well classification as: Gas Suspended Service WAG INJECTION Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance Mechanical Integrity Test X Subsequent form Approved by order of the Commission Origina! S~cned By David W. Johnston Form 10-403 Rev 09/12/90 IApprov_,.,al No. r'--~quire 10-4 Commi~ Date / 7 SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1Y-09 As per Conservation Order No. 173, Rule 5, paragraph (2), ARCO Alaska requests Commission approval to replace the existing surface controlled, subsurface safety valve in Injection Well 1Y-09 with a downhole, spring controlled, injection valve. This injection valve will act as a one-way check valve allowing downward injection of water and gas while preventing upward flow of reservoir fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. The proposed work would be performed during the forthcoming workover to install AB modified tubing couplings and a higher pressure rated wellhead in preparation for converting this well from water injection to WAG injection service. Attached is a schematic of the proposed injection valve. RECEIVED OCT - 8 1992 Alaska Oil & Gas Cons. ~;ommissior~ Anchorage TOP SUB ORIFICE SPRING . SEAT ~SEAT INSERT Otis MC Injection Valve FLAPPER VALVE AND SPRING ASSEMBLY RECEIVED OCT - 8 1992 Alaska Oil & Gas Cons. ~;ommissio~ Anchorage o. ^L SK 0 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing 99510 Stimulate Plugging Perforate Repair well Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3, Address P. O. Box 100360, Anchorage, AK 5. Type of Well: Development X Exploratory _ Stratigrap~hic _ Service _ 4. Location of well at surface 568' FNL, 1252' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1554' FSL, 1273' FEL, Sec. 2, Tt1N, R9E, UM At effective depth 1301' FSL, 1532' FEL, Sec. 2, T11N, R9E, UM At total depth 1253' FSL, 1581' FEL, Sec. 2, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8052' 6328' feet feet Other X 6. Datum elevation (DF or KB) 96' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-0~) 9.10.83-52APlPermit number nuTer~ppr°~l'. _ ~number so-02~-20935 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 7950' true vertical 6252' feet feet Junk (measured) Casing Length Structural Conductor 5 3' Surface 2 3 6 1 ' Intermediate Production 8 01 7' Liner Perforation depth: measured 7424'-7526', 7540'-7544', true vertical 5870'-5943', 5953'-5956', Size 16" 9 5/8" 7" 7690'-7716, 6062'-6080', Cemented Measured depth 251 Sx AS II 1000 Sx AS III & 250 Sx top job w/AS I 780 Sx Class "G" Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55 w/ tail @ 7364' MD RKB Packers and SSSV (type and measured depth) Camco HRP pkr @ 7333' & TRDP 1AE SSSV @ 1952' RKB 13. Stimulation or cement squeeze summary Intervals treated (measured) 73' 2381' 8037' Treatment description including volumes used and final pressure True vertical depth 73' 2209' 6317' 7731'-7738', 7748'-7758' @ 12 SPF 7738'-7748' @ 4 SPF 6091'-6096', 6104'-6111' @ 12 SPF 6096'-6104' @ 4 SPF RECEIVED :JAN 3 1 1.990 ,~,",'~'" 0ii & Gas Cons, Com~lis~iu~ . Anchor~ja 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1677 994 607 1060 165 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. (6334) 1550 Status of well classification as: Oil __ Gas Suspended __ 2490 Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~'~)/f~'~/~-~.~-'~'7~Title Sr Operations Engineer Form 10-404 F~ ~)6/15/88 sDUatBeM, ~ U,,~ L~i C~A~T E I ARCO Alaska, Ir~O Subsidiary of Atlantic Richfield Compm.~ WELL SERVICE REPOR'~ WELL '"ONTRACTO, O ~'~'~ - REMARKS ~..~,,~, . /5 ~P~ . IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME IOAYS / IDATE o?oo mov¢~ ~;~ 373~/ ~ ~v.~$' . r"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~°"~°~ 1 TM~ ,~ I- ~'°'°~1~''~'''~ m. !-v°'' AR~O Alaska, Inc. Drillsite Morning Report CPF ~ Date_ /"fA'P~bJ -~'~ !9~? - Time ,Z',/--/D_/) Drillsite -~.,-"F' statu~' Production Well status Gas Lift Status Shut-In Well P.T. or TP Choke Temp Last H2S CSG Pressure PSI Gas Inj. Rate # SI Zone PSI Bean °F WC% PPM 7" 10" Temp MeterTotal MSCFD Hrs Reason ..~ ~ '1~ 1~ o i '7~ I/Z.. .~ f~'"' ~_~ I ~ ~D ~',~ 11,5," ~ ~ .~ ~' i l /, q ?., 7 , r' .., .... ~ I ,, , , , .I. , , Total //, ~ ~ Stat~s Injection Well Status Shut-In Well!Gl, PW 'Inject. Pr;essure PSI Temp Choke CSG Pressure PSI Meter Injection Rate # or SW Zone Allowable Actual °F Bean 7" 10" Total BBLSIDay MMSCFD Hrs. Reason SWl Total PWI Total ~__ t') / ,~ 0 ~ 11' ...... I, .... O= J ~_i'liJ J:Jl'l~{[~l iris. PRI I Bath I Blanket I J I Chemicals J O Alaska, Inc. ~ , -" Orills. iJ[e Morning Report ' CPF Date .__~ - / - ~'~ Time Status P~:oduction Well Status Gas Lift Status Shut-In Well P.T. or TP Choke Temp Last H2S CSG Pressure PSI Gas Inj. Rate # SI Zone PSI Bean OF WC% F:'PM 7" 10" Temp MeterTotal MSCFD Hrs Reason ~ ~ /~ / 7.¢- /'2 4 //.,,- ~¢ 5,'.~ 12[.z~ 6,,o //~ ~~.~ z.~n ~ ~o ~ 9~ ?~ {~O 9¢0 ~ . ,. Status Injection Well Status Shut-In Well Gl, PW Inject. Pressure PSI remp Choke .CSG Pressure PSI Meter Injection Rate # orSW Zone Allowable Actual °F Bean 7" 10" Total,. BBLSIDay ,LHMSCFD Hrs. Reason · I -r· / I 5~ 13,~ ~ ~ ~ ~ · ~ I Z P~ ~t ~ 2¢~ /~ /26 l~ z~ ~7~7 ~z~Z ~ Total ~/~ SWI Total -~ PWI Total -~/. ,,~'~'5/ .D.ri,site I c°!' Te. mpe,ratu_re OF I C_oil Press, ure_PS! I _Bath I ..Blan_ke..t, I ..... I .,..._C_hemi,c~s_ ...... ....... k ~ u .3/"",. .... K~D ~ ~.~_11 _ k¢,~ .__3t¢- ? _ k,~,.~ ,2w-s' 6-/7-79 AL, A OIL AND GAS CONSERVATION COMM ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate __ Pull tubing _ Variance _ Perforate _ Other X_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 568' FNL, 1252' FWL, Sec. 1, TllN, R9E, UM At top of productive interval 1554' FSL, 1273' FEL, Sec. 2, T11N, R9E, UM At effective depth 1301' FSL, 1532' FEL, Sec. 2, T11N, R9E, UM At total depth 1253' FSL, 1581' FEL, Sec. 2, T11N, RSE, UM 8052' 6328' 12. Present well condition summary Total Depth: measured true vertical feet Plugs (measured) feet None 6. Datum elevation (DF or KB) RKB 9§ 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-Q~ 9. Permit number 83-52 10. APl number 50-029-20935 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 7 9 5 0' true vertical 6 2 5 2' feet Junk (measured) feet Nolle Casing Length Size Structural Conductor 53' 1 6" Surface 2361' 9 5/8" Intermediate Production 8 01 7' 7" Liner Perforation depth: measured 7¢[24'-7526', 7540'-7544', 7690'-7716', 7738'-7748' @ 4 SPF true vertical 5870'-5943', 5953'-5956', 6062'-6080', 6096'-6104' @ 4 SPF Tubing (size, grade, and measured depth 3 1/2", J-55, tbg w/tail @ 7364' Packers and SSSV (type and measured depth) Camco HRP pkr @ 7333' & TRDP-1AE SSSV @ 1952' Cemented Measured depth True vertical depth 251 Sx AS II 73' 73' 1000 Sx AS III & 2381' 2209' 250 Sx Top job w/AS '1 780 Sx Class G 8 03 7' 6 31 7' 7731'-7738', 7748'-7758' @ 12 6091'-6096', 6104'-6111' @ 12 13. Attachments Description summary of proposal X_~ Convert oil producer to water injection. Detailed operation program SPF .¢~t ,--~ · ,.¢.~,~a OiJ & Gas Cons. BOP sketch 14. Estimated date for commencing operation April 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S.¢ned /~~ z/~ .,~"~'~- .¢.,,~~ Title FOR ~MMISS~N USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test "'x/ Approved by the order of the Commission Form 10-403 Rev 06/15/88 IApproval No. I Subsequent for_n3, require 10-~ ORIGINAL SIGNED B'f LONNIE 6. SMITH Commissioner ¢,p~roved Copy Returned SUBMIT IN TRIPLICATE feet Well 1Y-09 Conversion to Water Injection , , , Wireline BOPE will be used in conversion of the well to water injection service. The static bottomhole reservoir pressure is estimated to be 3500 psi based on recent measurements in offset wells. No workover fluid will be used. ~ ...1 ~,zsl, . 1-~~' Anchorage ,3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. ,5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF IN ] REL I NE 80P EQU ! PMENT ARCO Alaska, In.' Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 Transmittal #:6054 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. .. 