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Home My WebLink About183-1151. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8787' Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/4/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com 8727' 107'107' 8756' 79'16" 9 5/8" 7" 2514' Length TVD Burst 8381' MD 2187' 6311' 2543' 6332' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025652 183-115 P.O. Box 100630, Anchorage, Alaska 99508 502920993-0000 ConocoPhillips Alaska, Inc. Kuparuk Riv Unit 1F-11 Kuparu River / Kuparuk River Oil COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 5928' - 6127' Perforation Depth TVD (ft):Tubing Size: 8200' - 8500' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7506 CAMCO HRP-1-SP /Baker FB-1 CAMCO TRDP-1A 8082', 5852' / 8360', 6032' 1799' MD 1696' TVD Size Authorized Signature: 7/18/2021 3 1/2" Perforation Depth MD (ft): J-55 m n P s 66 t y t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:50 am, Jul 06, 2021 321-335 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.04 13:02:20-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter X SFD 7/6/2021 SFD 50-029-20993-00-00 VTL 7/14/21 ext conductor DSR-7/6/21 X 10-404 Photo document pre and post extension JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 11:32:49 -08'00' RBDMS HEW 7/14/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 03 July 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KUP 1F-11 (PTD 183-115) to extend conductor. Summary: Conductor has subsided or well has grown 7” or more so we would like to add conductor to cover the surface casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.04 13:01:51-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Conductor has subsided or well has grown 7” Casing Strings Casing Description CONDUCTOR String O... 16 String ID ... 15.060 Top (ftKB) 28.0 Set Depth (f... 107.0 Set Depth (TVD) ... 107.0 String Wt... 62.50 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 9 5/8 String ID ... 8.835 Top (ftKB) 29.5 Set Depth (f... 2,543.0 Set Depth (TVD) ... 2,187.0 String Wt... 40.00 String ... J-55 String Top Thrd BTC Casing Description PRODUCTION String O... 7 String ID ... 6.276 Top (ftKB) 29.1 Set Depth (f... 8,756.0 Set Depth (TVD) ... 6,310.6 String Wt... 25.00 String ... J-55 String Top Thrd BTC Tubing Strings Tubing Description TUBING String O... 3 1/2 String ID ... 2.992 Top (ftKB) 27.3 Set Depth (f... 8,381.2 Set Depth (TVD) ... 6,046.3 String Wt... 9.30 String ... J-55 String Top Thrd EUE8RDABM Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 27.3 27.3 0.16 HANGER FMC TUBING HANGER 3.500 1,799.2 1,696.4 38.79 SAFETY VLV CAMCO TRDP-1A (Locked Out Flow Tube on 4/28/94) 2.812 8,059.0 5,837.7 51.03 SBR CAMCO OEJ SBR 2.813 8,081.6 5,851.9 50.86 PACKER CAMCO HRP-1-SP PACKER 2.867 8,194.0 5,923.5 50.04 BLAST RINGS QUADRA SEAL BLAST RINGS (3) 2.867 8,358.1 6,030.9 48.27 LOCATOR BAKER LOCATOR SUB 2.992 8,359.7 6,032.0 48.25 PACKER BAKER FB-1 PACKER 4.000 8,362.4 6,033.8 48.20 MILL BAKER MILL OUT EXTENSION 4.000 8,374.7 6,041.9 48.02 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,380.4 6,045.7 47.93 SOS BAKER SHEAR OUT SUB 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Description Comment Run Date ID (in) 8,059.0 5,837.7 51.03 PLUG 2.81" MA-2 PLUG 12/25/2011 0.000 8,640.0 6,226.6 43.76 FISH 33' PERF STRIP LEFT IN HOLE AFTER PERF 1/23/1983 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (sh...Type Comment 8,200.0 8,304.0 5,928.2 5,996.0 C-4, 1F-11 10/21/1983 12.0 IPERF 120 deg phasing; DA 5 csg guns 8,434.0 8,442.0 6,081.9 6,087.3 A-5, 1F-11 1/23/1984 4.0 APERF Zero deg. Phasing; 2 1/8 BarKone II DA 8,460.0 8,500.0 6,099.7 6,127.3 A-4, 1F-11 1/23/1984 4.0 APERF Zero deg. Phasing; 2 1/8 BarKone II DA 8,460.0 8,500.0 6,099.7 6,127.3 A-4, 1F-11 6/17/1984 2.0 RPERF 90 deg. Phasing (Reperf); LinkCone Notes: General & Safety End Date Annotation 9/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 9/13/2010 NOTE: Injection mandrel @ 8322 - Pulled severely eroded CV in 2 pieces 10/13/99, left empty. 6/9/2012 NOTE: Repair SC w/ 10" .400 wall 45.5# x 65 pipe from bottom of 9 5/8 starter head to 18' (OAL=18') Comment SSSV: LOCKED OUTWell Config: - 1F-11, 4/25/2013 6:45:52 AM Schematic - Actual TD, 8,787 PRODUCTION, 29-8,756 FISH, 8,640 APERF, 8,460-8,500 RPERF, 8,460-8,500 APERF, 8,434-8,442 SOS, 8,380 NIPPLE, 8,375 MILL, 8,362 PACKER, 8,360 LOCATOR, 8,358 INJECTION, 8,322 IPERF, 8,200-8,304 INJECTION, 8,188 INJECTION, 8,122 PACKER, 8,082 SBR, 8,059 PLUG, 8,059 GAS LIFT, 8,003 SURFACE, 29-2,543 SAFETY VLV, 1,799 CONDUCTOR, 28-107 HANGER, 27 Annotation Last Tag: SLM Depth (ftKB) 8,554.0 End Date 12/10/2011 Annotation Rev Reason: DRILL DEPTHS/DATES, CSGS Last Mod ... osborl End Date 4/25/2013 KUP KB-Grd (ft) 29.01 Rig Release Date 9/19/1983 Annotation Last WO: End Date 10/29/1988 1F-11 H2S (ppm) Date Mandrel Details S... N...Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com... 1 8,002.5 5,802.7 51.44 MERLA TMPX 1 1/2 GAS LIFT DMY RM 0.000 0.0 5/31/2004 2 8,121.7 5,877.3 50.57 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 11/8/1988 3 8,187.7 5,919.4 50.09 CAMCO KBUG 1 INJ CV BEK 0.000 0.0 10/13/1999 4 8,322.1 6,007.5 48.82 CAMCO KBUG 0 INJ EMPTY None 0.000 0.0 10/13/1999 See Note ... TD Act Btm (ftKB) 8,787.0 Well Attributes Wellbore API/UWI 500292099300 Field Name KUPARUK RIVER UNIT Well Status INJ Max Angle & MD Incl (°) 55.35 MD (ftKB) 7,600.00 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re 2 / DATE: Tuesday,June 28,2016 P.I.Supervisor Ked, 71 J1 la SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1F-11 FROM: Johnnie Hill KUPARUK RIV UNIT 1F-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J. 2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IF-11 API Well Number 50-029-20993-00-00 Inspector Name: Johnnie Hill Permit Number: 183-115-0 Inspection Date: 6/21/2016 Insp Num: mitJWH160627111752 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well1F-11 Type Inj N' TVD 5852 ; Tubing 800 940 , f 940 - j 940 - ! PTD 1831150 - Type Test SPT ITest psi 1500-I IA 125 1810 - 1780 - 1770 - Interval 4YRTST P/F P ,i OA 1 11 - 13 13 - Notes: 1.9 bbls diesel used SCANNED NOV 2 2 2016 Tuesday,June 28,2016 Page 1 of 1 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation available for this individual We]] History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ¡$3 1/5:e1l History File # Digital Data Added to LaserFiche File CD's - # Yes No DVD's - # Yes No Diskettes - # Yes No Oversized Material Added to LaserFiche File Maps # Yes No Yes No Yes No Mud Logs # Other # General Notes or Comments about this file. If any of the infonnation listed above is not available in the LaserFiche file, or if you have any questions or infonnation requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 OCT 0 9 2012 ANCHORAGE, ALASKA 99510 -0360 AOGCC October 5, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission + «� 1.. \f � ' 333 West 7 Avenue, Suite 100 l t' 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 in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.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, /4 177 Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/05/2012 1D,WSW,IF,2F,2L,2T,2Z,3G,31 & 3M 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 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 10-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 c..-> 1 F -11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 7'5" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other p SC Repair Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re- enter Suspended Well ❑ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ p 183 -115 3. Address: Stratigraphic ❑ Service 151 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 N. 50 -029- 20993 -00 r In 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' _ p 1F 8. Property Designation: - g Wt 6Q 1 ,4 t 10. Field /Pool(s): LoV.Ss‘S Kuparuk River Unit Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8787' feet true vertical 6333' feet Plugs (measured) Effective Depth measured 8787 feet Junk (measured) true vertical 6333 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 107' 16" 107' 107' 1640 630 SUR. CASING 2434' 9 -5/8" 2543' 2188' 3950' 2570 PROD. CASING 8647' 7" 8756' 6311' ry 4980' 4330 Sleeve 18' 10.75" .400 wall 45.5# D JU 7 �� Perforation depth: Measured depth: 8200 -8304, 8434 -8442, 8460 -8500 RECEIVED true vertical depth: 5927 -5996, 6082 -6087, 6100 -6127 JUN 1 9 2012 Tubing (size, grade, and measured depth) 3 - 1/2" , J - 55, 8381' MD. /� OGCC Packers & SSSV (type & measured depth) Packer = CAMCO HRP - - SP, 8082' MD / ` 0 SSSV = Camco TRDP -1A (Locked Out Flow Tube), 1799' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured) NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run Exploratory ❑ Development ❑ Service Daily Report of Well Operations X 16. Well Status after proposed work: 010 Gas ❑ WAG 1 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: 306 -367 Contact Martin Walters / MJ Loveland Printed Name Martin Walters Title Well Integrity Project Supervisor Signature Phone 659 -7043 Date 6/15/12 D MS J UN 2 0 20124444 �L 0 42---- Submit Original Only Form 10 -404 Revised 04/2004 • 1 F -11 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary , 12/25/2011 SET PLUG @ 8059' RKB / 8060' SLM, TEST 2000#; HOLDING, POOH, NEGATIVE TEST 200 #; HOLDING. Removed cement around surface casing and buffed to inspect casing. Found pipe in poor 5/12/2012 condition from the collar down to the top of the conductor. Need to remove more conductor to find good pipe. 5/20/2012 ICut 10' of remaining conductor to reach 20' of SC pipe, prep for pipe inspector. 5/20/2012 (Call stateman (Bob Noble) for opportunity to witness damage to SC - he waived. 