3C-16 Kuparuk River Unit 'A' Sand 100598H 8-26 thru30-87 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thrug-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thru8-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk Well Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk Well Pressure Report(Otis) Static A Sand 9-1-87 1Y-14 KuparukWell Pressure Report(Camco) C Sand 8-23-87 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 IY-5 Kuparuk Well Pressure Report(Otis) Static C Sand 8-23-87 1Y-16 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-11 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well Pressure Report (Otis) Static C Sand 8-22-87 2X-14 Kuparuk Well Pressure Report (Otis) Static C Sand 7-18-87 2Z-I Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-lO Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 Receipt ~cknowledged: DISTRIBUTION: te: Anchorag/~ A~aska 011 & Gas Cons~Commisslon -"~'State'of--Alaska BPAE Chevron Mobil SAPC ARCO Alaska, Inc, Is a Subsidiary of AllanllcRichlleldCompany Unocal ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF NUMBER NUMBER I N I T I AL 50-029 I NJ ECT I ON DATE OF DATA TYPE REASON FOR WELL ZONES PROF I LE/ PROF I LE/ PROF I LE/ COMPLET I ON TAK I NG SURVEY SURVEY SURVEY WAT ER I NJ ECT I ON BWPD 2B-11 21089 11/19/85 2H-01 20033 03/15/86 2H-04 20027 03/15/86 50-103 2T-04 20074 03/30/87 2T-09 20071 03/30/87 2T-11 20075 03/30/87 2T-15 20062 03/30/87 2T-16 20063 03/30/87 50-029 3A-02 21.431 01/21/87 3A-04 211133 01/21/87 3A-10 21457 01/21/87 21458 01/21/87 ~..>3 ~;~ 21490 04/14/87 fY-? 06/16/87 SPINNER FOLLOWUP A&C S A&C 06/05/87 SPINNER FOLLOWUP A&C S A&C 06/07/87 SPINNER FOLLOWUP A&C S A&C 06/13/87 SPINNER INITIAL A&C SS A&C 06/16/87 SURVEY INITIAL A S A 06/21/87 SPINNER INITIAL A&C SS A&C 06/16/87 SURVEY INITIAL A&C SS A 06/16/87 SURVEY INITIAL A&C SS A 05/25/87 SP INNER I N I T I AL A&::C SS A&C 05/87 SURVEY I N I T I AL AS~ SS A 05/87 SURVEY I N I T I AL A S A 05/27/87 ~ i N I T I AL ~ SS AS~C 05/87 SURVEY I N I T I AL A S A .. %... / 3485 1833 590 RECEIVED AUG ,:, a¢7 Naska Oil & Gas Cons. Commission Anchorage 2500 ._, 1200 1650 .RECEIVED Sas Cons. Co Anchorsn~e ¢,/! ATTACIIMENT 1 PAGE 3 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE tl - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl NUMBER NUMBER 50-029 '""~3B-01 J 21318 '"'-~3B-07~'/' 21337 '""~3B-12~/' 21370 3C-02 21414 '"'~3F-03c-~/ 21448 3J-04 214OO ~"°3J-05~'/~ 21436 '""~3J-08'-~ 21439 3J-13 21495 3J-16 21498 I,:- /; DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INJECTION SURVEY SURVEY SURVEY WELL COMPLETION 01/23/87 05/23/87 SPINNER INITIAL A&C SS 01/23/87 05/22/87 SPINNER INITIAL A&C SS 01/24/87 05/21/87 SPINNER INITIAL A&C SS 01/09/85 06/22/87 SURVEY FOLLOWUP A&C SS 05124/87 04101187 05/28/87 05128/87 03101/87 03/31/87 SPINNER SURVEY SPINNER SPINNER SURVEY SURVEY 01/21/87 05/21/87 02/02/87 02/02/87 02/02/87 02/02/87 NITIAL NITIAL NITIAL NITIAL NITIAL NITIAL A&C SS A S A&C SS A&C SS A S A S ZONES TAKING WATER A&C A&C A&C A&C A&C A A&C A&C A A I NJ ECT I ON BWPD 2530 A SAND 1240 C SAND 1927 932 1072 RECEIVED 0il & Gas Cons, Commission Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A ATTACHMENT I I KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 Drill Site Well No. Log Date lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site 1C Well No. 1C-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8 ' Log Date 5/9/81. 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. 10 Lpg Date 1D-1 v 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 (~_,k, lD-8 (ws-8) 5/i0/78 Oil & Gas Co:,s ,. ....... Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date lQ ~1Q-5~-12/1/85 Drill Site Well No. Log Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 , 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/B2 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Dri 11 Si te 1G Well No. LOg Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. Log Date 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 2/19/83 1F-2 2/3/83 1F-3 '1/31/83 1F-4 5/29/83 1F-5 10/25/82 1F-6 10/28/82 11/19/82 5/7/83 3/!2/83 1F-7 Alaska 0il & 6as Cons. ~ora~e Page 3 ...... Drill Site Well No. .Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 ~~ 6/20/83 ~_~- ~- 5/10/83 '-~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2~28~85 2C-7 10/15/84 ~2C~'16~12l-1-]~85 Drill Site 2Z' Well No. Log Date ~_Z=~. 7/10/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF-pg-O052 Alaska Oil & G~s Cons. Anchorage Page 3 · Drill Si~e 1Y Wel 1 No. 1¥-1 ~1¥-2 1Y-3 '1Y-4 .~1Y-5 1Y-6 --'~'~lY-9 "1Y-11 1Y-12 1Y-13 ~1Y-14 ~1Y-15 ~ 1Y-16 Log Date .x~0/21/83/ 6/10/83 '~3/4/84/ "6/18/83 '~ 7/2/83 '~6/29/83 ~6/27/83 ~6/22/83 ~/20/83 ~5/~o/83~ ~11/21/8~ %5/25/83 ~5/27/83 ~/13/83~ ~5/18/83~ ' ~/29/83 ~'5/30/83' ~ ~10/23/83 Drill Site Well No. Log Date 2Z "2Z-1 -~2Z-2 .~ "'-2z-3 "~2Z-4 ~-2Z-6 "'~2Z-8 7/10/83 6/24/83%,. 7/19/83/ 815/83 7/12/83 7/27/83 7/28/83 8/3/83 Drill Site 2C Wel 1 No. ,Lpg Date -- 2c-4 "'2/19/82 k ~. _ '~- 2/28/85×x , '~' 2C-7 ~'~10/15/84 .I VLF'p9'O029 RECEIVED FEB 2 1 1~85 Ai~k~ 011 & Gas Con~. Gommls~. Anchorage ARCO Alaska, Inc. Post Office ,"~ $0 Anchorage .... ==Ka 99510 Telephone 907 277 5637 Date: 1/30/85 Transmittal No: 5011 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 //Transmitted are following acknowledge receipt herewith the items. Please and return one signed copy of this transmittal. PBU ANALYSIS/BHP REPORT Camco ./1Y-'9 .M //1/21, 23/85 M IY-12 1/21,23/85 SEQUENCE OF EVENTS /2C-7 V' 1/23/85 /2D-7 / 1/23/85 1/23/85 "SBHP" 1/23/85 "SBHP" PRESSURE/TEMP SURVEYS Torque Turn /1G-8 / 1/15,16/85 Gauge ~63139 1/15/85 "PBu,' /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M DISTRIBUTION Date: Alaska Oil .~_ ,, -.,~SanchorageCo[zs. COmmissio~ Drilling W. Pasher State of AK Geology Mobil · -G.~s Phillips Oil Sohio Union NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary of AtlanticRich~ieidComDany ARCO Alaska, Inc..~--. Post OfficF'~ 360 Anchorage, ,.~laska 99510 Telephone 907 277 5637 Date: 2/05/85 Transmittal No: 4824 RETIYR~N TO: -. ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B ' P~O. Box 100360 , ~Anchorage, AK 99510 ' ~ f/Transmitted herewith are the following items. Please acknowledge receipt ~ and return one signed copy of this transmittal. PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 ~ -~ 2Z-6/ 9/03/84 2X-6/ 8/16/84 --- 2X-4/ 8/i6/84 --2X-iF'" 8/16,19/84 --2V-5/ 8/16,19/84 ~2V-2/ 9/07/84 .... 2F-9/ 8/28/84 ! -- 2F-8~"'.- 10/08/84 / --2F-7/ 10/07/84 _2B-lG/ 9/03/84 ---2C-5 / 8/17/84 -~-lY-!3/ 8/!6/84 ~lY-9/ 9/07/84 ~lY-5/ 9/14/84 1Y-5~ 9/06/84 ~lG-6.' '8/25/84 ~lH-4v 9/04/84 --1F-12¥ 9/09/84 -~lF-9 r~ 8/17,18/84 <-lF-8z 8/16,17/84 --1E-8~/' 10/12/84 ? ~-lD-5~ 10/07/84 ~lA-4~' 9/02/84 ----1A-3Z 9/02/84 Gearhart Otis Gearhart Camco Camco Dresser Otis Otis Camco Otis Otis Otis Dresser Camco Camco Otis Otis Otis Otis Camco Camco Otis Camco Otis Otis Receipt Acknowledged: B. Currier "}~P 232" "P~P 233" 9/06/84 "SBI-]P" 9/05/84 8/17/84 8/16/84 }o/o /84 "Static BHP" "PBU"" "PBU" "SBHP" "E Line" "Pressure Falloff" Drilling DISTRIBUTION W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips 0il Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc<.~-~ Post Offic .360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETLrKN TO: NCO ALAS~, I~. AT~: Records Clerk ATO-1115B P.0..~:~100360 ~/~ -~z°~°rage' ~ 99510 · . , v__=-~--- -/T'~n~itted_herewith are the following it,s. Please acknowledge receipt and return one signed copy of this transmittal. OTIS PBU SURVEYS 2W-8j' 1 / 08 / 8 5 . lB-7" 12/14/84 2F-12 1/06/85 2F-5-<'' 1/02/85 2W-§/_ 1/07/85 · 1107/85 lA-1 .... 12/31/84 lA-1 ~ 12/23/84 lG-5 ..... 12/25/84 2F-3 ~ -12/3!/84 2V-8A ~ 12/16/84 2B-10 ~ 12/17/84 1Y-9~ 12/20/84 ~iC~ 12/10/84 2F-2 '-~ 12/29/84 2~-[~ ~-~ ~/0~/85 2~-[4- [/04/85 2F-9 ~ 1/02/85 ~-8~ ~/0~/8s API 02 9-21228 '029-2D616 029-21097 029-21073 029-21220' 029-05900 -- 029-20908 -- 029-21178 029-21084 029-2 093 5 029-21 063 029-21048 029-21.090 029-21077 CAMCO PBU SURVEYS 1E-12 < 12/14, 16/84 /cat Receipt Acknowledged: B. Currier DISTRIBUTION Drilling W. Pasher State of AK BPAE Chevron Geology Mobil G. Phillips Phillips Oil Sohio Union D&H NSK Ops. J. Ratkmell Well Files TO: William VanAlen KUPARUK ENG ! NEER I FIG 'TRAN..~.41"FTAL #/~,,¢(0 Ff'¢:~: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following' PLEASE KOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, ARCO ALASKA, IKr---,. AT]N: SHELBY J. I~,~TTI-tD,~ - ATO/1115-B P. O. BOX 100360 ~E, AK. 99510 KUPA~L~JK ~ 1 NEER! l~ TO: William VanAlen FR~A: D.W. Bose/Shelby J. Matthews Transmitted herewith are the foliowincj- PLEASE ARCO Alaska, In'- Post Office= ...ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June- 23, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUKJBCT' 1Y- 9 DearMr. Chatterton: Enclosed are the well completion report and subsequent sundry report for 1Y-9. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:tw Enclosures ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ~ ALASK,, OIL AND GAS CONSERVATION L, UMM'ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX:IX 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-52 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20935 9. Unit or Lease Name Kuparuk River Unit OTHER [] 4. Location of Well Surface: 568' FNL, 1252' FWL, Sec, 1, T11N, RgE, UN 6. Lease Designation and Serial No. ADL 25646 ALK 2577 5. Elevationinfeet indicate KB, DF, etc.) 96' RKB 10. Well Number 1Y-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ND adapter flange & master valve, RU Schlumberger, Ran CBL/VDL/GR/CCL f/7950'-2300', Ran Gyro f/7900'-surface, NU adapter spool & master valve, Accepted rig @ 0400 hfs, 05/07/83. NU BOPE & tstd - ok. Perf'd the following intervals: 7738'-7758' 7731'-7738'/7710'-7716' 7706'-7716' 7690'-7700' 7540'-7544'/7524'-7526' 7504'-7524' 7484'-7504' 7424'-7484' RECEIVED JLJN 2 ~ 'lq~:~; Alaska Oit ,-~ Gas Cons, Commission Anchorage Ran 3-1/2" completion assy w/tail ~ 7364', pkr @ 7333', & SSSV @ 1952'. psi - ok. Disp 7" annulus & 3-1/2" tbg w/diesel. Set pkr. Closed SSSV. rig @ 0400 hrs, 05/10/83. ND BOPE. Set BPV. NU tree & tstd to 3000 Secured well & released NOTE: Geo-Vann tubing - release sub did not shear. 14. I hereby certif.~ that the foregoing is true and correct to the best of my knowledge. // Signed ~/ J ¢ Title The space be~w ~o~mission use Conditions/~f Approval, if any: / Approved by By Order of COMMISSIONER the Commission Date _ Y Form 10-403 GRU3/SN22 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - ~- STATE OE ALASKA ..... --- ~_~ ALAS~. ~JI'L AND GAS CONSERVATION .MISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILX~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .-. 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 83-52 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20935 4. Location of well at surface 9. Unit or Lease Name 568' FNL, 1252' FWL, Sec. 1, TllN, R9E, UM :]~"~-I~klSl~.~,.,~.v,, , Kuparuk River Unit At Top Producing Interval t ~ItIFI"'ED I 10. Well Number 1554' FSL, 1273' FEL, Sec. 2 , TllN, RgE, UM l~r& .~_ j. 1Y-9 At Total Depth i~'~i.' ---~ I1 11. Field and Pool 1253' FSL, 1581' FEL, Sec. 2, T11N, R9E, UM -~._~'~n'"~'-- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 96' RKBIADL 25646 ALK 2577 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. · I 15. Water Depth, if offshore i16. No. of CompIetions 04/15/83 04/24/83 05/1 0/83I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PIugBackDepth(MD+TVD} 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 8052'MD,6328'TVD 7950'MD,6252'TVD YES~] NO []I 1952 feet MD 1350' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/FDC/CNL, CBL/VDL/GR/CCL, Gyro 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# U-40 Surf ('~3'~ 24" 251 sx AS II 9-5/8" 40.0# J-55 Surf 2381' 12-1/4" 1000 sx AS Ill & 250 sx A,< I 7" 26.0# J-55 Surf 8037' 8-1/2" 780 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) 7738' -7758' 3-1/2" 7364' 7333 ' 7731'-7738'/7710'-7716' 7706' -7716' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7690'-7700' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7540'-7544'/7524'-7526' 552' 219 sx AS I 7424'-7524' (9-5/8" x 16" annul ,s) 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE I GAS-OILRATIO TEST PERIOD II~ FioTM Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~1~! 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None jf iN c, Alaska 0il & (~as C0f~s, C0rnmissio~. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. . .~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7424' 5870' N/A Base Upper Sand 7525' 5943' Top Lower Sand 7662' 6041' Base Lower Sand 7830' 6163' __ 31,. LIST OF ATTACHMENTS Drilling History, Completion Summary, Gyroscopic Survey (2 copies) - 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~ ~. /~~ Title Area Drilling Engr. Date /~//~-~ / --- / j / 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". PRODUCTION (]tOECI]DN) lEST DATA TEST SUHHARY -' WELL TYPE: Old )< New PERFORATIONS: 7~ ~ - 7~ C ', 7~0 - INTERVALS: DATE[' Producer' Injector ; TEST SUPHARY . " AVERAGE PRODUCTION (IN3ECTION) RATE DURING TEST: . AVERAGE GDR: AVERAGE WDR: :- _ CUHULAT~VE PRODUCTION (IN3ECTION) DURI~ TEST: rr~P. ,~- ,?Si SZ~HP ~0~ ~sZ ~ / ~DT~ PRO~CING (IN3ECTION) TIME= LD~GI~ ]BOLS RUN: = ~P,~F~./t_ ~C. L · BPD BBL API GRAVITY __ ~ - °K°I AT 60° ' SS HRS IOTAL SHUT IN TIME: ~ , ~ HRS HA3DR WELL EVENT HISTORY DATE START END EVENT _. t · . , _ 8HP = 3~0'~ ~F., = )~,'7 ° ~: :Poo H.- '. ~,D, a o CU~,,JLATIVE PRODUCTION (]N3ECTIDN): BBLS IOTA[ PRODUCTION (IN3ECTION) TIME: DAYS TIME SINCE LAST HA3DR SHU. T IN: D~YS · Y. UPARUK RIVER UNIT iY-9 DRILLING HISTORY NU Hydril & diverter. Spudded well 1400 hrs, 04/15/83. Drld 12-1/4" hole to 2411. Ran 60 jts 9-5/8" 40#/ft J-55 BTC csg w/shoe @ 2381. Cmtd 9-5/8" csg w/lO00 sx AS iii and 250 sx ASI. ND Hydril & diverter. Install 9-5/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - witness by State. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 11.5 ppg EMW. Drld to 4169. Had the 9-5/8" csg parted @ hanger. Set retrievable packer @ 552' ND BOPE. Repaired surface csg. Cmtd 9-5/8" x 16" annulus w/ 219 sx ASI. NU BOPE. Tstd csg to 1000 psi. Drld to 8052 TD (04/24/83). Ran DIL/SFL/SP/GR/FDC/CNL logs f/8052 to 2381. Ran 205 jts 7" 26#/ft. J-55 HFER~I BTC csg w/shoe @ 8037. Cmtd 7" csg with 780 sx class "G" cmt. Instld 7" emergency slips & packoff & tstd to 3000 psi - ok. ND BOPE and installed tubing head. Displ well w/diesel. NU master valve & tstd to ~000 psi - ok. Secured well & released rig @ 1700 hrs., 04/26/83. HILL/D 05/13/83 1Y-9 COMPLETION SUMMARY ND adapter flange & master valve. RU Schlumberger. Ran CBL/VDL/GR/CCL f/7950'-2300'. Ran Gyro f/7900'-surface. NU adapter spool & master valve. Accepted rig @ 0400 hours, 05/07/83. NU BOPE & tstd - ok. Perf'd the following intervals- 7738 - 7758 7731 - 7738 /7710'-7716' 7706 - 7716 7690 - 7700 7540 - 7544 /7524'-7526' 7504 - 7524 7484 - 7504 7424 - 7484 Ran 3-1/2" completion assy w/tail @ 7364', pkr @ 7333', & SSSV @ 1952'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp 7" annulus & 3-1/2" tbg w/diesel. Set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 0400 hrs, 05/10/83. NOTE' Geo-Vann tubing-release sub did not shear. GRU3'CS5 A,]ask~t Oil & Uas Cons. f-;urnmissi.o,,-~ Ai~cho~'ag,3 F'AGE 1 Y .... ~) ( SEC 1 'F 11N R'.:gE ) ~::. ' :';'7. ~"",'-I K I_1F' A R I_1J-:( :'2, -' ,'4:;~ .... ,'.:i L A S K A ......................... ~ .. VE]i::(TZCAL. SEC:T]ON C:ALCULATED '¢~LONG CLOSURE F:OMF'UTATION DATE IdAY 6,, 198:3 DATE r-iF' '-"1 I'"' ..... ., · :, _ n v ~ ~' M A Y "l. BFI:--;S GYR ]r.3E:r-~F' I C F;IJRVEY ,_lOB NLIMBER AK-BO-:'40041 KELLY BUSHING ELEV. = 96.00 FT. OPERATOR-SAMEC I'RUE SLIB-SEA HFZASURED VERT I C:AL VERT I CAL f: L:~]z']]q ....... -¢/EP'T'Pl DEPTH C: Fd_I IR F; E F:OURSE DOG-L. EG TOTAL Z NE:L I NAT I ON D I REE:T I ON :_:;EVER I TY RECTANGULAR C:OORD I NATEE; DEG Id IN DEGREES DEG/100 NORTH/SOLITH EAST/WEST V f< R T I C A L sECTiO'N : ::: 0 O. 0 (') -9'6. 0 0 N O, 0 E 0,0() 0,00 0,00 O, ()0 I .1. 0 C) 100. (')0 4.0 () 0 19 2 C) 0 2:00.00 104.00 0 18 :30 C) :':: (.)(). 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'"' . 0 . .. _ .. :2:.()7 6, 08 S .. 4-. 37 14 77 '=' · · 4 ,, 91. W 7. '29 W t2, 56 'W !? ,, :32 J. 5;'. :39 ('" ,t 2:l. Jo W :27. l°W :2:4 /*~ W :66. I6 S · '"' 45. S 98.47 ...:,'"" 43.66 W · '."54.09 W '?::; 7:3 i,-.1 4:3 ,, '72 62.64. .......................... I'b'i3 0 157 :i:-':. ('-):2' 14. 8:2 ,, ()2 2:5'.: 2/:, :F; 1 ': .... . 1 ~-''''' =' ='",'":' :2:C) :34. 6..::,L) 1621 5'2 ._,...' ........ ,. 17 C) 0 16, 6, 4. :37 156, 8. :2:7 :2:1 :27 S ............... , ....... f ....... 7' ............... ~ ...... ~ '--"7~' "~ S i'75(.~ ~ 7Uc,. ':: ..:: 16 ! U. ;-. L:: ,:, 1 50 ]. ::::~","} ........... 1749, 22: ]/',5:'~~:~' o4""'-'40 · . L;; :i 9()() 1:3:32,51 17:36.5 .t :34 :30 .S ::::/-,. () W ...,"=./','::). :37. :5:() W 4.6 :.3 ::::9,_. C) W .=.":' ]. ,':q_ 11 '7 .. (-)'7 S 7::":. E: 4 W 140., !:::;2 1:3/-, -'/.., = c- 9:':: 6::3 W 16 '~' 12 _ # ..., . - ~ -._t~ .'[ SE,. '~;4 $ I 0':?. 64 W ]. 'PC). EI::I :::"=~,~'O.'H...' :.. 0 :2i:::2:, 39' ' W ".' "' ..:':' ' ."1 :.. · 37.'80'W'.' .: 'i · .. 1.77.4.0 :-7 . : 12:6;06 W · 1":;';3. """ .'..3' .'. :".' , .:,u 142' 6'5 ' W · '" ,,, ,, , :. ... :..:. ,, w .'.' · 241.., :34.. S.. ' i 76'.'78 ;' W 2: i '7. :L 2 24. 9. E:¢-) :;;..:'~..;"'i;;' ~ :L () ........................... -:2 i]-(]'O ........ ~ 4 ,, ]. :i3-- 1 E: 1 E:..1. 8 35 5 '7 2 :i. ()0 1994.06, 1 :::: 98.06, 38 0 :2200 2072.24 ! 976.24 39 :5: .... 2 :..--: ri'c) ............. 2'I 4'i..'-:" F:; 7 ......... :~;-~' '~''''~'~;'-''"- '" · " 0."-~ .':.."-'~.." ~ i "" '"' ................ ~ -.~ :24. () 0 "222 :;':-'. '70 2126.70 42 49 · :'::7.6'? W 1 :3'7,80 W 2 :3/:,. 30 W 1 :37..~-,0. 'W · '2 Oo 60'W' · ' .1 ~_~ i_1 ,n . . . . . . · . · . .':. . ,, 46 . (:)4 ,47 :2:8'7.44 :-'i; 21:2. C)9 14 · ':":"=i c) C) :5; 248 ':' 1 14 384.7/:. :3 2:5:/=,. 47 W '.'T~- '%&" .'"1',,..., · .... .. · "' ' ' '~'~'g__';:";L' c;.. '. '. ...._-.__:::,~',/','~_ 1 · ~,.~ ,~i.., . ..,, ' ..." :"'.. ' :":' ".: .::: ' · .: .: · i" '. ..'. '.' :: ... :'...:' .... ... .. .. · . ... 416,. :38 479. 17 ;,,. · ,... ..,%, '~ ...... '"1--'-- -2,~'J' c:;, / "-I' 6,1 0 ,, 78 iY-.9 ('.=~EF: 1 1-11N RgE) F{LiPARUK A'I_ H.", t'., H'~ r--,.- ~ ..................................................... SPERF=,:Y-SLJN WELL SURVEYING COHP~NY ANCHORAGE ALASKA :'9 VER'f'ICAL SECTIOr,,I F:ALCULATEB ALONG CLO:~;URE CCd'iF'UTATInN DATE MAY 6, l'yu:-~ I]A-I'E (iF' '.-=;LIRVEY MAY ..:',L, B 0 S S O Y R f-I S F: FIF' I C SI_I R V E 'Y' ,JOB NLIMBER AK-Bn-:3C~C:,4i KELLY BUSHING ELEV, -'-'.-. '.:.>,'!,,,00 F:T, OF'EF~ATOR-SAMEC TRUE HIEASLIRED VERT I F':AL Di='PTH ...............'D'EF":"TH :::; I_1 B- S E A F: 0 i_1R S E VERT I r-:Al_ I NCL I NAT I ON L~EP"i"H ,LIEU C: 0 LI R S E D 0 iS .- L E G D I RECT I fiN SEVER I-FY DEGREES DEL]/i 00 TnTAL REF:TANGLILAR C:nnRD I NATE F-'; NORTH/SriLJTH EA:.::T/WEST V E R'T' i C: A L SECT T ON ................. 32.7.i:0 o:Z3'c5-,7 '7 :T2 ...... ~ .T";'--,.:"F2 27 ()0 24:3 8. '72 2 :=:,-1. 2.72 .........';;-~---', ("~,:"~ 2.'=; ('r.:;'. ":" '. ,,-, :.2413 . ._.':-';/-_, '2'--.)'C~ Cl ....... ........... .. ._'--' F;-, c,'r~ ,_, ... · A"7_, ........... 2L'].'E:'Z~ , ::::: / :q 0 C) 0 .- 6..~ ~-' '78 "" ~= .'=i' 78 ..... , ,.-' ,.,j,.... (=, :31 ('~ .... 0 272-": 4 4 a ~;"/::,~.-, .... o 4,(::' ..................... ~ :.:::,."uo ~;~",-'zp7 "2/= ! 3 :':: ()0 :2:5:66, 44- 2'77 O. '-1. 4 : :.=:zl. O0 2'P:_::7, :3'7 284.1. :37 ................ :350¢£ .......... ~CfO'?, :::.:'::; 3/=,00 :3078,24 ,.'.'"'- '":"-' Y o...', ;::4 ':aTC~O 3148, 80 30!52. :F:O 4:3 44 44- 15 44 47 S 40.8':? W 4.4 5'.:..' S 4.1,50 W ~;~--2 .......... ~--4-1-Z6~:? ' W 44 () '$ 44 30 S 4,2.19 .W. · .. . 43 39'.W" 44 52 !ii; 44.19 W 44 44 :---; 44.50 W 44 54 S 44.69 W 45 23 S 44,/:,,0" W ,,:1.5 11 · S 44.30. W 4,:, 2 '=' 44, 0 W o. 6 7 ':?() 8 ,, 77 (-) '2!=l '- = 9. . . . .':"._, 17 ('~. 22 1009. :36 o. 49 0 "'~ ':l ~ ~:.., 0.27 1,059'. 79 ! I 10.5:3 · . 1161. :37 S 4-:E:, :=:9 W S 43.60 W S '-' W 4..:,. 0 ,, :]i:O 0.26 O. 24 1 '212. '1. ':..'; 1262.97 1:31 :.3.63 S 43,69 W 0 4I ';,. t.0 ':W ."'..'" ::' ': 2 · ... ..... · . 36..39. W"." :' "/=", .44 .i364.00. 141"4 .. . . · :.. .: 1441 '-~c S :3:3. C} W .5. (.': 3 14/=,':?. (')c) ._,':' 32 ,30 W .~:.'-' ,, 0:3 1 ._, ..' 7.._7 S :32. :E:9 W 0, 4.1 1.587, 16 S 32, ,'50' .' !4 · O. :::': 2 164. 6, 31. C;. 62: .. ,:"i -z .[ 1704,93 :L / .:..,'., :31 · :, 409 62 t,4 S 45:=:. 81 W S 49'?. ~._,':'/" W S ._-,._,. 74 W 5'.:?2, 29 6,38;,'74- . I~ " ': 6o/:;. 16 · . W W W S 10:':: 1.5:--: W S lC~F:O.14 W S i 128.6,4 W S · 1176.94 W · . · .:, · · ... 1.2.';:"3, 39 'W · .:. :... . .. :. :.."~ · . S.: 124'4 ' ~'::'? ' ~ 0...~ W S 126:3. :'--':(] W S 1:301.:31 W S 17:.'_--:9.0/=, W S 1376.. 6'7. W '-' 'i414;'01' W ... c, 14 !':;0.9/.. 14 67 '.-? ,: :.'34 1 ()2:E:. '::? 1 116:-'-'/:. 67 127: :3. :-2:'7 1:3 () 5;' ,, 06 1 :'::'79, 65 1450, 4 4 1 F-.'; 2 :[ ,,:.)'" .::,'- 1:..- .... :;, 1 ,, 40 1 &,61.49 1 '7 ::2,1 i '.:,;' :'::'7 ,, 26 2 (-) ¢-)/-, ":'":' .... ,, -_, 207,:S '""= ,, ..=, ._1 214!5. ':? 4 .,: ii' 14, '::';/-, ·;ii[ '. .. :iii: .2. ,. 1 ,'.':i- ,,--. · :, 14:37..=;2 W r~ .-) -':, c- 1._~ ....70 W S 155'.P. 37 W .,:: 4 i ,.':,. 72 :2482.7:3 i 5'.? 4. Fi :L 1,4 16'29, i,-."'.', W 0 © SPERR"('-:_--;LIN WELL SURVEYING CCd"iI-:'ANY ANCHL]RAGE ALASKA P ,':'~ 13 E ARCO ALASKA, INF:. iY-9 (F;EF: 1 TllIq Rg'E) COMPI_ITATIFIN DATE HAY 6, 19:E:3 DATE AF SI_IRVEY MAY 4., Bi_q~E;F; i}YRCi:E;i-:i-IF'IF: :z;URVEY ,_1 i-I B Iq i_I I"1B E R A K- B C'i - :':: 0041 VEf;;TIC:AI_ SEF:I'II_-II'q CALCI_iI_ATED AI_O.NG C:LOSI_IRE KELLY BLI:~-HI'NL~ t-:LEV,' = ,-.'/A, O0 F'T. IjF ERA'f L R-oAHEL. I'RUE :-gl_lB-SEA I]:I-ILIRSE C:I3 UR'.--;E I-ICli'3-- L El-4 PiEASI_IRED VER'F I C:AL VER1- I C':AL I NCL I NAT I F~N D I REF:T InN SEVER I TY I'OTAL RECTANGULAR F:OORD I NATES VERT I ._.;-~L DEi:'"I-H DEF'TH [IEPTH BEG M I N DEGREES BEG/t 00 ] ] ~=; Z~ ('m~ ~'') 4391 /:.,./:, '-"' =' 66 '"'-' 4.,:..-.~.., 52 ':' '~ ....... · _-,,=. :--;._,=. 69 W 0 ,, 78 ................... I'40F;:TH/:F.;OUTH EAST/WEST .SECT t :2 (') .... 9 :':: 4o' ~'-' ':',_,1 o' 6,=,'-', 30 W '26 '73 ,, 4 5 !"""; 00 446'P, '75 4 :'47:3.7 r-"; 3 ::-': 26 S ':32.60 14 (), 4 :::: .=;6 (') 0 4548 :'::/-, 44. 52 :--:l/~~I :EII7 .=; '= . _ _ .......... , S :32 60 W o.~1 .... '_ .'. H'-' . :_--:7 . !"~; 7 c'~ ("~ 462'7 ,-,,-, 4._ .=, 1 /_-,6 7 '.:; 33 1 'P W O. 88 .';.314 d,. F) 5 ::3 1697. (')0 14 27 :;35. !=;:'4 21 'P:::, 1 :.3 S 17 :::0. :':: 1 14 2"79/_-. 9";' 2 2 4 9.2 7 cE; 17 6:3 , :'::_ '-.-/. W .,:.'-' '-c, ._, =''' -": ,, 4. 5 .: 0, 42 (). ,", .. 1.56' o 100 494- 2.76 4-;-34/-,_. 76 40 27 :3 ._,._'":'.=;, 1 '::>. W 6';:':' 0 ('~ 5018 75 4922. - =; . ....... 7._ 40 :37 S :36. 19 W 6:2: () () '- "':/"" - 49'.'T/7.81 42 ,z. . ..:, t) ~ .:,. b.: 1 4 ._, :2:7 · ! 9 14 :L. 5'::.,2' (] ,, 6'7 1.5:::: · .,4._,:,.:36 :$; J. IpO1 14 14 3102,, 6'...' '? 506. 14 S 19:39, (.'38 W :'416 7. 50 '"' =' .=l ':~ .,:. ..... :.. 10 F; 1978.._~,/-.., 14 ::'.::2::.:..::'"-':./t-8 S'. ,'"L3 - ,. ,, ,, - S 39.80 W'.' 0.94 · . _ . · 26 t.3.02:5 . 2020,'4() W 3:301.70 2A67':q2'S..':: '"''' ' ...... ~0o4,87 W' 3:372. z.,_,'-'° 2723 ~ o: · . .::, 1 /_-,'7C{C~ ._ o74 4/z, ._ ,:7o. 46 48 11 68()() 5440./-,2 .5:'::44. 62 48 5/:, 69 ()() !5 !5 C-~ 6.87 5410.87 4:3 4 S 40.69 W 1.62 S 42.:39 W 1.48 S 4:3.50 W 1.21 44. t0 W ' · 0,94 '-1.4.69 N C-~. :30' 4.4.80' W'.".'... · 0~8'? · . o,_, ;=, .' . ..'-,=,.i 0. = ,.,o W :374 :i ...... · -'... ,,,~ ~ . · ~.,'xr,/. · S '_;"-':.'A t 67 W :3814. 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'2;~;0'0 ............. ~'~].;15. 14 6119, 14 4:2 11 S 46. 0 W O. 8:--: :":::387,81 S '275'P. 65 W 80()c~ 62:3'P. 2::: 61'P:'::. 2:':; 42 11 S 46. 0 W O. 0() :34-34.46 S 280'7.9/.: W ,-', - i:~.--, .-, ~,-, ,::, U._ .~ 6 :.32--':'7 76 62:31 76 4. 2 11 '.B 46 0 W c') ("~ A ........ :,4 .... =,, 7:2 S 2:_=:3:'_::. 08 14 ............................................................................................ I.-iF)F~IZC~N"I"AL. D I::::';F:'L. AC:E"MENT = 4470 91 FEET AT :::;F~II'I'H' .3'~ :DEC; i9 M IN WES;]' .Al! 'M'D =' 80.'=;'.;. ~, . -, -- ,~. .. · ,,~ # ... · ,...~, .:..... · ... . .' · . · . ..'.' . .. ......... "i~i:lE" ([J:'-A'l...'iji}[)l_tJ~i: I-i~i;j:"4'-" [:::TF~i]Ii~:iFIj[..IF:;:E:S ARE BASIFI"I (]1'.1 THE USE [:"iF ...... 'THREE D I MENS I r'INAL RAD I I I::; OF:' r':LII:-,:VA"FLiiRE 44:2.: 6. :2:5: 447(b. 91 ME-i"HCID. iY-'? (SEC 1 ]-llN R'F'E) I'( U I::' A R A L. iq ',:_'-; K A F;F'EF:'(RY-SUN WELL SLIRVEYING E:OFiF'ANY ANCHORAGE ALASKA F ~,-~bE: 4 COMF'LITATION DATE MAY ,.6, 198:3 DA]"E OF :-:;I_IRVEY HAY 4: ._lOB f',tI._IMBER AK-BA-:::.:C)C)41 I<EI_L.Y BLISHtNG ELEV. OF'EI"?AT'OR-SAMEC :::.'/- (),h J:':T II'4"I"EFRF'OI_A'i-ED VAL. LIES FOR EVEN i()C)C) FEE'I-OF i"lr:;.(':~:-'::IjIRED DEF:"I-H '1' R U E S U B - :_:: E A I' I E-" A :~.: I.] F< E D ..... -OE-F'~'T'J'L:.'i:.]:' [ ............. -~'E'~]'-~ C A L D E F' 1" H D E P T H D E F' "1' H TOTAL REE:'F A NGLIL AR COORD I NATES MD-'TVr) NORI'H/SOLITH EAST/WE'ST [~ I F'FEREI',IC:E VERTICAL CORRECT I ON i (:). 0 C) 0. C) 0 (':). 0 C) :::.06 S 4.?1 W (').()2 0.02 287.44 S 212 . ("). I~-~. W ,:,'-' ...i ~ ,, "E: 2 ':"--''--' = ' 79 :q06-- · ,_,..C"--' '.~-- 63~:.~ 74 W 347. ~---"'~ -':':' 261,. 4:1 1._--:13 A':' '-' ... , ..... ;:, I 128, 64 'W 6:37.95 .2'::'~0 7:3 1,'_-375 90 S 1._,~.., 70' W '.:)1:'::: =,:~ . ,. .. ~ z'-" /' ._1 .,.1~, 700 () 55'74 2 ::::: ._ 4- / .::.. 2:':: 800 (). d, 28 'P . :.2:3 d, 19. :::_. ..-"" ..:,'" ........ F::() 5'2 ............ ~i,'.':~f?/: '76 6231. "I"HE r.:::AL. CULATION F'I::¢OCEDLIRES ARE BASEI] ON T'HE ,1. 724.24 t 3.47 ... ILl;=, OF CI-.1RVATIJRF' ME::]"Hf"~i"f, D I ~ I[:.N;:.~ t ONAL RAD' '-' .... ' iV ..... ~.:' (:----;EF: 1 TllN RgE) ~ I<UF'ARUI< E;F'EI-RRY~-SLIN WELL 'SURVEY I NiB CAMF'ANY ANCHORAGE ALAF;KA ' C: 0 H F' U I- A 7' I 0 N D R T E MAY DA]"r-':: ('iF: SURVEY MAY 4., ,JL-.IB I'qI_Ih'IBER AK-BQ-:":-:OA41 "'::: :' .....KELI-Y BUSHING ELEV, OPERATOR-SAMEC I'~T~O~ED"VAL"OES FOF~-E-:'~.EI',I 100 FEET OF :F;U£.:---SEA DEF"i-H 'l-RI.J E SI_ID- ::;EA TQ T AL ...... TqEF.'t-'i..'9,i.]RED--'--'~]'C~A'L- VbR ! 1C'AL ' RECi RNijLIL. AR COORD ~ NATES DEF"T'H DEF'TH DEP'I'H IqOF,"I'H / SOUTH EAST/WEST .............................. ..rT --D. ~.~t.~ ..... !)/-,. ()(.) O. (..)(_) O. '?,-':. ':?/.:,. ()() 0. C)(':) ('). 17 S O. 1 '? H 19/- 19/_-,. 00 1 (') (-), 00 0 · 48 S 0,6:3 N ............ 2 '?,."