6/9/2012 Started repairing 6/7/12 and finished welding 18' long 10.75" .400 wall 45.5# sleeve onto surface casing 6/9/12. 6/12/2012 Post SC repair MITOA. (Passed) Initial T /I /O =si0 /25/0. Pressured up OA to 1800 psi with 1 bbls of diesel for one hour test. Starting T /I /O= siO/75/1800. 15 min T/I/O= si0/75/1750. 30 min T /I/O= si0/70/1730. 45 min T /I /O= siO/70/1720. 60 min T /I/O= siO/70/1720. Bled OA back to 0 psi. Final T /I /O =siO /25/0. 6/13/2012 Welded 19' 7.75" long 16" .375 wall 62.58# pipe, conductor extension onto existing conductor • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 15, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 1F -11, PTD 183 -115, Sundry 306 -367 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor ^!^e w-- X . ' ' ;a r!• 4 ' .,,n 2 .? ?� : `re ,�Y a if /! ? I � _ r r 1, .. t. " z , y: °r It, ', , j 7a " ; r x v Yr ,. t � ''t,+. p a u x x-.- 'nod .-f +t s t t :aK y. s sK t e * *" . �� 1 ,.. tam . � c fit • ,. - - r X Fi t * :.'%"'' - 1 ^� 7 S Fi . j ' { r P�2 d k. , .- 1 '2 , ..,, ,n , . , - ; ,-4 :, , , , ,, :: f F Y Y} t ( ]] ! a r Z .S; 1 >. 11 4 4 ` , , 4 1x 4 .. • 4 1 • 4 + 4 >: 4 4 .: 1 • 6 • • N g • • 0 fit. t;. 0' . „. ¢ :.. , y � ” - a y { *. s T � f , w ,. ,,_./. , P ' �- - P i. i E S. x € .% r # ,. Fu ♦ , A - ConocoPhillips RECEIVED Alaska NOV 1 7 2000 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 Alaska Oil & Gas Cans. Commission Anchorage November 14, 2009 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7` Avenue, Suite 100 Anchorage, AK 99501 1. rL. < Dear Mr. Schwartz: Enclosed please find the 10 -404 Report of Sundry well operations for ConocoPhillips Alaska, Inc. well 1F -11, PTD 183 -115 surface casing repair attempt. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, 6 r MJ toveland ConocoPhillips Well Integrity Projects Supervisor Enclosures RECEIVED STATE OF ALASKA NOV 1 7 ?009 ALASKA OIL AND GAS CONSERVATION COMMISSION p Ska Oil & Gas Cons. COMMISSIOri REPORT OF SUNDRY WELL OPERATION Anchorage 1. Operations Performed: Abandon ❑ Repair Well Q Plug Perforations ❑ Stimulate ❑ Other ✓❑ Repair well w Plate 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: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 183 - 115 / 309 - 303 3. Address: Stratigraphic ❑ Service Q" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20993 - 00 KB Elevation (ft): Well Name and Number: RKB 109' 1F-11 Property Designation: 0. Field /Pool(s): ADL 25652 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured �, 8787' feet true vertical 6333' feet Plugs (measured) Effective Depth measured 8787 feet Junk (measured) true vertical 6333 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 107' 16" 107' 107' SURFACE 2434' 9 -5/8" 2543' 2188' PRODUCTION 8647' 7" 8756' 6311' Perforation depth: Measured depth: 8200 -8304, 8434 -8442, 8460 -8500' true vertical depth: 5927 -5995, 6082 -6087, 6100 -6217' Tubing (size, grade, and measured depth) 3.5, J -55, 8381' MD. Packers & SSSV (type & measured depth) pkr= CAMCO HRP -1 -SP ; BAKER 'FB -1' pkr= 8082' ; 8360' SSSV= SSSV SSSV= 1799' 12. Stimulation or cement squeeze summary: 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 Casinq Pressure Tubina Pressure Prior to well operation NA -- Subsequent to operation NA - 14. Attachments . Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service 21 Daily Report of Well Operations _X We11 Status after work: Oil❑ Gas❑ WAGE] GINJ❑ WINJ ❑ WDSPL❑ 17. 1 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 -303 Contact MJ Loveland/ Perry Kle�659 -7043 Printed Name MJ Loveland Ti a Well Integrity Project Supervisor Signature // Phone: 659 -7043 Date �XSh. /tD / 9 ' Pre red b n IAl su Dr K 263 -4612 Form 10 -404 Revised 04/2006 ` Z Submit Original Only h 1F-111 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/23/2009 — Rrankpr Platelet SC Repair attempt aborted., Initial T /I /O = SI/490/0. Shoot fluid level of the OA @ 38 feet. Rig up triplex to skid manifold pressure test to 2500 to check for leaks. Fluid pack OA with about one bbl of diesel. Established LLR 6 gpm @ 2 psi Started to pump 1.5 bbls of diesel gel. Attempted to establish liquid leak rate until we noticed fluid coming out of open flutes. Shut down job and sucked out conductor through the open flutes about two feet below the 3/4 inch hole. Leak IQ large for Platelet re ain r. Fin al T /I /O = SI/490/0. Summary SC repair attempt aborted due to leak size. I • Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ~ P.O. Box 100360 , ~ Anchorage, AK 99510 '~~ ~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 1 F-11 Sundry Number: 309-303 :~ ~; r~~ : , ,. , ... ~ :_~.~ , Dear Mr. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions ~f 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 ~Cammission an application for rehearing. A request for rehearing is considered timely 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, • Daniel T. Se~mount, Jr. Chair DATED this~ day of September, 2009 Encl. • ~ • • ConocoPh~ll~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 28, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~ - ~ ., .,i- i 4~ ~ (Jl~r... ~~~: ~ , . ~ a,: - . Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1F-11 (PTD 183-115) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, .r~~~G~'l MJ veland ConocoPhillips Well Integrity Projects Supervisor Enclosures . _. ,t , ~~ ~ • ~.. ~ ~~ ~ ~ ~~ O STATE OF ALASKA ; - ~ ~ t {,w ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~ ~~ ~~ ~~ ~~ ~ `~~~`~` ~'~~`'' 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other Q Altercasing ~ Repairwell ~^ Plug Perforations ^ Stimulate ^ Time Extension ~ SC Platelet • 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. oeveiopment ^ Exploratory ^ 183-115 • 3. Address: Stratigraphic ~ Service Q. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20993-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ 1 F-11 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25652 ~ RKB 109' ~ Kuparuk River Field / Kuparuk Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth nno (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8787' ' 6333' • 8787 6333 Casing Length Size MD ND Burst Collapse CONDUCTOR 107' 16" 107' 107 SURFACE 2434' 9-5/8" 2543' 2188 PRODUCTION 8647' 7" 8756' 6311 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8200-8304, 8434-8442, 8460-8500' S927-5985, 6082-6087, 6100-6217~ 3.50 J-55 8381 ~ Packers and SSSV Type: Packers and SSSV MD (ft) pkr- CAMCO HRP-1-SP ; BAKER'FB-1' pkf= 8082' ; 8360' SSSV= SSSV SSSV= 1799' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch Q Exploratory [] Development ^ Service 0• 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ . GlNJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/ Perry Klein 659-7043 Printed Name MJ Loveland Title: Well Integrity Project Supervisor Signature T Phone 659-7043 Date ~ ~ Commission Use Onl Sundry Number: ~ Conditions of approval: Notify Commission so that a representative may witness ~ ~ Plug Integriry ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other. Subsequent Form Required: /a•7e~ ,~ ~ ~ ~ ~ ~ ~" % APPROVED BY ~ Approved by: ~~ C MMISSIONER THE COMMISSION Date: ~ Form 10-403 Revised 06/2006 ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~~•~;°~`~'~° ~~ ~_ ~~~:'" ~ ~ ?=~~v ~/'~~~mi~~Du~icate~~~ /~ ~ ~ ; , ~;. €° ~ ~ ~ ;` ConocoPhillips Alaska, Inc. ~ ' Kuparuk We111F-11 (PTD 183-186) a~ ~ ~~ ~~ ''~~~ SUNDRY NOTICE 10-403 APPROVAL REQUEST ~~~ ~° k` ~ August 28, 2009 This application for Sundry approval for Kuparuk well 1F-11 (183-115) is for the repair of a surface casing leak. The injection well, drilled and completed in 1983, was previously reported as having a surface casing leak near surface. Subsequent testing indicated the leak depth in the surface casing approximately 7' down from the OA valve. For technology development and due to the back log of surface casing excavation repairs ConocoPhillips is planning a temporary repair with Brinker Platelets (long term plans still include a conventional welded patch, approved Sundry 306-367). Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications, and within the operating conditions of the well. Each particle is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: l. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 8. Excavate and repair surface casing (Sundry 306-367) as schedule allows. . . FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 66510 Re: Kuparuk River Field, IF-II Sundry Number: 306-367 ('-";: I~ Dear Mr. Dethlefs: ..' ",," 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 timely 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, DATED thishdayofNOvember, 2006 Encl. ,~3-11S' . (f:}\y 15~...../\lJ STATE OF ALASKA ~'h'-\ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 EI\/ED ~" : 1'\J !Uø:~!U! nH 8, nm~ Cm!S f\}mln¡CJ;;é~¡m¡ 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D W¡¡!¡¡e¡>h,,'W, Other D $ .,." "iI'. ,. ,]' "~.-. t..;:-"'; Alter casing D Repair well 0' Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 183-115 3. Address: Stratigraphic D Service 0- 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20993-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes D No 0 . 1 F-11 . 9. Property Designation: ß II-(~ .ofp 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit ,4þl- t6t.5""Z RKB 109' Kuparuk River Field I Kuparuk 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): 8781' 6333' 8787 6333 Casing Length Size MD TVD Burst Collapse CONDUCTOR 107' 16" 101' 107 SUR. CASING 2434' 9-5/8" 2543' 2188 PROD. CASING 8641' 7" 8756' 6311 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8200-8304, 8434-8442, 8460-8500' 5927-5995,6082-6087,6100-6217' 3-1/2" J-55 8381' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= CAMCO HRP-1-SP; BAKER 'FB-1' pkr= 8082'; 8360' SSSV= SSSV SSSV= 1799' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 4th Qtr 2006 Oil D Gas D Plugged D Abandoned D 17. Verbal Approval: Date: WAG 0 . GINJ D WINJ D WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Marie McConnell I Perry Klein 659-7224 Printed Name d.erry DethlefS_ .