?:, -- c.';~-'iq-O ]20 0 '-:~'00 '" .... '='"-~ ........ d. 7._, .=, 0'275'-"N :':', !;? 6 :i::'i;;' 6. ()0 :3 ()(). C)0 t. 02 S I. ~ 3 · [4 4'? 6 4 '? 6. ('~_ o. 400.00 1. ._-,'". '='~, ._,'-.:' 'l. :-49 W ........... :'",'-:--~,:':; ~'~:'. 0(.:,- -'~:~ l. 80 S 1.91 W 6';;'A ......... /-,'P6. ()0 /:,0("). (')C) =.'--' :2::::: :::; ~..'-' 6:3 W 7'? 6 7'~6. r) (') 7 c)_ c).. 0 c) ..-.':' 78 ,.E; ":' 40 W ................... 89,.'-':: ....... -'E:'?.-;5/;'OO 800. O0 1 () ? 6 1096.. ~:-:~ (') 1000 ,, 00 ............... I' i' ':?',:!i.' ............ -~"I'":7;::";. t.)(..)T.'I 00, ~..)c) 12'i;;' :.2: 12'F' 6, 0 () 1:2-:: ()(],. () 0 140 :t. 13 ?//:,, C)(") 13 C)0. C) I'iD-TVD D I FFEREI'4CE: VERT I CAL CORRECT I ON ................ O. 00 0.00 <), 00. O. O0 O. O0 0.01 O. O1 0.02 ('). 00 0. 0.00 0, O0 0. O() O, O0 0, ()0 0,00 ...... 150:3 ......... --]:"' .~.':~ ~' 7' 0 (3 ...... 1';~:0'<..,-~.-~_~.')' 1620 1596. ()0 1 '= .... 17:':.':7 169,.':,, ("~() 16()0. O0 TT~F,: oo 4.17' W O. O0 W 0.0:2 O. I0 '0. O0 '(ii o.s,' 2. :3.5 W C). A2 20. :39 W :::4.96 W 1.6:3 :3, 60 t 2. '78' :24 ,, 46 .. 4 i, i'::: 6.9'3 · ~. (;:,,."_', .. ... : 16:. 67' 1/'-,1.44 W 1:3.62 J.:J_Ii;'ARI_IK 0 · =,F c. nl-~ Y--."',LII~ WEI_L Si IRVEY I NG AI',.!F:H CtRA C-~E'_- AL A'.ii;KA L-:CIhiF'LI'TATiON DATE M A Y ,.'::., 1 '/:::::: DA]'E" ('-d:" ::::,i_IIRVE:~" NAY 4, ,_10 B N UI"'I B E R A K-B O- :3 C, 04-1 A L ¢4 F.'; I'::; A KELLY BLISHZNG ELEV,, OPERATOR-SANEE '""" F) f",} ;' .': ....... F-"I", I'RUE INI"ERF'FILA'I'ED VALUE:=; FOR EVEN IC)(-) FEET OF :=;LiB-tSEA DEF'-i"H '._.:; I_1B - :::; E F/ ]" F-I T A L l"i E A S; Ij R-E B ................ 9'~'"'1""~ C A L -- f) E F'"I'H DE F' TH VERTI[;:AL REF:I'ANGLILAR. F:OORDINATES MD--TVD DEP"FH NORTH/SOUTH EA'ST / WEST El I I=FERENCE VERTICAL CORRECT t ON 1 i9'/'? 1 ::: i96.0 <"} 1800. C) (') 277.01 .=, 2102 1 'P 96.00 1900, (:) 0 :=: ::: 6.20 .S 22::30 :2 C)'F,, 6, 0 C} 20,[':) 0,0 C) 4 (") A. :':: 4 S ',:.'::c,u 21""' c,] ":'10'0':-i:¥0 .......... 46S/ :'~::~ S 250() 22'P/'.:.. 00 2"2.00.00 !.542.9? S :26:3'P ':237~6, Cx'-~ 2300.00 617,'58 ::;; 204.02 W 81.5:'3 249. :::4 W 106.47 '=."P 7.91 W 1:34.64 21 · 79 24. 'P:3 2:::. 1'7 351.17 W 167.60 40'-". o~: W .'204.7'I 47i 67 W ';-' ""' . ..:~4 ~ 90 :32. .,¢ (..) · ' ............":. 9 '? 1 ";' ~:: ':)/-, <] 0 .-"-' ._, '=' O' U'. 00 766 .06 S : :3 c).. 60 2 c'-, 96 .00 2600 .00 :--: :37 ,7:3 .:,'-' 5:'::6.76 W 284.82 602 C) 2 W ':".--'.'--', "=' . . ._,.~.-_ . /=.6/:,, 'P7 W ::~ Zl.. 17 40. 40. :'::,~.?. '::;'2 2.'_:: 12 :3200 2796, ~"~,["~, ..... .-7U J,,, ()0 ,T,'cr~' ,14 ..,':' :: ::::.=:4.1 28'::).-S. F)O ......2800. OC} ':?:=:C~, 06 .:.~ :: ..:,'"' 4- ,:,'":' ..:,":' :2 '::;' '.:;' 6 .00 2 '? ()O.. 00 1 O_ ..'":"; .i .21 ;z, ''"' 7.:,.=). !o.. W 804.63 W · . ... 874 ¢/~ ~ .'~..~' l~t 4,04.72 445, 6.i 487,, 06 40.5.4 · " 40., '?0' 41:.'' ' '='4 .., · =, :::, .~ ._, 3 ("~ ':::' 6.0 c'~_ :3000 .00 11 ~'"" ..:,"'"..:,'-' o"" '.:; o'"1-' ~ ! 1,, . . . : ..:, 7 :,,:, 3196 A A 3 ,1. 00. () 0 1 t 95. :30 S : :3 ':? 0 '7 32'P 6. <:) 0 3200.00 126,/:,. 71 S 945.68 W 1015.28 W 108:3.70 W · -,.,: :: 21 .570.71 611. :36 42. 41. 40. :i 4 .51 6.5 4.r}4'"/ :=:3'P6, ("~('~ 3:30c). 00 1.3:37,62 c. 41 ;:', 6 :34'P 6. ~"~ (-~ :3.1. 00., 00 1407.7.1. S · -":',"v: O0 .... '"': .... O0 14F; 4:322 .: ..... ;,: ...... ,=,.:., U 0 t 71 :i217,..16 W · 1272,05 W. :'. 40.. .. 06 ". 1.'"';6P';. A::: 5; 1:325.02 W '766.72 40.54 ./ 1 Y- 9 ( :-':::E r-: i T 111'4 R'i..?E ) i<I_iF'AFi:LII< ::;F'EI-2RY-'.E:UN WELL .=,URVEYING COtJPANY ANCHORAGE ALASKA' F:OMF'UTATION DATE 1"'1A Y 6,, 15'8:2: DATE f]F .:._R'vE,' NAY 4 dOB NLIMBER AK-BO-:3()041 AL. ASEA i<ELLY Bt..oHING ELEV OF'ERATOR-SAMEC TRUF I NTEF:;.:F'OLATED VALILIES FL-iR EVEN SIJB-L:;EA TOTAL 1 (')0 F E E T A F ::2; U B- S E A D E F"T I-'4 VERT I _.~.:~L V ERTI E.~-,L REC:TANGULAR COORD I NATES MD-TVD VERT I CAL DEF:'TH DEPTH DEF'TH NORTH/SOUTH EAST/WEo r D I F"'FERENCE CORRECT I ON '"1. 603 4 7 41 4.:3'7:E: :2:'796. (-)(:) :'-":'7 c) (-). 0 c) 164 :::. 0 ? ::; 1:2:'7'7, :2:1 W :':: 0'7, C):2: :.5:896,. :39'i:"'6.00 :3'F/O0.00 1:2:c)7. .... ~':, S 1479,/::,._, = W :--:82 , :'::/-,_ _ '.5012 4 () ? 6,, 0 () 4000.00 188:3, 01 :!3 ._.'4145 41 'i;' 6, ()('} 4.10,::), O0 1 ':'."'='; ...,.6, :37 S 527,2, 4296,. 00 4200, ()0 2027, 44 S .... !37f.(:fS ....... 7~:7.~i;~T7 oo 4:2,00. oo 34, .5:9 · 32; 68 30',: 88 2C)':7.'6. :39 S 166,5, 19 W 10C)'P. 57 29.26 ..... .:,..:. 4496 A () !566 c) 4596,. (':, 0 ':' ................. ,.~*"~:~'::k ;-; E:':i ,*'*, ._l ........... 4 ¢'t ,---:'**,;/~, ............ ,, ()0 .'"-, ::' :1. 04'796. ()C) ,.5,('} :::1:::: 4. q'-7~/- ()(') ...... ........................... 617 (') 4- 996.00 44. 00. (:) 0 :216:'::. 6, 0 S 45 C) ('). 00 :-';,2' 22':7'. 22 4600.0() 22';-";-".. 27 S 4. 70 C) 00 -.,..::,..,..'""" '= =;, 29 S; 4:::':a.')O, 0() 242:' 1,04 :::; 4900. 00 10:'-.:7. 1064. 51 27.94. 29 26,. 79 17'P1,62 W t E:78'. 43 'W 1089. 1114. 1142. 2490. :::_ 9. S 1927. ._.=; ~., =' W 11 '74. C):3 31. :;-24 6, 5: C):2 5 t'-) 96. (] 0 5 () C)c). 0 C) 6 44 (') 5196. ()() 51 C) 0.0 C) ............. 2-,.<~: 4.' ......... Ts~':¢;z; -'i:';i% ...... R~.,-&5. oo 6732 '='"'"'~ ' · ..;..:, ::- e.. 0 () 5'300.00 ' ""'-" "" '=, 496 '.'] 0 54 (') 0 0 ('~ ~:, 'Z'""'. '-, .... . . .. t* '_ ............................. :::..'560.6,:E: :i; 1979.76 W 1206.9:5 26:35. ('} 8 :i; 2 C):37. :39 W 1244.50 :.32. o":, :37 ~ 55 2714.5C) S 2797.'~'= 6 ,.";4 ..,,,1 2881 ' 73 S 1'7. ,::.d · 73 :L.:, 67 48 ,' :'i. 5 51 ..41 2'5:' 6 C). 7 6, S 2:326,97 W 14:36.07 48. :34 SF'ERRY-F;LIN WELL SLIRVEYING C:Cd,IF'AI~,IY ANRI-..iOF::AGE ALAF;I<A ' DAI"E i-iF- .-'1 I'-'"'-" _ .:,_ nv,-, PlAY 1 Y-? ( S E C i I<UF'ARUI< " ..... AL'ASi(A 1 TllN Fi?E) C:OHF'LITATIF~N F~ATE MAY 6,~ 1'.:..'8.3 ,J F~ B I'.11J M B E R A K- B 0 - :"40041 KELLY::'": Bt, fSH:'tNG :~:ELEV, .=' 96. O0 OPERATOR-SAMEC -~-Tl~~i~T_~':~-t~-'Fl.'-T~.l'-g,~-'.E'.-_:'...']-'; F'Fd::~ EVEN 1(-)0 FEET OF ?:-';LiB-SEA DEF"I"H 'T R t_I 1:' S I_1 B-S E A T 0 T A L H:.F..ASI.1RED. ................. ' ' ' - ~ ............. ........ --~7ERTi CAL ~ ER1 I _.AL REI_:TRNL-,~ILAR IZ:0CIRD t NATES DEPTH DE:F'TH DEP'I-H NCIR'I'H/:.:;OLITH EAST/WE',::;T I"iD'TVD D I FFERENCE VERT I CAL CORRECT I ON / i / / .:,o::,c,(.)(.) ~'1-0'" I-)Ii-) '~''~4(')l(';)'' '~l~";i' W · . ..: (.).'..:,.7,. / L) .":, _ .... 7:31 '~.-/ 57':.-z 6,. ()0 5'700.00 :z: 107.47 S 2472.8 6, W · _ . .-q 'F~7 '-' '.':.'54-:2:. :32 W 7 '.I. 60 5:5:.F.//-, 0 o .5 ::: 00 00 ::: 17 .... :. ----':.~;~:F'-.~-~, ..-,--- -., 4:3 W-- :..' ':'": .. . ---- . .-- .-~ 77:'-'i:7 ~..,~1.,,..,. OF) 6F)00 00 :.:::SlO. :Bt] .:, .-6,:,.). 71 W '7 :-:-': 74 619 A 0 ("} 6100. 0 () .:,.:, 7 ;-:,. 75 'S 2747.17 W ........ 'L'.:-O'()9 .............. ]~::2;i;~"',': uO 620n. nn :34:3::.:. '72 S 2812. :_::'7 W 14 :-'"": 1. :':: 1 152:3.86 · _,~,4. (-)6, 1603.34 1641.68 1678, 17 ' 171:3. 1:3 4.!:";. 24 42.54 40.20 ..:: .':;)'. ,,,,.,...,: ~.,- ~ ,,:, ,_-, # :36. 28 4 'i;' 1724.24 11.11 THE ....::iF:.~Ei'_'~'LTE,'AT'iCiI,;~i-~:E]ffOE~ USE A L I NEAR I NTERF~O'EAT']"O'N'"'BET~--E'~i 'I'HIE NEAREST 2A F'OOT MD (FRL')M :" i '"' ' .. . ' ... . RADI JL-, OF CURVATURE) POIN]"S i"/'-9 (F.';EF': 1 TllN RgE) I-:::I_1F'A R 1_I .... SF'IERF:Y-SLIN WELL SI_tRVEYING (-:Oi4t::'AN¥ ANCHORAI]EALAot~..A~' '""' ' F'AGE 9 COMF'LITAT'Z ON DATE MAY 6, lY:::::: RA'I'E" F'F' '.:::;I_RVI.'---'Y I'""iA't" 4, ,_1 Fi B N El M B E R A K- B F'f - :2:004. J. KELLY BLISHING ELEV, = 'i;.' ,'!-. ,, 0 0 F"F. OF'ERA'DqR--SAMEC I NTERF:'(]I_.(.'~-I-EI] VALL!E'S FOR SF'I.-.'F: I AL '-:.-: LIRVEY F'O i I'..I 'T :-'-'; TF(UI~: I'iEiAS UF:E D ............ ¥%RT'I'[.*;::~E OEF'TH DEF']"H S Lt B- S E A VIFRT ~[ C:A L -- DEF'TH ]"Cf ]"Al_ REC:TANGLILAR COORD I NATES NORTH/SOUTH EAF:]'/WEST I'"IARKEi~ · _, ~ 4.,:..z, ~. .'=;::: 4 C- ..... 766'2 6041. :21 5945.21 7::::30 ........ ~::f'?:,:3 ~'4:h.'-;- ....... ~0;.C'2", 4/.:, 7'il) 00 6215. 14 6119, 14 795() 6252. 19 /.:, 1 ,.,,:.:, 19 :'::: 15:E:. 4:--': :::: · "'~ --~ (" '-)' --7 .:,.,:..) / , / ..:, :::; :2:274. :_::9 S "F OF' I_IF'F'ER ~-'.':AND BASE UF:'F'ER SANfi 'T CfF' L i.-:iW ER SAIqD BAE:E LOWER .=,Al II) SURVEY DEIr:'TH '. PBTD ' ::2: ("):5:2 65:2 '7. '76 62:31.76 · '-..1 ..... :,. 72 S 28:3:3. C) 8 W "FI31'AL OEP]"H I]RILLER _0 0 ARCO AL~'q:;3KA, INC. 1Y-9 (:3EC 1 TllN R'.:./E) . STIRAT I GRAPH I E: E;LINI'"'tAI::.:Y F~EI:-i:IVED LISING iD'Il._ DEPTHS ¢:'~NO ::;PERRY SI_IN SLIRVEY DATA .......... ;_; ...... i l...'~-- 2:,i'Ll ii-~7.., l ........................... : ...... ~ .......... ~ ' .~ ' : ':': ........ ..... :! .... ~ i.~ ~.~..~ ~ ~ ~ ~:~ ;.. L_~._ ...a ~ ~. ~ ................... ; ............................ ...................... I"iARF:ER I¥1EASLIRli:SD [ E.F' ;FH T V D ]' H I Il:t,;:: N E S .L:: BI< B BI.::: B S LIB- ::;E A V E R'f' I C: ~'.', L C O O R D i N A']'E :::; WITH I:?EF', 'i'O WELL. F'iiFF'~D ( 0 R I G I N- 56, 8 F:'N L 12 !"'", 2 l-' b~ L. :3EC: 01 T i 1 N R O'iF,' , , ".=lc, 4.'DS ;--'.'-','..'...,, "'TOF'"'Z.iF'PER'-:~FTND ~;~'[' 5870 I9 .5774 19 Z~i._.:,, ' ....... = 2~5W BASE IJF'F'ER SAND "='""=izod.. 5942, ~,~='5 ~e,,,,.. o~c,, 52 ':'~' '.~=O7, 73S 2575 .6,4W TOF' LOWER S~ND 7662 6041,21 =o*= ..... · ;,.-,+~,, 21 :3274, ::;':~-; 264:3, :3:5W {' ................. BA~T~ER ' SO~ND 7i:::t::( ) .... ;~/':i. ¢-.' :-.:.'"' '~/-, .... 6067 4A '-'"'" =:..: .... 4 .5;'4. S 272F5... 7,5 Ig S I_1R V E Y iD E F' T H 79 ..... 00 6215 14 /-. i i e 14 :3:387.81 c:._. .... ~' ..... / .::,-"::.". (:,' .c,~"' t4 F'B T D 79.50 62.52, 19 6156.1 'P :3411.138 278 :l:. 81 W '.--i=~ ................. .~;~ ...... 6.:,=~, 7~, E, so 1 · 7~; 3458, 72S 28:i::3, 0:3N ....... TOT¢i[/-DEFWH-ORTEE-E'~ ..... -,9'052 · :! .......................... ......... 12'5 ...... I]!i::i-I';i]""i..I-I'El-? I::'l:i:l"'lGF-~('ll;'l --SF'EI:i:Fi:Y ::";UI',I THREE D IMEi',I::";IONAL RAI"~IUS OF CLIF:VA]"LIF:E. iDi::~"l"¢'-'~ CAI.('::I. JL.A]'I O1',-I AND I NTEFtF'OLATI ON BY RAB I I..IS OF CLIRVATI_IRE C'C. iHF'UT(-.Yi" I ON D~TE :'DATE ' OF 'S.LIRVEY · MAY 4.:, 198!3" ':' '7' '." .. u . ::'.. .: . ':. "' :'.' : ' :' MAY ,5, 19:"--'::'"-': .JOB NUHBER (:-',I-:::-BCi-:B(-)C~41 I<ELLY BUL::HIIqG ELEV. = 96.00 FT. I -3000. O0 -2500. O0 I -2000.00 -1500.00 -1000.00 TRUE NOBTH Surface L°cati°nl 568 FNL 1252 FWL| -500. O0 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30041 Well: #1 Y-9 (SEC 0I TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: May 4, 1983 Operator: Samec Scale: 1" = 500' -500.00 1000. O0 -! 500. O0 -2000.00 -2500.00 8052 HORIZONTflL PR(] -3000. O0 3500. O0 JECTION 0.00 ! 000. O0 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30041 Well: #1 Y-9 (SEC 01 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: May 4, 1983 Operator: Samec Scale: 1" = 1000' 2000. O0 3000. O0 4000.00 5000. O0 6000.00 4470.91' @ S 39° 19' W 8052 7000. O0 I 1000.00 2000. 00 3000.00 4000.00 5000.00 VERTICAL PROJECTTON Suggested form to be inserted in each "Active" well folder to check for timoly compliance with our regulations. Operator; Wel_~ Name and 'Number' Reports and Materials to be received by: ~~ Date · Required Date Received Remarks ~ , , Completion Report Yes., Well History Yes .~ ~-~"' . . . .Core Chips ' ,//~/. ~ /~,. · , , . , ' Core Description OK .. Registered Survey Plat y ~%5' . . . _ Directional. Survey., ".y --PI ~ -- ?_ .~'-- ~, ~'~.,' :-- ~ /i.~.:?~ .... ' ' · :'"' ,,F' '-- . ' . Drill Stem. Test RepOrts /,/~(~~.. - , · , . . Production Test Reports y ~...~; . Digitized Data . '~ ~- ~ ~'~,,~'~'- ~ ' d ~. . ,. KUPAF~K BNC I NEER ! bis TRANSM I T FAL # TO: Wi I liam \/anAl en ~,4: D.W. Bose/She Iby J. Matthews DATE: ~' Zr?O ~ . Transmitted herewith are the fol I~ving- P LEASE~~ F-FILM, T-TAPE, PC- R-DTOOOPY E:. - -~-~/.~ ~'L-~. A~: ~E~Y J. ~A~iB~5 - ATO/111 ~ka Oil & Ga~ Cons. CommiSsion P. O. ~X 100360 Anchorage . ~~E, ~. 99510 KLJPAF~i< BkC; I NEERI TRA~ 11-~AL #~ TO: William VanAI en FF~,4: D.W. Bose/She Iby J. Mat thews Transmitted herewith are the foll°Wincj- PLEASE i'~)TE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE PLEASE RE-RJRN RECE! PT TO:" AP, OD ALASI/~A, IF,C. ATTN. D-IELBY J. IVATI'HD,~S - ATO/111 5-B P. O.- BOX 100360 ~E, AK. 99510 ARCO Alaska, Inc. Post Office' Box 100360 Anchorage, Alaska 99510 Telepl-Jone 907 276 1215 May 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska-Oil & Gas Conservation Commission 3001 Porcupine Drive ~Anchorage, Alaska 99501 Dear Mr. Chatterton: gnclosed are the Monthly State Reports for the following wells' 1Y-16 1Y-1 1Y-2 1Y-3 "1Y-8 : 1Y-lO Ravik State #1 2Z-8' Ugnu S3~T #1 West 'Sak ~PT #1 Thank you. Sincerely, District Drilling Bngineer PAV/SH: tw Attachments ·,~--. STATE OF ALASKA , --- ~ ALASKA ~._ AND GAS CONSERVATION Cb 'IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellj~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-52 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20935 UM 4. Location of Well atsurface 568' FNL, 1252' FWL, Sec. 1, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) PAD 67' , 96' RKB 6. Lease Designation and Serial No. ADL 25646 ALK 2577 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Y-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. April ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1400 hrs, 04/15/83. Drld 12-1/4" hole to 2411-'. Ran, cmtd, & tstd 9-5/8" csg. Drld to 4169'. 9-5/8" csg parted @ hanger, repaired same. Cont. drlg 8052' TD. Ran logs. Ran, cmtd & tstd 7" csg. Secured well & released rig ~ 1700 hrs, 4/26/83. SEE DRILLING HISTORY to 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40#/ft, J-55, BTC csg w/shoe @ 2381'. Cmtd w/1000 sx AS II I, & 250 sx AS 7" 26#/ft, J-55, HF-ERW, BTC csg w/shoe ~ 8037', cmtd w/780 sx Class "G" cmt, SEE DRILLING HISTORY 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/FDC/CNL f/8052' to 2381' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Rep~.9~ on this f~p/m is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~uonservatio~ Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate KUPARUK RIVER UNIT 1Y-9 DRILLING HISTORY NU Hydril & diverter. Spudded well 1400 hrs, 04/15/83. Drld 12-1/4" hole to 2411. Ran 60 jts 9-5/8" 40#/ft J-55 BTC csg w/shoe @ 2381. Cmtd 9-5/8" csg w/lO00 sx AS III and 250 sx ASI. ND Hydril & diverter. Install 9-5/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - witness by State. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 11.5 ppg EMW. Drld to 4169. Had the 9-5/8" csg parted @ hanger. Set retrievable packer @ 552' ND BOPE. Repaired surface csg. Cmtd 9-5/8" x 16" annulus w/ 219 sx ASI. NU BOPE. Tstd csg to 1000 psi. Drld to 8052 TD (04/24/83). Ran DIL/SFL/SP/GR/FDC/CNL logs f/8052 to 2381. Ran 205 jts 7" 26#/ft. J-55 HFERW BTC csg w/shoe @ 8037. Cmtd 7" csg with 780 sx class "G" cmt. Instld 7" emergency slips & packoff & tstd to 3000 psi - ok. ND BOPE and installed tubing head. Displ well w/diesel. NU master valve & tstd to ~000 psi - ok. Secured well & released rig @ 1700 hrs., 04/26/83. HILL/DH14 05/13/83 ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1983 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Y-9 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. complete this well with our workover rig. Verbal approval for this work was received from M. Minder. you have any questions, please call me at 263-4970. Sincerely, /J. ? B.~/Ke. win / Area Drilling Engineer JBK/GRU3L 1: sm Enclosures We propose to If Oil Gas Conu; Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION CL,,~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-52 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20935 4. Location of Well Surface: 568' FNL, 1252' FWL, Sec. 1, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) qG ' RKR 6. Lease Designation and Serial No. ADL 25646 ALK 2577 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-9 11. Field and Pool Kuparuk River Fie]d Kuparuk River 0il Pool 12. 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 I~X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] , [] Other I~X Pulling Tubing [] Pull 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 complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-i/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: May 5, 1983 Verbal approval was received on May 5, 1983, from M. Hinder, AOGCC. Work. l~eported 14. I hereby/~ that the foregoing is true and correct to the best of my knowledge. Signed /Z~/'~ ~,~ The spac w mis on use Conditiorfs of Approval, if any: Title Area Drilling Engi~neer Approved by ~ L~HHi£ ~,. $i~iTII COMMISSIONER Approved Cop~ By Order of the Commission Date Form 10-403 Rev. 7-1-80 GRUB/SN1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TRANSMITTAL TO' William Van Allen DATE' FROM: D.W. Bose/Shelb~v J. Matthews Transmitted herewith are the following' PLEASE NOTE' BL BLUELINE, S - SEPIA, F - FILM, PC - PHOTOCOPY q EPT ACKNOWLEDGED' RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN- SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 MEMORANDUM State of Alaska ALASka& OIL AND GAS C~)NSERVATION ~[JhilSSION TO: C. terton DATE: Apirl 21, 1983 T~: Lop~uie C. ~tth ~ Corn. mi s s i one r FROM: Bobby Petooleum Inspector TELEPHONE NO: SUBJECT: Witness BOPE Test Dn ARCO's 1¥-9 Sec. 1, TIiN, R9E Permit #83-52 Sunday, April 17, 1983: I traveled this date to Prudhoe Day ~_: ~i--tff~~i the ~PE:test on ARCO's 1Y-9. The test began at 2:30 p.m. and was concluded at 4:30 p.m. As the attached BOPE test report shows, the check valve failed. This is to be repaired and the AOGCC office notified.