~ Title: Problem Well Supervisor Signature -- '.?£ ee.é/ c0~¿::, Phone 659-7043 Date #/~¿;; / , Commission Use Only Conditions of approval: Notify Commission so that a representative may witness sun¿¡¡;~e~ 1 Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Otho' V\-..o\oili.",,,,,,,-,,-\o.\\,,,,, cÁ-Cx.~~ ~~ ,. ~ \J-J ," ,,'- <,.,,~ ""- \ '\ ~~It" ' ~~ v-'> Nt f'-- W(:\ \. '\ "" ~-.) ,\'{ -\<I ~'Cf > S'b,",,'oo' Fo"" Req"'ed '-{I:) ~ f RBDM!> 8Ft ¡ á lüü6 I Iff" /)6 App..'ed by T .~ I ~ '({ APPROVED BY COMMISSIONER THE COMMISSION Date: . Form 10-403 Revised 06/2006 \.../' "\./ O'RIGtNAL Submit in Duplicate ,. II. 'fo ~ /f- f~-D£:. t( It! . . ConocoPhillips Alaska, Inc. Kuparuk WelllF-11 (PTD 183-115) SUNDRY NOTICE 10-403 APPROVAL REQUEST 11/05/06 This application for Sundry approval for Kuparuk injection well IF-II is for the repair of the surface casing. The well is to be excavated and inspected for near surface casing damage, "" suspected to be due to corrosion. A previous attempt (Sundry 301-171) was unsuccessful, but current diagnostic and repair techniques make the well once again a candidate for repair. The well is a 3-1/2" completion that is designated as an MW AG injector, completed in September 1983. Diagnostics indicate a surface casing leak at or near 6' -9" below grade. The well has been shut-in since the casing leak was discovered in May 2001. A Mechanical Integrity Test (MIT) has successfully passed on the production casing and there are no known tubing problems. With approval, inspection and repair ofthe casing will require the following general steps: I. Safe-out the well with plugs and load the tubing and IA with water and diesel freeze protection cap. Isolate the well from surface facilities. 2. Remove the floor grate and equipment ftom around the wellhead. 3. Install nitrogen purge equipment for the IA and conductor so that hot work may be conducted in a safe manner. 4. Excavate around wellhead and install construction shoring box. 5. Notify the AOGCC Field Inspector of opportunity to witness the damaged casing. 6. Cut away the conductor and remove cement ftom around surface casing for inspection. Approximately the top 12 feet of conductor will be removed to provide work access. 7. CP AI Mechanical Engineers will determine the appropriate patch and/or repairs to return the casing to operational integrity should the damage be repairable. 8. QA/QC the repair and MIT-OA for a final integrity check (if repair was performed). 9. Install anti-corrosion coating to casing. 10. Replace the conductor and fill the void with anti-corrosion material designed to seal out water and oxygen. 11. Backfill as needed with gravel around the wellhead. 12. Remove plugs and return the well to injection service. 13. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 11/5/2006 ~ . . , CønocoPhilUpsAJðska, the. KRU 1F-11 API: 500292099300 Well Type: INJ Angle @ TS: 50 deg @ 8201 .. SSSV Type: Locked 0 ut Orig Completion: 9/19/1983 Angle @ TD: 44 deg @ 8787 Annular Fluid: LastW/O: 10/29/1988 Rev Reason: Set DMY sssv Reference Loo: Ref Loo Date: Last UDdate: 6/5/2004 (1799-1800, Last Tao: 8563 TD: 8787 IIKB 00:3.500) Last Tao Date: 10/13/1999 Max Hale Anole: 55 dea tã> 7600 CasÎna StrÎIIO" ALL STRINGS . DescriDtion Size TOD Bottom TVD Wt Grade Thread TUBING CONDUCTOR 16.000 0 107 107 62.50 H-40 (D-8381 , SUR. CASING 9,625 0 2543 2188 40.00 J-55 00:3.500, PROD. CASING 7.000 0 8756 6311 26,00 J-55 10:2.992) TubhiaStJ:ill!l".TUBING. I] 'ii:i::: - Size TOD I Bottom 1 TVD 1 Wt 1 Grade 1 Thread 3.500 0 8381 6046 9.30 1 J-55 I EUE 8RD ABM Perfur¡:¡tioiisSümroaìV . Interval TVD Zone Status Ft SPF Date TYDe Comment PLUG 8200 - 8304 5927 - 5995 C-4,UNIT B 104 12 10/21/1983 IPERF 120?? deg. Phasing; DA 5 esg (8060-8061, ~. ouns 00:2,813) 8434 - 8442 6082 - 6087 A-5 8 4 1/23/1984 APERF Zero deg. Phasing; 2 1/8 BarKone II DA 8460 - 8500 6100 - 6127 A-4 40 6 6/17/1984 RPERF 90 deg. Phasing (Reper!); LinkCone Gas tift MalldrelsNallles PKR ~ St MD TVD Man Mfr Man Type V Mfr V Type VOD latch Port TRO Date Vlv (8082-8083, Run Cmnt 00:6,156) ... 1 1 8003 58031 Merla 1 TMPX 1 DMY 1.5 I RM 0.000 0 5/31/2004 Iniectioll MalldrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt 2 8122 5878 Cameo KBUG DMY 1.0 BK 0.000 0 11/8/1988 Closed Injection 3 8188 5920 Cameo KBUG CV 1.0 BEK 0.000 0 10/13/1999 Oaen mdrellDummy 4 8322 6007 Cameo KBUG EMPTY 0.0 0.000 0 10/13/1999 1 Valve 2 (8122-8123, 1. Susr>ect mandrel damaaed. Pulled severelv eroded C V in 2 r>ieces 10/13/99, left emr>tv. 00:5.313) Other (I lu)s.~ uip"è1¢.l·JEWElRY DeDth TVD TVDe DescriDtion ID 1799 1696 SSSV Cameo TRDP-1A Locked Out Flow Tube on 4/28/94)) 2.813 Injection 8060 5838 SBR Cameo 'OEJ' 2.813 MandrelNalve 8060 5838 PLUG PLUG set 8/3/2001 0.000 3 8082 5852 PKR Cameo HRP-1-SP 2.867 (8188-8189, ) 8360 6032 PKR Baker 'FB-1' 4.000 8375 6042 NIP Cameo 'D' Nipple NO GO 2.750 8380 6046 SOS Baker 2.992 Perf 8381 6046 TTL 2.992 (8200-8304) .... .................... ..... .... ............. .... ........ ... DeDth 1 DescriDtion 1 Comment 8640 133' Perf StriD 1 Left in hale after Derf Injection MandrelNalve 4 (8322-8323, PKR (8360-8361, 00:6.156) ~ .... ". ... .... SOS ±II. (8380-8381, 00:3,500) TTL (8381-8382, ~ 00:3,500) Perf ~ - (8434-8442) ~ - ~ - Perf = = (8460-8500) ~ - Perf ~ - (8460-8500) ~ - = = ~ - ~ - ~ - ~ - - 33' Perf strip (8640-8673, 00:5,000) 1F-11 (PTD 183-115) plan . . Tom, We are investigating 1F-11 injector to evaluate integrity. The well has been SI since 2001 due to a hole in the surface casing. Sundry #301-171 was approved 7/2001 and a subsequent 10-404 was submitted in 2/2004. The surface casing leak repair attempt was unsucessfull as the leak is too deep to excavate and repair. Currently, a tbg mandrel above the packer is empty and a TTP is set. Since the tbg tail plug was set, 2 CMITs have passed verifying integrity of the IA and PKR: The tbg needs to be tested to prove integrity in order to submit a 10-403 application to return the well to injection. Current plan is: 1. Install a DV in the empty mandrel and MITT / MITIA to check tbg integrity from both sides. 2. Pull TTP 3. Measure SBHP 4. MITIA 5. Submit 10-403 to resume injection based on diagnostics Once approval to injection is obtained, the conductor pipe window will be replaced as noted in the 10-404. Since the well will remain SI for diagnostics for steps 1 thru 4, I'd like to wait until step 4 is completed for a better understanding of well integrity before submitting the 10-403. Please advise if this is acceptable. Marie McConnell Problem Well Supervisor 659-7224 ,'. 1'" I, ~",~íi< \r"~'F' Öv~::~~\'Iji::.: ; ~¿ C: ... ''#''- Q""Q"~~-~~ I of I 11/14/200612:31 PM IF-II Casing Repair Tom: Sunday I had Scheve come over to watch us open up the conductor casing on IF-II. As per the other email you were cc'd on, the fitting we thought was leaking did not turn out to be so. After we opened up a hole where we could look inside we found the leak was still below us by several feet (nitrogen purge was bubbling up through some liquid on the cement top). We will have to do a little more investigating before I can tell you more. I don't know if the top job we pumped is covering the leak or if it is exposed. Most likely it's a thread leak, but it will hold no pressure at all. Our N2 purge leaked through at just 1 or 2 psi. We have a couple things we can look at for repairs, but they are more along the line of sealants rather than welding. It is unlikely a cement column would be adequate since this is so close to the surface. I have never tried to obtain a variance for a leak in the surface casing, but there also are no regulations regarding this that I know of. There is no IA x OA communication on this well, so a variance of some kind is something we should discuss. What is your feeling about that? This well is one of those with slight T x IA communication on gas service, so has been limited to water injection only for many years, and there has been no problems in that service. I will keep you posted as we get further into this. Call if you have any questions. . Jerry Dethlefs Phillips Problem Well Supervisor . 1 of 1 ~"'~~0 11/14/2006 12:31 PM 1 F -11 Casing Repair Subject: IF-ll Casing Repair From: "NSK Problem Well Supv" <nI617@ppco.com> Date: Sun, 5 Aug 2001 14:22:25 -0800 To: tom_maunder@admin.state.ak.us CC: "NSKProblem Well Supv" <nI617@ppco.com> \~5-\ \S- Tom: Sunday I had Scheve come over to watch us open up the conductor casing on IF-II. As per the other email you were cc'd on, the fitting we thought was leaking did not turn out to be so. After we opened up a hole where we could look inside we found the leak was still below us by several feet (nitrogen purge was bubbling up through some liquid on the cement top). We will have to do a little more investigating before I can tell you more. I don't know if the top job we pumped is covering the leak or if it is exposed. Most likely it's a thread leak, but it will hold no pressure at all. Our N2 purge leaked through at just I or 2 psi. We have a couple things we can look at for repairs, but they are more along the line of sealants rather than welding. It is unlikely a cement column would be adequate since this is so close to the surface. I have never tried to obtain a variance for a leak in the surface casing, but there also are no regulations regarding this that I know of. There is no IA x OA communication on this well, so a variance of some kind is something we should discuss. What is your feeling about that? This well is one of those with slight T x IA communication on gas service, so has been limited to water injection only for many years, and there has been no problems in that service. I will keep you posted as we get further into this. Call if you have any questions. . Jerry Dethlefs Phillips Problem Well Supervisor . 1 of I ~\<"-~~\ ~Co~ 11/14/2006 12:31 PM 1 F -II Pictures . . Chuck: Attached are the pictures I took this morning of IF-II. Let me know if they don't work--this is a pretty big file. Rick Overstreet had the best explaination for the "fitting" we found in the casing. If they have problems centering the casing during landing they will wedge it with whatever is handy--in this case it may be from some other piece of equipment. He thought it may be from a load-cell from a hydraulic system. Since our leak is lower down it really is a mute point anyway. Back to some diagnostics and some other approach to fixing this problem (if possible) . (See attached file: IF-II Parts from Cutaway.jpg) (See attached file: IF-II Casing Cutaway 3.jpg) (See attached file: IF-II Casing Cutaway.jpg) (See attached file: IF-II OOA Looking Down.jpg) (See attached file: IF-II Casing Cutaway 2. jpg) Jerry Dethlefs Phillips Problem Well Supervisor IF-ll Parts from Content-Type: image/jpeg Content-Encoding: base64 IF-ll Casing Cutaway Content-Type: image/jpeg Content,;,Encoding: base64 Content- Type: image/jpeg IF-ll Casing Cutaway.jpg Content-Encoding: base64 Content-Type: image/jpeg IF-ll OOA Looking Down.jpg Content-Encoding: base64 Content-Type: image/jpeg IF-ll Casing Cutaway 2.jpg Content-Encoding: base64 ~~~~~~ 1 of 1 11114/2006 12:28 PM \ of F- ¡ \ IF-J J600xJ200 F- j Kuparuk 1 F -11 Casing Repair . . Tom: I got your voice mail about the ok to move forward on IF-II casing repair. When we have work scheduled on the well we will give the Inspectors a call. Thanks! Jerry Dethlefs Phillips Problem Well Supervisor 1 of 1 11/14/2006 12:28 PM [Fwd: IF-II Cement Top Job] . . Guys, This is a follow up to the other note. This well has a really goofy set up. There are side outlets on both the conductor and surface pipe. It isn't like anything I've seen before. Anyway, Jerry D used a boroscope to examine the set up after a leak was found. The outlet on the 9-5/8" surface casing has cracked. The crack was pretty evident in the pictures. What they propose to do is perform a conductor x surface casing cement job to fill up that void space and stabilize the installation. Then they are proposing to cut away a portion of the conductor pipe to allow access to the interior outlet. They plan to cut it off and weld on a patch. The surface casing grade is J-55 so there really aren't serious metallurgical concerns. Jerry indicated that the well will be safed out. I don't have the specific details, but he mentioned of insuring that all hydrocarbon was away from the surface in both the annulus and the tubing, a tubing plug would be set and a blanket of N2 would also be employed. Let me know your done and I think to safely do it. Tom thoughts. It looks like an operation that should be they have put in a lot of good thoughts regarding how Thanks. Content- Type: message/rfc822 Content-Encoding: 7bit 1 of 1 11114/2006 12:28 PM Re: IF-II Cement Top Job . . Pete, Jerry was in the other day and we discussed this well and looked at the boroscope pictures. What a strange set up! Your plan to perform the conductor x surface pipe cementing operation now is appropriate. You indicated you had been in contact with Jeff Jones for witness. Since this operation is a part of the whole, it is not necessary to send in a 404 at this time. Capture all the goings on when all the operations are completed with one 404. Good luck. Tom NSK Problem Well Supv wrote: Tom I am working on a package to fix the leak in the surface pipe for IF-II. Prior to cutting away at the conductor and patching the surface pipe the cement level in the surface x conductor annulus needs to be topped off. The void in the annulus is about 54 ft deep and the surface pipe leak is 2' 8" into the annulus. I am planning on cementing the annulus up to about 4 ft from the surface, leaving access to repair the leak. Getting the package approved for cutting and welding is a lengthy process. Prior to this approval I would like to proceed and do the cement top job. Once the package is approved, I will then capture the cement job and the following repairs in the 403 and 404 forms. Thanks, Pete Nezaticky Phillips Alaska Problem Well Supv. (907) 659-7224 1 of 1 11/14/2006 12:27 PM ~. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Rego..--J . P.I. Supe:'isor \<'f.11 &/71 [\ij DATE: Monday, June 07, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC IF-11 KUPARUK RIV UNIT IF-11 f~3-IIS FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:JBr;-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IF-I I Insp Num: mitLG0406051 11404 Rei Insp Num: API Well Number: 50-029-20993-00-00 Permit Number: 183-115-0 Inspector Name: Lou Grimaldi Inspection Date: 6/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IF-II Type Inj. N TVD 6332 IA 0 3075 3050 3040 3030 P.T. 1831150 TypeTest SPT Test psi 1463 OA 0 0 10 10 10 Interval OTHER P/F P Tu bing 50 750 750 750 750 Notes: Test after repair ofOA Monday, June 07, 2004 Page 1 of 1 y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 6,2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc., well IF -11 (PTD 1831150). The report regards an attempt to repair the surface casing. Please call Marie McConnell or me at 907-659-7224 if you have any questions. Sincerely, ~~ Jerry Dethlefs ~~ Problem Well Supervisor ConocoPhillips Alaska, Inc. Attachments RECEIVE[) FEB 0 9 2004 Alaska Oil 8i Gas Cons. Cornrni~5¡olì Anchorage ,~;CA\fNqMED' rES 1 82004 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D Suspend D Alter Casing 0 Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 109' 1. Operations Performed: 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 8787' feet true vertical 6333' feet measured 8563 feet true vertical 6172 feet Length Size MD 107' 16" 107' 2434' 9-5/8" 2543' 8647' 7" 8756' Operation Shutdown 0 D D Perforate D Stimulate D Other D Variance D Annular Disp. D D D Time Extension Plug Perforations Perforate New Pool Re-enter Suspended Well 4. Current Well Status: Development D Stratigraphic D Exploratory D Service 0 5. Permit to Drill Number: 183-115/ 6. API Number: 50-029-20993-00 9. Well Name and Number: 1 F-11 10. Field/Pool(s): Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 107 2188' 63111 Measured depth: 8200'-8304',8434'-8442',8460'.8500' Intervals treated (measured) RECEIVE: FEB 0 9 2004 true vertical depth: 5927'-5995',6082'-6087', 6100'-6127' N/A Oil-Bbl Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations_X Contact Jerry Dethlefs @ 659-7224 Printed Name Jerry Dethlefs 0 Signature /1 - ó'1/ /'. - ~ C-/~q- L- - y / \ / L/ Form 10-404 Revised 2/2003 . Tubing (size, grade, and measured depth) 3-1/2" , J-S5, 8381' MD. Packers & SSSV (type & measured depth) CAMCO HRP-1-SP; BAKER 'FB-1'; pkr= 8082'; 8360' SSSV= CAMCO TRDP-1A SSSV= 1799' 12. Stimulation or cement squeeze summary: Alaska 011& Gas Coos. Am,,;m! l-mP. 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 8000 3500 0 0 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilD GasD WAG[2J GINJD WINJ D 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: 301-171 Casina Pressure 1500 400 Tubina Pressure 2750 0 WDSPLD Title Phone Problem Well Supervisor 907 -659-7224 Date 02,,4 /t' t/' fE.a 0 19 19~~UBMIT IN DUPLICATE .MS Bf~.. ConocoPhillips Alaska, Inc. Kuparuk Well IF-II (PTD 1831150) Report of Sundry Operations 10-404 02/04/04 As per Sundry #301-171, ConocoPhillips Alaska, Inc., attempted to repair a surface casing leak in Kuparuk well IF-II. The well is an injector that was found to have a surface casing leak to atmosphere (into the conductor casing), suspected to be through a cracked fitting connection 2- feet below the surface casing hanger. After cutting and removing a portion of the conductor casing it was determined that the surface casing leak was much deeper than originally thought and repairs from the surface are not possible. The leak is now suspected approximately 40-feet from the surface. The well is currently shut-in with a tubing plug and will remain so until an AOGCC approved repair and/or waiver is completed. The conductor "window" that was removed has not been replaced. Attached are a table of events were recorded as part of the repair attempt. NSK Problem Well Supervisor 02/04/04 ConocoPhillips Alaska, Inc. Kuparuk Well 1 F-11 Operations Report . Date: I '. Comment: :When attempting to charge the OA gas immediatly vented out from between the surface :pipe and conductor. After further investigation it appears the leak in the surface pipe is . ..........~Œ!?_q2.~..L~.!:!~Y..~.!~~..!~~!..~_9.~!!.:._....."........w.....................'.'.'...."."""""""""''',,,,,-,, ...." ." ..'......-.,...,^.._w....,.................'.-,^................. ... . .. ..,...."........"....., ¡.. .........~~~!'?:'Q.Q.~J§E!~.~,i.~..!~..~.2.~.~g_.~?~..~.!..~~..~~~~.~.~~.i..~.~t..~.~.~~.:.._.........".,^..._...........,...-....w""""""",,,',,,,,,',,,,,,,,,,,,,"...'. ",-""""""",-w...."-..w",,,,,,,,,,,,,,,ww,. ¡RIG UP N2 TO OA, VAC TRUCK ON STANDBY. STRAP FLUID LEVEL IN CONDUCTOR: iAT l' 4". SHOOT FLUID LEVEL ON OA NEAR SURFACE. START N2 PURGE DOWN: jOA, FLUID LEVEL AND BUBBLES START RISING IN CONDUCTOR IMMEDIATELY. :CONTINUE PURGING N2 AND TAKING RETURNS UNTIL BUBBLES AND FLUID : LEVEL STOPPED RISING. LET SETTLE, START PURGE AND LISTEN FOR N2 OR ¡BUBBLES, ALL N2. STOP ALL PURGE AND STRAP CONDUCTOR FOR FLUID LEVEL; 'AT 2' 8". SHOOT FLUID LEVEL ON OA NEAR SURFACE BUT BY COMPARING INITIAL: ~FLUID LEVEL AND SECOND ON OA, IT APPEARS TO HAVE MOVED DOWN VERY ~ ;SLlGHTLY. STRAP ON CONDUCTOR TO GRAVEL PACK IS 581. LANDING RING IS ; . 