~ In sumr~ry, I witnessed the P/OPE Test on AY~CO's 1Y-9. Attachment: I vms notified by Bob }~ewnmn, that the check valve was repaired and tested. 02-001AiRev. 10/79) N'~'A'l']~ U~' aL~b~'N ALASKA 0.~'-'~: GAS (DNSERVATION C~SION B.~.P.E. Inspection Report Location: Sec / T//~R Location, General_ Well Sign Ceneral Housekeeping ~eserve pit ~ BOPE Stack "ITest Pressure Annular Preventer.. / ~ ~ ~ ~o~o Choke Line Valves / ~.c.~. Va~- / · Kil 1 Line Valves. . ~ Check Valve / ACCUMULATOR SYSTEM Full Charge Pressure_~/z3 0 Pressure After Closure/~-Z~ 0 Pump incr. clos. pres- 200 psig Full charge Pressure Attained: Controls: Master dFC_5 psig psig -- min~ sec. /n min/~ sec. psiq Remote L,,~. ~ / Kelly and Floor Safety Valves Upper Kelly. / .Test Pressure _~0~ Lower Kelly /.. Test Pressure Ball Type /. Test Pressure.~ Blinds switch cover Inside' BOP. / Test Pressure Choke ManifoldC~ ~ Test Pressur~ No. Valves ~ ' No. flanges ~ AdjuStable Chokes / Hydrauically operated choke / ., Test Results: Failures .... '" '/ Test TimeL~~_hrs Repair or Replacement of failed equipment to be made within. ~ days and Inspector/Ccmmission office notified. __'/~,-/2 '- ' · ' ~ ' Distribution orig. - AO&GSC cc - Operator CC - Supervisor [.~arch 18, 1983 ~r. Jeffrey B. Kewin Senior ~ '~ ~rliling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 ~ae~ Kuparuk River Unit 1Y-9 ARCO Alaska, Inc. Permit No. 83-52 Sur. Loc. 568'~L, 1252'FWL, Sec. 1, Tll~.], RgE, UM. B~ole Loc. 1089'FSL, 1494'FEL, Sec. 2, TllN, R9E, ~. Dear Mr, Kewin. Enciomed i~ the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log infor~mtion shall be submitted on all ~ ~ogs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing Operations you may be contacted by the Habitat Coordinator's Office, ~partment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, ~rticle 7 and the regulations promulKated thereunder (Title 18, Alaska AdministratiV~ Code, Chapter )0) and by the Federal %~ter Pollution Control Act, as amended. Prior to co~ncing operations you may be contacted by a representative ofc~e'~ Department of Enviromm~ental Conservation. To aid us in scaedulzn~ field work, please notify this office 24 hours prior to commencing installation of the blowout Mr. Jeffrey B. Ke~in Kuparuk River Unit 1Y-1 -2- March 18, 1983 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. %~ere a dlverter 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~r~ truly y~ours, C. V. Chatterton ~'¥ ~D~ 0~ Chairman of ~ Alaska Oil and Gas Conservation Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o encl. be ARCO Alaska, Inc. ~' Post Office i.._.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Harch 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1Y-9 Dear Mr. Chatterton' Enclosed are' o - An application for Permit to Drill $100 application fee. Kuparuk 1Y-9, along wi th a Alasim Oil & Gas Cons. Commissior~ AnchoraEle o A diagram showing the.proposed horizontal and vertical projections of the wel-lbore. o A proximity plat. o A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. ARCO Alaska, Inc. is a subsidiary of AtlanHcRichfieldCompany 0 Since we estimate spudding this well on April 2, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG2L32:sm Attachments STATE OF ALASKA '--" ALASKA O,L AND GAS CONSERVATION CO~,,~vllSSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLEMULTIPLE ZONE ZONE [~X[~"~r,,,~-" 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 568' FNL, 1252' FWL, Sec. 1, T11N, R9E, UM At top of proposed producing interval @ Target: 6052' TVD, 1320' FSL, 1320' FEL, Sec. 2, TllN, RgE, UM At total depth 1089' FSL, 1494' FEL, Sec. 2, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) PAD 67', RKB 96' 6. Lease designation and serial no. ADL 25646 ALK 2577 Kuparuk River Unit 10. Well number 1Y-9 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 15. Distance to nearest drilling or completed 1Y-lOwell 60' ~ surface ~feet 18. Approximate spud date 04/02/83 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi. NW of Deadhorse miles 1089' FSL ~ TO feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8141' MD, 6342' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT1000 feet. MAXIMUM HOLE ANGLE 45 oI (see 20 AAC 25.035 (c) (2) 2 ¢,b, 1 psig@ 80OF Surface '~¢108 psig@ 5902 ft. TD (TVD) ZI 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" 65# H-40 PEB 80' 29' I 29, 109'l I 109' ±200 c.f. 12-1/4" 10-3/4" 45.5# K-55 BTC 41' 29' 29' 70'I 70' 900 sx AS Ill & 12-1/4" 9-5/8" 40.0# J-55/ BTC 2228' 70' ~ 70' 2298'1 2200' 250 sx AS I HF-ERW 8-1/2" 7" 26# K-55 BTC 8113' 28' I~ 28' 8141'116342' 344 sx Class "G"extended. -- 22. Describe proposed program : 335 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8141' MD, (6342' TVD). 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 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2641 psig. Pressure calculations are based on latest reservoir pressure data. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job, 1Y-10 will be 60' away from 1Y-9 (~ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ 2559' MD, approximately 500' MD 23. I hereby certify that the foregoing is true and correct to the best of my knowledge above top of West Sak Sands. The space use CONDITIONS OF APPROVAL Samples required []YES Permit number Form 10-401 Mud log required [-]YES Approval date Directional Survey required [~YES I-]NO APl number 5o-o ~-~-~-z SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission Submit in triplicate : . Surface ~ive.[ter Sy.s~em !. 16" - 2000 psi TanKco starting heat. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double stuUUed a~apter. ¢. 20" 2000 psi drilling spool w/lO" side ou,t,! ets. 5. 10 ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatical ly upon closure of annular preventer. 6. 20" 2000 psi annular'preventer. · 7. 20" bell nipple. · Maintenance & Operation 1. Upon initial insi:allation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines 'ever7 12 hours. 3. Close annular preventer in the event-that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor ANNULAR PREVENTER 9 BLIND RAMS ! PIPE RAMS 7 t DRILLING '1 PIRE RRMS m · CSG -~-'~'7~ - HD · k I ) L 15. OiAGRAM ..-'1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16'; - 2000 psi Tankco starting head 2, 11" - 3000 psi casing head 3. 11' - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" - 5000 psi pipe rams $. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-$/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams .g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. L'HECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT· THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE, 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. ,CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. '- S. INCREASE PRESSURE TO 1800 PSI ANO HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES, BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS, 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANOPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. k T ? :~:!NULAR ~ -,:: .: ~.NTER i! _ ) BLIND RAMS'. I0 PIPE ARMS '~, 9 ( DRILLING SPOsOL · 3 ') HD D IAGRAN m2 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16~' - 3000 psi tubing head 4. 7-I/16" - 3000 psi x 11" - 3000 psi doub)e studded adapter 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spoo! - 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 9. 13-5/8" - 5000 psi pipe rams 10. 13-5/8" - 5000 psi blind rams 11. I3-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUIO. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3, OBSERVE TINE THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4, RECORO ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONOS CLOSING TIME ANO iZO0 PSI REJ~AINING PRESSURE. 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT' ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT ANO SEAT Itl WELLHEJ~). RUN IN LOCK DOWN SCREWS IN HEAO. 3. CLOSE ANNULAR PREVENTER AND_CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. S. INCREASE PRESSURE TO 18_~_00, PSI AND HOLE FOR MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. ?. INCREASE PRESSURE TO ~0~0~_0 PSI A,NO HOLD' FOR I0 NINUTES. - 8. CLOSE VALVES OIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSt OOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAHS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANOPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 1S. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. LOCATED IN PROTRACTED SEC.I,TWR lIN., RGE...9 .E.3 U. MIAT .MERIDIAN. J , RESERVE PI'I: .., . , RESERVE PIT PHASE II · : . _ ~ j= 60' TY P..STAKEOUT RESERVE*PIT RESERVE* PIT 380' 9. Y=5974755.55 X= '5309 ;~1. 60 LAT. 70°20'31.5137". LONG. 149° 4 4' 56.599" 568'FN L , 17.52' FWL Y-' 5974 755.3? X= 530861.81 LAT. 70o2.0. 31.5163" LONG. 149044'58.345" 568' FNI~, 1192' FWL I I,' Y= 5974755. 40 X-' 530801,57 LAT. 70°20'31,5190'' LONG. 149°45'00. 105" 568' FN L ~ 1132' F~V L 12. Y= 5974755.31 X= 530741.58 LAT. 70° 20' 31. 5206" LONG. 149°45' 01.858" 568' FNL ~ 1072' FWL. 13. Y= 5975115.63 X = 530741.64 LAT. 70°20' 35,064:F" LONG. 149° 45'01.813" 207'FNL, 1074~ FWL 14. Y='5975115. 61 X= 530801.96 LAT. 70 o 20' 35.0621" LO NG. 149° 45'00.050" 208' FNL, 1134' FWL , PHASE I SURVEYOR SURVEY I D.S./~ VICINITY MAP Scole': I"=lmi. NOTES: I. ALL Y & X 'COORDINATES ARE ALASKA .STATE PLANE~ZONE 4. '2. DISTANCES TO SECTION LINES ARE GEODETIC, 3. SEE REF. DWG. 22988, SHT, 7Y'I2'3OOI~REV. 7A. 4. DRILL SITE AND Y e~ x COORDINATES ARE BASED ON MONUMENTS I,Y WEST AND I.Y MIDDLE BY LHD A'~SOClATES. CERTIFICATE 15. Y=5975115.5i X= 53086 I.,3_7 ,, LAT. 70020 ~5.0587 LONG. 149°44' 58.$15" 208' FNL~ 1193' FWL 16. Y=5975115.36 .' X= 530921.68 LAT. 70° 20'35.0547'' LONG. 149°44 '56. 552" 2:08' FNL,1254'FWL tlllllJlll e·l~ lilll llllgltllJ drawn by ' J.B. / D.E dwg. no. NSK ~ , date' FEB. 1983 scale' I":~00' D.S. IY CONDUCTORS AS. BUILT LOCATION PHASE I i ARCo Alaska, Inc. Kuparuk Project North Slope Drilling I.HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN ,THE STATE OF ALASKA, AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION, AND THAT ALL.DETAILS ARE · CORRECT AS OF JANUARY 30,1983. I i CHECK LIST FOR NEW WELL ?ERMITS Company Lease & Well No, ~, ~:, ~!, / '"~ ' ITEM APPROVE DATE ..('~ thru 8) ('9 thru 11) (4) Casg ~~./~ ~- 7~-~ (12 thru 20) (21 thru 24) e 10. 11. 1 Is the permit fee attached YES NO REMARKS 2. Is well to be located in a defined pool ............... , .......... 3. Is well located proper distance from property line ............... 4. Is well located proper distance from other wells .................. '.. 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat ~~ !i.. iiiiii (~~ 7. Is operator the only affected party ........ ~ ~ [ '8. Can permit be approved'before ten-day wait .~ ........ ] '] .' .... Does operator have a bond in force . . . f~ Is a c°nservati°n °rder neededIs administrative approval needed .... ,iiiiiiiiiii,ii{iiiiii{ii{iii,iiii{ ~~f...-~'' 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ............. o~ ~l~;~'~' a~ ''''' '''~ Is enough cement used to circulate gg~gg --,-,,-,- Will cement tie in surface and intermediate or production strings ... Wil Wil Wil Is Is Is 1 cement cover all known productive horizons ..................... 1 surface casing protect fresh water zones ....................... 1 all casing give adequate safety in collapse, tension and burst.. this well to be kicked off from an existing wellbore ............. old wellbore abandonment procedure included on 10-403 ............ adequate well bore separation proposed ........ ................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~O psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. ~ _ Additional Remarks: o Geology: Engi~e~ng .cs ' EW '~VA ~ JK~_~HJH rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. .o UqP 010.}i02 VER1F.ICA'FIL][,, 1. I5'I'1.1',{; PAGE I ~, 'rAPE ;-tEADg[; $1~:R¥1CE i'~AMg DATE : 83/04/29 TAPg NAI~.'I~ ~82 C]NYI' ~IIATION ~ PRE V I LIU5 TAPE COt~tENTS :LISRAR~ :$FRVIC .~t FILE ;4EADER F 1. [,g NAME :SEIaVIC.001 SERVI2E NAM£! : VERSION DATE : MAXIb~UM I.,ENGTH : 1024 FILE T~'P~J : P R E V ! t) {,I S .,. INF'[tR, M~II. ON RECORDS CN : ARCU ALASKA FN : t~'UPARUK RAN(,,, 9E ~{~N. llN SEC t' ~ 1 COl N: N. SLOPE S ~A m ALASKA CIRY. USA U N 'l T TYP~: 000 000 000 0 () 0 000 0 t) 0 000 000 00 o CATE 0 CO 000 000 0 o 0 000 000 000 o00 o00 S.IZE 016 004 008 O02 004 002 008 00~ 00 065 O65 O65 065 O65 065 O65 065 O65 l..,vP t.tO.~.~02 VEIq.I.t~'ICA"I~it)N L,.LS'I'.ING Pt~GE 2 ~,Ebh = !,'I ELD = COtJNT'~ = STATE = dOB N[J~BER /~T gCC: 6~211 ~[1~ ~l~ DhTI'~I hOGGED: 24 APe 83 [,DP1 d.[~'~ ~OtiRING CASING TYPE FLHID [~tir 8tgv: = DS[S1. TY = 10.3 I.,B/(; Vl. SCOSITi = 37 S PH : 9,5 NATRI~ S,~NDSq'[]NE: 2 138 3 ' R~ = 4.200 0 74 DF RF~,F = 4.470 ~ 74 DF RMC = 2.77~ (a 74 DF R~ AT SBT = '2.194 (a 1.48 DF DATA FOIq~I/~T RECORD ~*~ ENTi{ ¥' E UOCI~S TYPE SIEK IqEI::P .'/!l)F EOTP¥ 4 1. 66 1 8 4 73 6,0 9 4 65 .1 .l ~ 0 I ~,, 6 0 SPEC I:FICATI£IN 6L(JCI~,5 SERVICE SER¥I. CE [INIT APl AP1 AP]: APl FILE SIZE P[IOCE'SS SAMPLE REPR 1D ORDER ~ LOG TI/'PE CLASS D E P T F 1' 0 0 0 0 0 4 S F L U D l h O .~.'] ~ N 7 0 0 0 0 4 I l,lq D l L I.J:Ht~ N 7 O 0 0 O 4 I. b g O 1 L U ~ ~.~ N 7 12 46 0 ~ 4 S P D 1 L ~V 7 I 0 0 O 4 GB l..) lb 6 A.P. 1 7 3 ~ 32 0 0 4 N P H .l F O iV P it: 42 6 ~ 2 0 0 4 DRI.{U FD~ 0 0 0 4 R HOB FDN I 0 0 4 ~ P 8 4 0 4 N C N [, FD N ,." 2 .3.4 92 0 FC t~ L ['1) N CPS': 42 34 93 0 0 4 CaLl EDN IN 42 28 3 0 0 4. I,.~EVE[~ CODE 0 1 08 0 I 68 0 I 68 0 'l 68 0 I 68 0 I 60 0 I 68 0 1. 68 0 I 68 0 1 68 0 I 6:8 0 I 68 { l.,V[:' 010.1t02 VgPll~ ICt~T.I. UN LI,5'I:IN3: pa, GE 4 NHAT F" D ~',~ 42 P 1~) R A 1:'1) N 42 31 32 o 0 42 I 0 0 0 (; 0 0 4 0 4 O 4 0 1 68 I 68 1 68. ,~ L) AI'A *-~ DE:PT ~084.00C0 SFL, U 8P 32.0 )0(1 GR DE, PT 8000.0000 LSFLU SP -8.0547 GIR G[,~ 1Dl.Ob25 NRA7 DEPT '7900°0000 5FLU 8P -79. 2500 GR RbCi6 2,3555 NCr~L GI4 92,2500 NRA'I DEPT 7800.0Of O SFLU SP -4~.5625 GR Rht.~ 2.38(9 NCNI, Gl4 9().31 2.5 NRA'[ DEPT 7700.0000 SKI U SP - 109. 2500 GR R h t,.l B 2.30 ( U N C N L GR b 1.2500 NRA'.I~ D,~J[.:T 7~00.0000 ~FLU sp -23.1562 . GF 7 I I 250 I,)EPT 7300.00(]o SFLLJ 8P -19.1.562 GR R.HOB 2 3379 'NCi~L G'R 128:62.5o naA~ I)EPT 720C .00( {] S P - 23.6719 G 3.2656 I'i.,N 82.1875 NPiil -999,2500 FCNL -999.2500 ~N~A 3.36"12 I 1',~.'1 I D1.0625 NPi~I 21 7( .00O0 3.16~0 21~629 II,,,~ 92.2500 NPhl 1912)(0(0 3,834o 5.0391 l[.~ 90.3125 NPhl 240~.0000 FCNI, ,3.1133 bN~A 21 . 8906 1[,~ 61.2500 NPHI 3204.0000 FCNL ~ .9453 8.1o41 II,M N P H l 2.7520 I~ ~ }'",h 2 t2.4375 1 L 90.2500 ¢i P ~t I 3.1934 ILO -999,2500 DRBU -999.2500 CALl. -999.2500 2.9531 I[,['~ 35.0098 DRHO ~10.5000 CA[,I 3.5527 2.8809 46. 0938 DI4HO 4,~1 .; 500 C/~LI 4.3320 a.63,28 3.0000 ,3.5156 25.640~ 31 . 3965 994.0(,100 CALl 3.2227 7.4141 I L D 2 '7.6367 L) [~ 14 [I 91 O. 000:0 C.A l., I 3. 0000 1.1. 9844 l.z" 92, 0000 2.5078 I . 9814 [I B[ 4.3. bO 35 DFHO 42 ! · 0:000 C A I., 1 4. 2422 2.37,30 !113[ 40.0:391 b R},t [') 7., 50 O 0 C A l'., I 3.8672 3. 7891 Ibl') -9gq . 2500 2.916o -999.2500 8.7500 2.8223 0.0669 10.1953 2.8047 0.0703 ll.lOle 4.531 3 0. 0068 10.7188 23,0156 0.0156 9.89(.)6 7.2070 0.0008 10.5703 12.7266 -0.0015 10.593g 1.9385 0. 0029 1, 0.6 172 2.343~ 0.0'1,81 10.'[828 3.6211 -999.2500 90.2500 DEPT 1:100. uO0 D SP -10.6250 ( F~ 379.5000 DEPT RHU5, -999,2500 Gi.~ 95.6250 DEPT 09 )0.0 )0{) SP 11~ .4375 GR RI-If)& -999.2500 NC. Nb GR 136.8750 NDt ] DEPT 68 )0,0 )00 S SP 1~(., 656 3 RHt)B -999. 2500 NCNB (;1~ 92. 4375 N l:-ti DEPT bT30.O)O0 SP -1~ .8594 R. ROB -999,25(.)0 NCN6 GR 104.8750 NRI I DP.;PT 66 DO. O 300 SFLU RHOB' -999. 2500 NCNI.., Gt'~ 131,2500 Nal SP D t3 P'r 0 E P T 6.3)0.0)00 SFLU · ~5 · I 328 GR 99 , 2500 NCi'.!L i 37.50¢10 NRt 'I' 62 ~0.0)00 SFLu 20,6563 (JR -999,~50o NCNL 156.0000 i'~ H t 'l 61 )0. O )('t0 SFLU -999.P50r) -999,250o 4.0)0fi 1LF; 379,5ono NP[4I -999.2500 I" ~.l~ t, -g9'g,25n0 ,F ~[-; b 6.0625~ ,IL, N 95 ;( 250 NFk! I -999.2500 f .'NL -999.2500 [~NRA 1,9346 l,[,~ 1.36,8750 NPHI -999.2500 ~CN6 -999,2500 RM~A 6 . 7461 1 L 92.43'7,5 NPH1 -999 . 2 _.500 -999.2500 RN~A 5.4727 1. L~ 104.875n NPHI -999.2500 fCNI, -999.2500 RNRA 2.4902 IL~ 13 1.., 2 5 ( 0 N P i4 'I -999,2500 I~ ,,NI, -999. 2500 [~NRA N P l.,t I -999.2 500 F -9:'99-'250:fl NPF~ 1. -999.2 500 '999.250:0 : :RNR~ I . 6 240 11, ~1 -9~9.2500 CALl -999.2500 3.484'4 'q9~ .2500 :[.NFO '999.2500 CALl -999.2500 3,5%69 1LD -99c..2500 '[NkU -99q.2500 CAI,.] -9q(. .2500 1.8379 ILl') -ggg.: ~5( 0 I.)RHO -999.2500 C %I,I -9gc. .2500 ,4.6:]28 Ik.P -99q.: B( 0 DRFiO -999.2500 C ~,I., ! -99~ .2500 4.. 2227 l L,D -g9g.~5( 0 DF:MU -99c~.2500 C -99~ .~500 ?.49~2 ILD -99q.~5{0 -999.2500 CaLl, -99S.2500 1,6875 II,,D -99q.~'~( 0 DRHG -ggq.2500 C. ~,L ] -99S. 2:500 3.228:5 16 D -_999.~B( 0 DRHCi -999.2500 C ~,t,,iJ, - 99S .2500 3.5156 I IZ Iq '999.,5 51( 0 -q99.2500 C -qgs .2500 2.8223 1 I., D -999.2500 C -99S. 25()0 t .6875 16D 10.78 1 3 3,315) ~99.2500 10.8203 3.4531 ~99.2500 11.8516 1.7207 -999,:500 11.5781 5,05O8 -999,:500 11.0938 4.2344 -999 ,; 500 12.18'75 2.511? -999.:500 11.1172 1. 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