5/18/2001 I ATTACH EDTO CONDUCTO~ BY WELDING. :"",,,,,,,,,,,wM""'M""Mw"'''''ISer¡ç2'''pfû'g'1nM''Š^šS\TnTpple"'@"T79'gÎ"Üower"plüg"wõ'uÎd'ñötseif"TestedpIug;ws'etBp'v'rñ"""'''~ t"...§!,g2.~~2Q.~,J!,~~.i,~.Q:,,,ê,I~.9..,99~n,,!~.:,YY~!.~,!~,,~~~.~~,~,§!..,~n!!I,..~~.~,i.r,-),9wE~!?,~i~~9.:..,......ww"W'..'., "..M".."..", .,. ,W'" .'......"........,.,.., ... ., . ; Performed boroscope inspection of OOA for leak area. Suspect cement circ pipe crack. : : Located approx. 2'-8" down on backside of wellhead. Need to verify by repeating !. 5/28/2001[' boroscope with N2 venting through leak. '1 ,RIGGED UP N2 BOTTLE TO OA. RUN BOROSCOPE DOWN TO 2+ FT DOWN THE :!SURFACE PIPE X CONDUCTOR ANNULUS. SAW HOLES AROUND A 2" PIPE . :COMING OFF THE SURFACE CASING. THIS PIPE LOOKS TO BE ATTACHED TO THE. ¡CEMENT CIRC LINE COMING OFF THE CONDUCTOR. FLOWED N2 DOWN THE OA :AND SAW INDICATIONS THAT THE NS WAS COMING THROUGH THE HOLES :',.""w.§(g(g.Q.9..~".,~.B.Q~.~.Qw!,~..,§.,?:.I:.~.I,~§..~,Q.~.I.~..§...Q,~I.,Q.~,I,~§..ê.~,~~~g§,~,~,§I,~§~~I~,§ð,~..~~~.Y~:w,.. ,~ ;. Met with AOGCC about repair plans. Agreed to following: Submit 10-403 to AOGCC prior :to repair taking place. Invite Field Inspector to witness. : Basic steps: 1. Pump OOA top job (done). Submit 10-403. ;2. Cut hole in conductor. : 3. Cut off fitting. 4. Weld repair patch (to be determined by facility Eng.). :5. Submit 10-404 summarizing repair steps. .: 6/11/200f!PTD # 1831150. t""""'''''''''''''''''ëEK~1'EÑTE5'sU¡:fFACi~x''''cð"fZjõncro'Ã "ÃÑ'ÑU'CUS""O'p...tÖ"Lr FT"'FROM fH'ETÕP"Öï="'" ': 6/16/2001iTHE HANGER FLANGE. AOGCC approved Sundry #301-171 to fix surface casing leak. Notify Inspector to witness 7/20/2001 submit 10-404 Checked T & IA; both on Vac. Pulled VR plug from lA, installed purge vavle. Installed OA purge valve with hose extension down about 2-1/2' (obstruction further). Should be near 8/4/2001 of leak. Installed all lines and N2 bottles. Notified AOGCC Page 1 ConocoPhillips Alaska, Inc. Kuparuk Well 1 F-11 Operations Report """"""''''''''''''''''~-''-'''''''''~-''''''''''~'''''''''''''''''^''''-''''''''''''''''''''~''''''''''''''''''''''''''~''~'''''''''''''''''''~''''''''---...._._-_......-..........,~...._.....,.,~""~........,............................-...........,..."~~.....""".,................-_,..,,.........~....,.~,,.........................."y,"""""""''''-'.....''''',y,....................................,...............................,,,,,.........~..,.,,.,,,,,.................,,,....,,-''''w.,w' ,Cut hole in conductor casing for inspection of leaking surface casing fitting. Found fitting was not connected; probably used during setting surface casing to help center the pipe (wedged in tight). Could see nitrogen purge gas bubbling in fluid on cement top ,approximately 4-feet further down in OOA. No repairs were attempted; well remains shut- , ",.~!?,(?,Qg..~....linw~i!,.~.,I,I~"in,..~.ê..~,,,~!:!9,}?Y"1,~,P..~.II,~,9",(9,P,~^~,.J?9~,~~!):,^Y,B,,...P!,~f;t..~,.~~,~~,~~.,....p~,I,I~~,.,!!9,.~.w,I,~:,w,W^^'''^'',w.' ¡OA FL @ 43'. Vac out 3 gallons of fluids from conductor casing, cement top @ 4'6" from 8/8/2001 ¡bottom of cut in conductor. T/I/O= 0/0/0 '" ""^":pum"p^ecfdiesef'wiif1"'IR'§"d'òwrl'oA:'iãkiñg"'reiú'rr1swljp'Q'ÖA::'Fîad 'to'''Úse''1Î''šifñ'ç)'erh'õs'ê'from ': ¡vac truck in OOA. established 0.5-0.6 bpm @ 100 psi stability between pump rate and vac ; 8/10!2001Jt~u~kcapability. ". . '. ..' ','. ".' '.".". .'" . ..' .".' ...H .". '.'.". .' '.....'.'.'. . ' : ,,^-_w, ,,^^,-, '_.-w,",,", ,'~JfÎTIA""^:p'ãssêd'.'--'T7I76~s¡¡4õo7õ':--p"rešš ü-r:ê'cf 'ú'pMfÃwTåMw§'õo')'psrwith 'C¡iëse Cstarttvfîilt\,'''''' w"www, T/I/O=si/3000/0, 15 minute reading-T/I/O=si/2980/0, 30 minute reading-T/I/O=si/2970/0. :""'" §!??,/,29q~.iln~I,~~,!,~,,9P\,\l~!,ti~~I^I(!(Q,=w~i!~92!2,w,ww"",..., " ",,,,w,,w.'.. " . "'.,W''','W'^"'''''",',,. " Page 2 ~PHILLIPS Alaska, Inc. .~ A Subsidiary of PHILLIPS PETROLEUM COMPANY KRU 1 F-11 SSSV . (1799-1800, OD:3.5OO) I TUBING I (0-8381, OD:3.5oo, ID:2.992) IIJ SBR ...;........... (8060-8061, ~ OD:3.500) ... ..... PKR (8082-8083, OD:6.156) .) ..... ... 1 F-11 API: 500292099300 SSSV Type: Locked Out Annular Fluid: Well Tvoe: INJ OriQ Completion: 9/19/1983 Last W /0: 10/29/1988 Reference LOQ: Last TaQ: 8563 LastTaQ Date: 10/13/1999 Casina Strina - ALL STRINGS Description Size CONDUCTOR 1~000 SUR. CASING 9.625 PROD. CASING 7.000 Tubing String - TUBING Size Top I Bottom I TVD I Wt I Grade I 3.500 I 0 I 8381 I 6046 I 9.30 I J-55 I Perforations Summary Interval TVD Zone Status Ft SPF Date Type 8200 - 8304 5927 - 5995 C-4,UNIT B 104 12 10/21/1983 IPERF Ref LOQ Date: TD: 8787 ftKB Max Hole AnQle: 55 deQ @ 7600 Anale (ã) TS: 50 deQ (â1 8201 AnQle (â1 TD: 44 dea (â1 8787 Rev Reason: GL V design, set pluQ bv ImO Last Update: 8/5/2001 Top 0 0 0 Bottom 107 2543 8756 TVD 107 2188 6311 Wt Grade Thread 62.50 H-40 40.00 J-55 26.00 J-55 Thread EUE 8RD ABM 8434 - 8442 6082 - 6087 A-5 Comment 120?? deg. Phasing; DA 5 CSQ Quns 8 4 1/23/1984 APERF Zero deg. Phasing; 2 1/8 BarKone II DA 40 6 6/17/1984 RPERF 90 deg. Phasing (Reperf); LinkCone 8460 - 8500 6100 - 6127 A-4 .0____.' Gas ljffMandrelsNalves St MD TVD Man Man Mfr Type 1 8003 5803 Merla TMPX Injection MandrelslValves St MD TVD Man Man Mfr Type 2 8122 5878 Cameo KBUG 3 8188 5920 Cameo KBUG 4 8322 6007 Cameo KBUG ()thef( phíf:JS,éQuip.,etc,) -JEWELRY Depth TVD Type 1799 1696 SSSV 8060 5838 SBR 8082 5852 PKR 8360 6032 PKR 8375 6042 NIP 8380 6046 SOS 8381 6046 TTL Fish. FISH Depth Description 8640 133' Perf Strip Injection MandrelNalve 3 (8188-8189. OD:5.313) ...- Description Cameo TRDP-1A (Locked Out Flow Tube on 4/28/94)) Cameo 'OEJ' PLUG reset 8/3/01 Cameo HRP-1-SP Baker 'FB-1' Cameo 'D' Nipple NO GO Baker V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt OPEN I 1.5 I 0.000 I 0 8/3/2001 .... ....... ... .. ... .. V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 0 11/8/1988 Closed 0 10/13/1999 Open 0 10/13/1999 OPEN .............. ID 2.813 2.813 2.867 4.000 2.750 . 2.992 :--..2'-992- DMY CV OPEN 1.0 1.0 0.0 .. BK 0.000 BEK 0.000 0.000 Injection landrel/Dummy Valve 2 (8122-8123, OD:5.313) Perf (8200-8304) --. -- - Injection MandrelNalve 4 (8322-8323, OD:5.313) I I I ' I - . ------ Comment 1 Left in hole after perf PKR (8360-8361, OD:6.156) . SOS (8380-8381, OD:3.500) Perf - I- -- (8434-8442) --- I- -.- - I- -- -I- -- - I- --- Perf - I- -- (8460-8500) - I- -- -I- -- =-þ.: == Perf -- -. -.- (8460-8500) - I- -- - I- -- - 1-, .-- --.-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _X Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address ! P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 510' FNL, 503' FEL, Sec. 19, T11 N, R10E, UM At top of productive interval 3645' FSL, 3667' FEL, Sec. 18, T11 N, R10E, UM At effective depth At total depth 1291' FNL, 3884' FEL, Sec. 18, T11N, R10E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Servi~X (asp's 53947O, 5959014) (asp's 536049, 5963495) 6. Datum elevation (DF or KB feet) RKB 109 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1F-11 9. Permit number / approval number 183-115 10. APl number 50-029-20993 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: Casing CONDUCTOR SUR. CASING PROD. CASING measured true vertical Length 107' 2434' 8647' 8787 feet Plugs (measured) 6333 feet 8563 feet Junk (measured) 6172 feet Size Cemented Measured Depth True vertical Depth 16" 175 sx cs It 107' 107' 9-5/8" ~1oo sxAS m & 25o sxAS ~ 2543' 2188' 7" 775 sx Class G & 150 sx AS I 8756' 6311' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 8200'-8304', 8434'-8442',8460'-8500' RECEIVED 592T-5995',6082'-6087', 6100'-6127' ,JUN 2 7 2.003 3-1/2", 9.3#, J-55 Tbg @ 8381' MD. ~aska 0il & Gas Cons. Commission Anchorage CAMCO HRP-1-SP @ 8082~ MD; BAKER 'FB-I' @ 8360' MD; CAMCO TRDP-1A (LOCKED OUT FLOW TUBE ON 4/28/94)) @ 1799' MD. 13. Attachments Description summary of proposal ___X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation July 2, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended I Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedJerald~ts¢~''~ ~ (~~ Title: ProblemWellSupervisor FOR COMMISSION USE ONLY Questions? Call Jerry Dethlefs 659-7224 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance _ Mechanical Integrity Test __ Subsequent form requked 10- ~f~ Approved by' order of the Commission :ORIGINAL SIGNED BY Commissioner E) 'iaylor Seamount ORIGINAL Approval no.~(~/. /? / Form 10-403 Rev 06/15/88 · Return to: Problem Well Supervisor, NSK-69 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 1F-11 SUNDRY NOTICE 10-403 REPAIR REQUEST 06/25/01 The purpose of this Sundry Notice repair request is for approval to repair the surface casing on Phillips Alaska, Inc., Kupamk well 1F-11. The problem was discussed and the repair steps were summarized in a meeting between the AOGCC (Tom Maunder) and Phillips Alaska (Jerry Dethlefs) on June 11, 2001. Kupamk well 1F-11 is an injection well found to have a surface casing leak to atmosphere through a cracked fitting connection 2-feet below the surface casing hanger. The fitting was apparently used during the initial completion of the well to circulate cement. The fitting is no longer needed; the repair is designed to remove the fitting and repair the site with a welded patch. The leak was found on May 7, 2001, by the Drillsite Operator. While attempting to charge the surface casing x production casing annulus (outer annulus, OA) with gas, gas returns were immediately noticed coming from inside the conductor pipe. Further inspection showed a circulation fitting that penetrates the conductor casing and attaches to the surface casing. Differential shifting between the conductor casing and surface casing is thought to have caused the fitting connection to crack and leak. It is unknown when this originally may have occurred. The surface casing x conductor casing cement top was found to be 58-feet down. To prepare the well for repairs a cement "top job" has been pumped to bring the cement top within 4-feet of the conductor top (2-feet below fitting leak). The remaining repair steps are outlined below. ACTION PLAN 1) Submit in-service repair package to PAI Facility Engineering to determine the appropriate weld or patch specifications for the type of casing and service. 2) Safe-out the well for the repairs. See the attached safe-out procedure. 3) Notify AOGCC Field Inspector of repair date and time for witnessing. 4) Perform cutting & weld repair as specified per Facility Engineering. The basic steps are: a) Cut a hole in the conductor large enough to access the damaged fitting. b) Cut off the damaged fitting. c) Grind and clean the surface casing to prep for welding repair. d) Weld/repair as per specifications by Facility Engineering. e) QA/QC the weld repair. f) MIT the annulus @ 1500 psi to check for repair integrity and other internal or external leaks. g) Remove safe-out on the well and return to injection. 5) File Sundry Notice 10-404 summarizing the details of the casing repair and cement "top job." NSK Problem Well Supervisor 06/25/01 Phillips Alaska, Inc. 1F-11 SURFACE CASING LEAK REPAIR PROCEDURE Remove and Patch Circulation Fitting Object Remove and patch the broken cement circulation fitting leak in the surface casing. The leak is an environmental and safety hazard. The fitting was used during the initial completion of the well and is no longer used or needed. It appears the fitting weld was broken due to differential movement between the surface casing and conductor casing (see pictures). General 1. AFC K85329, CC 230DS10FL 2. The cut and repair sequence for the failed fitting will be determined by PAl Facility Engineering as appropriate for the rating and service type of the surface casing material. 3. The conductor casing is 16" 62.50 Ib/ft H-40. A window will be cut in the conductor casing to provide adequate access to cut and remove the fitting and weld the casing patch. 4. The fitting is welded to the surface casing FMC/OCT 9-5/8" hanger, which is 4130 metal. The thickness is unknown and will require a UT inspection. The base outside diameter (the surface casing end) of the fitting is estimated at 3 inches (accurate measurement is difficult). 5. The surface casing/conductor annulus (OOA) has been filled with cement to within 2' below the fitting to be removed. 6. The surface casing/production casing annulus (OA) fluid level is at or near the leak site and will require removal to below the leak area prior to cutting and welding. A fire-suppression agent will be applied to the fluid surface in the OA prior to hot work commencing. 7. The well is a water injector. The safe-out procedure includes a tubing plug (done) to secure the well from the formation and isolation from the facility by closed wing and lateral valves. Process isolation lock-out & tag-out procedures apply. The tubing and IA will be bled to zero pressure prior to Hot Work commencing. A nitrogen purge will be maintained on the inner annulus (IA) and outer annulus (OA) during the welding operation with continuous monitoring of 02 and LEL levels. Special precautions will be required to prevent excessive emissions from the OA when the fitting is removed and a patch is installed over the leak area. A fire-suppression material will be used on the fluids (diesel) inside the OA. There appears to be adequate workspace in the cellar without removing wellhouse flooring or piping. 10. There is an excavated cellar box with a concrete floor. 11. On-site personnel should be limited to only those with activities and responsibilities associated with the job. 12. Any on-site personnel have the authority to stop or suspend the job should any safe-out or procedural conditions become suspect. Safety is everyone's responsibility. . . Job Preparation 1. Prepare In-Service package for cutting and welding for the repair sequence. (WG, ENG) . 10. 11. 12. 13. 14. 13. Develop JHA package to cut and remove a window from the conductor casing to gain access to the surface casing, and for fitting removal and patch repair. (APC and APC Supt.) 2. Shut-in and secure well (done). Set tubing tail plug (done). Pull BPV from tubing for monitoring tubing pressure during Hot Work. (WG) 3. Bleed tubing, IA (3-1/2" x 7") and OA (7" x 9-5/8") to zero psi. Verify flow is zero; inability to maintain zero psi prior or during job will cancel the repair operation. (APC & WG) 4. Prep 9-5/8" casing head: Pull VR plug and install opposing valve on casing head for N2 purge. (WG & Valve Shop) 5. Prep 7" casing head: Pull VR plug and install opposing valve on casing head for N2 purge. (WG & Valve Shop) 6. Remove OA fluid to about 10' below hanger via suction hose. Void area between leak point and fluid level (_-- 8') will be capped with a fire-suppressant material. Material specification and application time is to be specified by Safety and Fire Departments. (APC & WG) 7. Steps 3-6 will be done prior to Hot Work to ensure well is stable and provide for scheduling of personnel involved in the repair operation. 8. Install purge lines from N2 bottle rack to IA / OA, and from IA / OA to slop trailer. Discharge will be monitored for LEL and 02 levels and must be accessible. Position slop trailer downwind and as far from wellhouse as is practical. (APC) Connect indirect fired heater to wellhouse for heat and ventilation. (APC) Disconnect CAT wellhouse heater gas supply line (if applicable). (DSO) Station Fire Truck outside wellhouse, and hand-held extinguishers in and around wellhouse. (APC & WG) Inspect and remove any combustibles in accordance with Hot Work standard. (APC) Install welding blankets to cover cellar and ground around wellhead. (APC) Hold pre-job safety meeting and ensure all permitting is in order. (WG) Job Procedure 1. Notify AOGCC Inspector 24 hours in advance for witnessing repair; attendance may be waived. (WG) 2. Safety department will check entire well area before Hot Work commences. Sniff entire piping layout in wellhouse to check for any potential flammable material sources. (APC and/or PAl) 3. If not already done in the well safe-out, apply fire suppression material in OA as a barrier to the repair area and OA fluid. 4. Purge the IA and OA with nitrogen, venting outside to slop trailer. Purged gas is to be monitored throughout job for LEL and 02 levels. Target 02 level is < 5%. The cutting / welding operation may commence after target 02 level is reached. (WG) (APC Safety) 5. Establish fire watch and begin hot work, including prepping surface, cut casing access hole, cut off fitting, and welding. Weld as per PAl Welding Procedure determined by Facility Engineers specifying pre heat, welding and post heat requirements. (APC, PAl Engr) 6. Allow weld to cool as per weld procedure. Perform dye penetrant test of weld after cool- down. (APC) 7. Pick up all trash and debris for disposal. Please leave a clean location! (ALL) 1F-11 Weld Proc 06-20-01.doc NSK Problem Well Supervisor Post Weld Procedure 1. MITOA to 1500 psi to check for any external leaks in wellhead connections and repair area. Notify AOGCC Inspector prior to MITOA for witnessing. (WG) 2. Remove the additional annular valves on IA and OA. (WG & Valve Shop) 3. Return well to injection. Monitor 9-5/8" annular pressure and welded area for 30 days. (DSO) 1F-11 Weld Proc 06-20-01.doc NSK Problem Well Supervisor - ARCO Alaska, Inc. ,qp, GKA 1F-11 :;; :;JJ:i:i APl: 500292099300 Well Type: INJ Angle ~ TS: 50 de9 (~ 8201 SSSV L sssv Type: Camco 'TRDP-1A' Orig Completion: 9/19/83 An~lle @ TD: 44 deg @ 8787 (1799-1800, ~ Annular Fluid: Last W/O: 10/29/88 Rev Reason: Tag fill, set CV by OD:3.500) !: ImO !::~ !::::::i:i: Reference Log: Ref Log Date: Last Update: 10/15/99 ....... :~ Last Tag: 8563 TD: 8787 ftKB TUBING ~ Last Tag Date: 10/13/99 Max Hole Angle: 55dogie7600 (o-8384, : i;~;~ ~in~l~ Stri~ ~ ~ONDUCTOR 0D:3.500, :--- ~in~ st~ihg ~ SURFACE: Size, Top , Boffom I TVD I Wt J Grade, Thread =.~ ~iii=. 9.625I I I J I I0 2543 2188 40.00 J-55 SBR ==.~=.==.= =..~=~=......=..=.=..:. ca~ih~ S~i~g~ PRODUCTiON (8060-8061, o~;~.~00, S,ze I ~o. I ~o~o~ I ~w I wt I~ra~oI ~roa~ ~fi~ih~ String~ ~UBING ; Size I Top IBo"om I TVD I Wt I Or,.ol Thread PKR 3.500 I 0 I 8384 6046 9.3O J-55 EUE 8RD ABM (8082-8083, ~ ~ ~ ~rfOratiOn$ SU~ma~: : 0D:6.156) ~ ..... Interval TVD Zone }tatusFeet SPF Date Type Comment B BarKone II DA ]~~1 8460-8500 6100-6127 A-4 40 6 6/17/84 RPERF 190 de~. Phasin~ IReperf); LinkCone ~,~ :: ::~:: G~i Lift M~hdmlS/Valves: ~ S,n ..~vo.an ~a. v.,rv.,,o vo.,~,c,,o. ..o~a,o v,v Mfr Type Run;omment :~:'~:: I 8003 5803 Meda TMPX DMY 1.5 RM 0.000 0 313194 MandreWalve 3(8188-8189 .... Stn MD 'FVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv ~ Mfr Type Run ;omment OD:5.313) .... 2 8122 5878 Camco KBUG DMY 1.0 BK 0.000 0 11/8/88 Closed ,e,~ 3 8188 5920 Camco ~BU~ CV 1.0 BE~ 0.000 0 10/13/B9 O,en (8200-8304) ~ ~'"~'i 4 8322 6007 Camco KBUG OPEN 0.0 0.000 0 10/13/99 OPEN Depth TVD Type Description ID InJection , 1799 1696 SSSV Camco TRDP-1A (Locked Out Flow Tube on 4/28/94/I 2.813 8060 5838 SBR Camco 'OEJ' 2.937 MandmlNahta '~iii"ii: ~ 8082 5852 PKR Camco HRP-I-$P 2.867 {8322-8323, :::~ 8360 6032 PKR Baker 'FLY-1' 4.000 ::: :::;i:' 8381 6046 q-I'L 2.992 PKR ~ FiSh ~ FiSH: :: : : I (836O-8361,~ t DepthI Description Comment OD:6.156) ~!i: "!:. 8640133' Perf StripILeft in hole after perf 808 f~.~ ii OD:3-5O6) !::: Ped (843~0442) Perf (8460-8500) Ped (84~o-S500) ARCO Alaska, Inc. '~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 19, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 1 B- 10 Perforate 1D-02 Other (inj valve) _~1 F- 11 Other (sssv) 1Q-10 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR051996 (w/o atch) RI C£ V£D Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate ~ Plugging ~ Perforate /~/'~ L'' ' Other _~X Pull tubing Alter casing Repair well 2. Name of Operator 15. Type of Well: Development ARCO Alaska. Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service Location of well at surface 511' FNL, 504' FEL, Sec 19, T11N, R10E, UM At top of productive interval 1635' FNL, 1613' FWL, Sec 18, T11N, At effective depth 1357' FNL, 1420' FWL, Sec 18, T11N, At total depth 1292' FNL~ 1378' FWL~ Sec 18~ T11N~ 12. Present well condition summary Total Depth: measured true vertical R10E, UM R10E, UM R10Ep UM 8787 feet 6332 feet 6. Datum elevation (DF or KB) RKB 115 7, Unit or Property name Kuparuk River Unit 8. Well number 1F-11 9. Permit number/approval number 83-11 5/94-11 2 10, APl number ,50-029-20993 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None \1 feet Effective depth: measured 8 6 7 4 true vertical 6250 feet feet Junk(measured) 33' Perf Strip @ 8640' Casing Length Structural Conductor 8 0' Surface 2 51 2' Intermediate Production 8 7 2 7' Liner Perforation depth: measured 8200'-8304', true vertical 5926'-5994', Size Cemented 1 6" 175 Sx CS II 9.625" 1100 Sx AS III & 250 Sx AS I 7" 775 Sx Class G & 150 SX AS I 8434'-8442', 8460'-8500' 6081'-6087', 6099'-6126' Tubing (size, grade, and measured depth) 3.5, 9.3#/ft., J-55 w/ tail @ 8381' Packers and SSSV (type and measured depth) PKRs: Camco 'HRP-1-SP' @ 8089' & Baker 'FB-I' @ 8367'; SSSV: Measured depth True vertical depth 107' 107' 2543' 2187' 8756' 6310' RECEIVED M/XY 2 $ 1994 A.iask~ Oil & Gas Cons. Commission Anchorage Otis MCX w/OR Lock @ 1799' 13. Stimulation or cement squeeze summary Installed spring-controlled safety valve in injection well. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pdor to well operation 0 4979 0 1350 3823 Subsecjuent to operation 15. Attachments Well Schematic Copies of Logs and Surveys run Daily Report of Well Operations 0 4978 0 16. Status of well classification as: Oil Gas Suspended 1350 3827 Service WAG Injector 17. I hereby ,C.,e~tify that the foregoing is true and correct to the best of my knowledge. Si~lned Title Senior Encjineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Well: 1F-11 AR._J ALASKA INC. - KUPARUK ! ..~.D Spud Date 09-1 0-83 Completion Date: 1 0 - 2 6 - 8 3 -Maximum Hole Angle: 55.4 Original Rig RKB: 27' All depth are RKB MD to top of equipment, 6,7 AP1#50-029- 20993-00 C Sand: ~ A Sand: OPEN deg. @ 7600' MD Well Type: WATER INJECTOR Tree Type: FMC GEN. 5000# Tree Cap Type: Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: 1 0 - 2 9 - 8 8 Jewelry 1 SSSV: CAMCO TRDP-1A 2.812" ID @ 1799'/Locked out, Otis MCX w/CR Lock 2 SBR: CAMCO OEJ 2.937" ID @ 8066' 3 PKR: CAMCO HRP-1-SP @ 8089' 4 PKR: BAKER FB1 @ 8367' 5 NOGO: CAMCO'D' NIPPLE 2.750" ID @ 8376' 6 SHEAR OUT: BAKER @ 8381' 7 TUBING TAIL: 3.5" TUBING @ 8382' Minimum ID: 2.750" NOGO Casing and Tubing Size Weight Grade To_D Bottom Description I 6" 62.5# H-40 0 1 07' CASING 9.625" 40# J-55 0 2543' CASING 7" 26# J-55 0 8756' CASING 3.5" 9.3# J-55 0 8380' TUBING Gas Lift Information Depth Stn# Valve Type Sz. Latch 8002' 1 D/V 1.5" RM Port Sz. AID# Date Run 03/03/94 8122' 1 D/V 1" BI'( 8188' 2 CV 1" BK 8322' 3 CV I" BK Perforation Data Interval SPF 8200-8304 12 8434-8442 4 8460-8500 4 Date Zone C A A 1 1/08/88 05/1 6/93 05/1 6/93 RECEIVED MAY 2 ;3 1994 .~,sv,~ uu & Gas Cons. Commission Anchorage Comments Comments: 33' PERF. STRIP @ 8640. TRDP flapper locked out. Hydraulic equalizing sleeve is still closed (not shifted). LASTTD: 8581' on 12/17/93 PBTD:8674' PBTDSS: 6141' LAST REVISION: 05/17194 SWC:CH ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1994 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 1F-11 Variance (sssv) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments FTR050295 (w/o atch) RECEIVED MAY '" 5 '~994 u~t & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 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 511' FNL, 504' FEL, Sec. 19, T11N, RI OE, UM At top of productive interval 1635' FNL, 1613' FWL, Sec. 18, T11N, RIOE, UM At effective depth 1357' FNL, 1420' FVVL, Sec. 18, T11N, RIOE, UM At total depth 1292' FNL, 1378' FWL, Sec. 18, T11N, RIOE, UM 12. Present well condition summary Total Depth: measured true vertical 8787 feet 6332 feet 6. Datum elevation (DF or KB) RKB 115 7. Unit or Property name Kuparuk River Unit 8. Well number 1F-11 feet 9. Permit number 83-1 15 10. APl number 50-029-20993 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 8674 true vertical 6250 feet feet Junk (measured) 33' Perf Strip @ 8640' Casing Length Structural Conductor 8 O' Surface 2 51 2' Intermediate Production 8 7 2 7' Liner Perforation depth: measured 8200'-8304', true vertical 5926'-5994', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 w/ tail @ 8381' Packers and SSSV (type and measured depth) Size Cemented 1 6" 175 Sx CS II 9-5/8" 1100 Sx AS III & 250 Sx AS I 7" 775 Sx Class G & 150 Sx AS I 8434'-8442', 8460'-8500' 6081'-6087', 6099'-6126' Measured depth 107' 2543' 8756' True vertical depth 107' 2187' 631 O' RECEIVE[ - 5 1994 .~..., u. ~ Gas Cons. Comm.<. Anchorage Pkr's: Camco HRP-1-SP @ 8089', Baker FB-1 @ 8367'; SSSV: Camco TRDP-1A @ 1799' 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch _ Install a sub-surface, sprin9 controlled safety valve in injection well. 14. Estimated date for commencing operation 115. Status of well classification as: May 1994 I Oil __ Gas Suspended 16. If proposal was verbally approved Name of,,alpprover Date approved Service WAG Injector 17. I here~e/~~.t~g is true and correct to the best of my knowledge. Si~ned I/ v'--'~ , - Title Sr. Engineer Date ,,,- .! FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance __,/_ .~, Mechanical Integrity Test _ Subsequent form require 10- ~ IApp~val No. Approved by order of the Commission original Signed By 0avid W. Johnston Form 10-403 Rev 06/15/88 Commissioner Approved Copy Returned. ('.[./__ Date ~,/"i)/~ ? SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 1D-02 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the failed surface controlled, subsurface safety valve in Injection Well 1D-02 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 these fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. RECEIVED MAY - 5 1994 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: ~'. Name of OPerator Operation Shutdown m Stimulate m Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 5. Type of Well' Development Exploratory ARQO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK I Stratigraphic 99510 Service '4. Location of well at surface 511' FNL, 504' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 3645' FSL, 3667' FEL, Sec. 18, T11N, R10E, UM At effective depth 3923' FSL, 3860' FEL, Sec. 18, T11N, R10E, UM At total depth 3988' FSL, 3902' FEL, Sec. 18, T11N, R10E, UM Other 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) 115' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1F-11 9. Permit number/approval number . 83-115/8-704 10. APl number 50-029-20993 11. Field/Pool Kuparuk River Oil Pool measured 8 7 8 7' feet true vertical 6332' feet Plugs (measured) Effective depth: measured 8674' true vertical 6250' Casing Length Size Structural Conductor 8 0' 1 6" Surface ' 251 2' 9 5/8" Intermediate Production 8727' 7" Liner Perforation depth: measured 8200'-8304', true vertical 5926'-5994', feet Junk (measured) feet ; · Cemented Measured depth 175SXCSII ' 107' 1100 Sx AS III 2543' 250".~Sx AS I 775 Sx Class G & 8 7 5 6' 150 Sx AS I 8434'-8442', 6081'-6087', Tubing (size, grade, and measured depth) 3 1/2", J-55, tbg w/tail @ 8381' Packers and SSSV (type and measured depth) 8460'-8500' 6099'-6126' True vertical depth 107' 2187' Camco TRDP-1A SSSV @ 1799', Camco HRP-I-SP pkr @ 8082', & Baker FB-1 pkr @ 8360' 13. Stimulation or cement squeeze summary Refer to daily drill site report. Intervals treated (measured) Refer to daily drill site report. Treatment description including volumes used and final pressure Refer to daily drill site report. 14. R. ep.re~en~ative D~ily Average PrQduction or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4000 1200 2400 Subsequent to operation 54O0 50 4000 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 WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si'ned 1~.-~4~%1~. ~ ~-~"4''w/¢ Fnrm v f3R/17/R.q Title Senior Operations Enginee~r Date RI IRMIT IN Ill IPl I¢,ATI: KOGS MORNING WELL REPORT DF- ILL$ITE IF FOR 12/17/85 PAGE W Z S E 0 T L ;J A L E- T ~ B TS 7 ~ PR t2 q- =~ 1~ ~ PR 1.G B oR TOT~'_S: W Z S E O T L N A L E T 5 3 P,~ 8 A PW 1.? ~ $I 11 5 GI 13 B PW 15 B SI TOTALS: TP PSI 130 151 140 1i7 123 119 153 llG PRODUCTION 4ELL STATUS 7" 10 TI' JC H2S CSG CS CHK OEO % PFM PSI PS 176 1C2 ~2 40 1120 113 176 1i* 40 30 850 87 176 120 54 70 1550 85 176 50 1 Z5 960 85 176 lbo 11 $2 975 17-3 94 8 20 780 70 176 128 50 25 12~0 61 ]75 126 5.t 85 1230 31 INJECTiOk NELL STATUS ALLOW ACT 7" 10" INJ INJ TT CSG CSG PSI PSI DEG CHK PSI PSI 2500 2530 2500 2500 %630 2500 25U0 240 244 242 391 391 165 158 176 1410 300 154 176 1390 210 15, 17& 920 750 152 175 1170 750 8~ lO0 0 0 8~ 45 0 30 156 10~ 1260 bOO 0 0 3 0 SWi: 0 + P~,~I: 1252~+ = GAS LIFT STATUS TEMF METER PEG REAglNG 0 5~r 0 ,1 O 0 O 0 0 O 36 0 0 42 0 0 %0 0 0 6.5 0 O 5'+ 0 INJECTION INO RATE MSCF 793 0 0 799 73% 1012 895 470 ~703 RATE INJ INJ METER RATE RATE READING BPD MMSCFD 1937 1701 1833 2908 0 G $2~9 896 1252~ 0o000 0.000 0.000 0.000 4°561 0.000 0.000 9.955 HM SN 0000 0000 0000 0000 0000 0000 0000 0000 IMPACT C 0 O EFL E BBLS O 0 C 0 0 0 0 0 0 S/I C H M 0 R I O S N E O00G 0 GO00 0 0000 0 0000 0 0000 0 0000 0 0000 0 1600 55 STATE OF ALASKA [~ '~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~ WATER INJECTOR ,, , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-115 .. 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-2099~ 4. Location of well at surface 9. Unit or Lease Name 511' FNL, 504' FEL, Sec.19, T11N, R10E, UM Ku~aruk River Unif. At Top Producing Interval 10. ~Vell Number 3645' FSL, 3667' FEL, Sec. 18, T11N, R10E, UM !F-!! At Total Depth 11. Field and Pool 3988' FSL_~ 3902' FEL~ Sec,18, T11N, R10E. UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6:Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKB ADI '~r~Rr~2 A I( 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/10/83 09/17/83 10/26/8:?,* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back DePth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8787'MD/6332'TVD 8674'MD/6250'TVD YES'~ NO [] 1799' feet MDI l~'~n' (~p?ro×) 22. Type Electric or Other Logs Run D I I/RFI/Rp/c.I~/Cal_/FDC/CNL, GR/CBL/VnL/cm nv,~ re~ /T~mn Inn 23. CAS~N~~, L~I~IE[R-~,'N'I~'~E~I~ING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# U-40 Surf 107' 24" 175 sx CS II 9-5/8" 40.0# J-55 Surf 2543' 12-1/4" 1100 sx AS Ill & 250 sx ~S I 7" 26.0# J-55 -Surf 8756' 8-1/2" 775 sx Class G & 150 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8381' 8082' & 8360' Perforated w/12 spf, 120° phasing 8200 ' -8304 'MD/5926 ' -5994 'TVD 26. ACI D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Perforated w/4 spf, 0° phasing See attached Well ,~ervice report, 8434 ' -8442 ' MD/6081 ' -6087 'TVD 8460'-8500'MD/6099'-6126'TVD dated 11/25/83,. fo stimulation data. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A . . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZEIGAS'OILRATIO TEST PERIOD ~l~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneDEC - 7 .,:~,i~sl.',~ 0il & ~s Con:. C0mmiss;~ * NOTE: Drilled RI~ 9/19/83. Perforated well and tubing run 10/26/83, Added perforations 1/23/83, Stimulated well 11/25/83. Reperforated 6/17/84. Converted to water injector 8/12/85. Workover performed 10/29/88. Form 10-407 WC5/042 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 8201' 8293' 8418' 8575' TRUEVERT_ DEPTH 5925' 5987' 6070' 6179' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Service Report (dated 11/25/83) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, a~r injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc.~ Sul:?dlary of Atlantic Richfield CompanY" ~ Q//'~//~' -"-/,~:/_~/ Pa ! I FIELD. DISTRICT- STATE / F ' I I I ,~' 4.';,¢ I ~ ~ ,~ ,+z. ~ ~c cO.I~T-RACTOR t ~ .. IOPERATION AT BEPORT TIME REMARKS I/~ELL SERVICE REPORT !DAYS IDATE' I /i.z~'.~, I111 /~ CHECK THIS K IF SUMMARY CONTINUED ON BAC ReportWeather I Temp' 'F' I Chill Fam°r I Vi'lbillty-- ~ ~'/'F mi. IWind vel' knot~ STATE OF ALASKA ~-'" ALA,_. ,A OIL AND GAS CONSERVATION COMMIS,,. jN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pedof~te __ Pull tubing __ Alter casing __ Repair well __ Pull tubing __~_ Other~ WORKOVER 2. Name of Operator ARCO Alaska, inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 511' FNL, 504' FEL, Sec.19, T11N, RIOE, UM At top of productive interval 3645' FSL, 3667' FEL, Sec. 18, TllN, RIOE, UM At effective depth 3923' FSL, 3860' FEL, Sec.18, TllN, RIOE, UM At total depth 3988' FSL, 3902' FEL, Sec.18, TllN, RIOE, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 109' 7. Unit or Property name Kuparuk River Unit 8. Well number 1F-11 9. Permit number/approval number 83-115/8-704 10. APl number 50-- 029-20993 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 8787 ' MD feet Plugs (measured) 6332 ' TVD feet None Effective depth: measured 8674 'MD feet Junk (measured) None true vertical 6250' TVD feet Casing Length Size Cemented Structural Conductor 80' 16" 175 sx CS I I Surface 2512' 9-5/8" 1100 sx AS i I I Intermediate & 250 sx AS I Production 8727' 7" 775 sx Class G Liner & 150 sx AS I Perforation depth: measured 8200'-8304' MD, 8434'-8442' MD, 8460'-8500' MD Measured depth 107 ' MD 2543 ' MD 8756'MD True Vertical depth 107 ' TVD 2187'TVD 631 O' TVD true vertical 5926'-5994' TVD, 6081'-6087' TVD, 6099'-6126' TVD 13. Tubing(size. grade, and measured depth) ~..'; .: - ::: :%/" '~ ~' . 3-1/2", J-55. tbg w/tail ~ 8381' ' Packers and SSSV (type and measured depth) Camco 'TRDP-1A' SSSV ~ 1799', Camco 'HRP-1-SP' pkr ~ 8082', & Baker 'FB-I' pkr ~,~836..0' Stimulation or cement squeeze summary K /A I ntbrvals treated (measu red) Treatment description including volumes used and final pressure DEC - 7 1988 oil & Gas C0n:. C0mmissMi A~ichurag~ 14. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run. __ Daily Report of Well Operations%~__ 16. Status of well classification as: Oil __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Water I n'jector Signed ¢ ~ ~ / Form 10-404 Rev 06/15/88 Title * Workover Well History Area Drilling Engineer (Dani) SW03/064 Date 1,'~ SUBMIT IN DUPLICATE ARCO Oil and Gas Company,~,'~' Well History - Initial Report - Daily Inalructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough IState NORT_u_ _~LOPE ~ AK ILease or Unit ~nm., 956K_9 ITitle WORKOVER ARCO A!~--°t'~. Inc_ Field Auth. or W.O. no. I Well no. iF-!! Operator Spudded or W.O. begun _~_CCE?T Date and depth as of 8:00 a.m. 10/27/88 ( TD: 8787 PB: 8674 SUPV:JH 10/28/88 ( TD: 8787 PB: 8674 SUPV:JH 10/29/88 ( TD: 8787 PB: 8674 SUPV:JH API' 50-029-20993 I ARCO W.I. }Date ....... IHour IPriOr status if a w'O' ' 19127/88 9!45 [i ompleterecordforeachdayropo~ed ~RDT~ 1 DISPLACE WELL W/ll.7 PPG MW:11.7 WBM . MIRU, ACCEPT RIG AT 0145 HRS, 10/27/88, PULL BPV, DISPLACE WELL W/ 11.7 MUD DAILY:S21,000 CUM:$21,000 ETD:S21,000 EFC:$190,000 POH W/ 3-1/2" TBG CO COUPLINGS MW:11.7 WBM CIRC. WELL W/ 11.7 PPG MUD, SET BPV, ND TREE, NU BOPE, TEST BOPE, PULL TBG, SHEAR OEJ, SET STORM PKR, CHANGEOUT TBG HD, NU BOPE, POH W/ 3-1/2 TBG CHANGING OUT COUPLINGS DAILY:S34,752 CUM:$55,752 ETD:S55,752 EFC:$190,000 RIH W/ 3-1/2" TUBING MW:11.7 WBM CONT. POH W/ 3-1/2" TBG, CO COUPLINGS, PUMP 20 BBL SLUG OF 12.5 PPG, FINISH POH, PULL WEAR RING, RIH W/ 3-1/2" COMPLETION DAILY:S32,791 CUM:$88,543 ETD:S88,543 EFC:$190,000 The above is correct ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submil Ihs "Final Report" on the tirst Wednesday after allowable has been assigned or well ia Plugged, Abandoned, or Sold. "Final Reporl" shou d be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an olflclal tesl Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~CO A'laska, Inc. Field KUPARUK RIVER UNIT AUth. or w. ,(~§.552 Operator 3LRCO Accounting cost center code Lease ~i[ 25652 1F-11 Title WOI:;~OVE R API: 50-029-20993 state no. IA-R'C°5~/?0000 Dat~' 10/27/88 Complete r[~¢Df~ea~h day reported Spudded o r~[Vc%l~[I~ n Date and depth as of 8:00 a.m. 10/30/88 ( TD: 8787 PB: 8674 SUPV:JH I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I °u~)145 HRS IPrlor status If a W,O. RIG RELEASED MW: 0.0 DIESEL CONT. RIH W/ 3-1/2" COMPLETION, TEST TBG, TEST TBG HGR, TEST ANNULUS TO 2500 PSI FOR 30 MIN, TEST SSSV, SET BPV, ND BOPE, NU TREE, TEST TREE TO 5000 PSI, DISPLACE WELL W/ 315 BBL H20 FOLLOWED BY 295 BBL OF DIESEL, SET BPV, RELEASE RIG AT 2400 HRS ON 10/29/88. NOTE: CAMCO 'TRDP-1A' SSSV @ 1799', CAMCO 'HRP-1-SP' PKR @ 8082', BAKER 'FB-i' PKR @ 8360', & TT @ 8381'. DAILY:S61,577 C0M:$150,120 ETD:S150,120 EFC:$190,000 Old TD I New TD I PB Depth I I Released rig I Date IKInd of rig Classilications (oil, gas, etc.) Type completion (single, dual, otc.) Producing method Official reservoir name(s) Potential test data Well no. Date' ~Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct S,ona,u,e I / For form preparatiory~ di;tril:fution, see Procedures Manbe~'Section 10, Drilling, Pages 86 and 87. "-"' STATE OF ALASKA '-'-" AL/-,oKA OIL AND GAS CONSERVATION COMMIo.,~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend __ Alter casing g Repair well Change approved program ~ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. 0. Box 100360~ Anchorages, 4. Location of well at surface AK Operation shutdown __ Re-enter suspended well m Plugging ~ Time extension __ Stimulate __ Pull tubing _~_ Variance ~ Perforate ~ Other i5. Type of Well: Development ~ Exploratory __ I Stratigraphic.~_ 9951 0 03 60 Service ~ 511' FNL, 504-' FEL, Sec.19, T11N, R10E, UM At top of producbve interval 3645' FSL, 3667' FEL, Sec.18, T11N, RIOE, UN At effective depth 3923' FSL, 3860' FEL, Sec.18, TllN, RIOE, UM At total depth 3988' FSL, 3902' FEL, Sec.18, TllN, RIOE, UM 6. Datum elevation (DF or KB) RKB 109' 7. Unit or Property name Kuparuk River Unit 8. Well number 1F-11 9. Permit number 8_~-1 15 10. APl number 50-- 029-20993 11. Field/Pool feet Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 8787 ' M D feet Plugs (measured) 6332 'TVD feet None Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 80' 25;12 t 8727' measured true vertical Tubing (size. grade, and measured depth) 8674 ' MD feet Junk(measured) 6250 ' TVD feet None Size Cemented Measured depth True vertical depth I 6" 1 75 sx CS I I 1 07 ' MD 9-5/8" 1100 sx AS I II 2543'MD & 250 sx AS I 107'TVD 7" 775 sx Class G & 8756'MD 150 sx AS I 8200'-8304', 8434'-8442', 8460'-8500' 5926'-5994-' 6081'-6087' 6099'-6126' 3-1/2", 9.3#, J-55, tubing w/tail @ 8372' ' · ' /¢'~¢ Packers and SSSV (type and measured depth) TRDP-1A 5SSV ~ 1910', HRP-1-SP pkr ~ 8089'; Baker FB-1 pkr @ 8367' 13. Attachments Description summary of proposal ~ Detailed operations program g BOP sketch 14. Estimated date for commencing operation October 19~ 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Service Gas ~ Suspended i Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~f ' FOR COMMISSION USE ONLY Conditions approval: Notify Commission so representative may witness ( J C ) $ A 3 / 0044 I Approval No. ~",_ .,,~ Plug integrity i B.OP/Test Subsequent form required 10- ~ ' _, Mechanical Integrity Tes~,~. -- Location clearance __ .. /_./ :-,'~pprovecl Copy Retur~e~ Approved by order of the Commissioner ~t.4--~ k//~ Commissioner Form !0-403 Rev 06/15/88 Date ¢~ / ~'-- ~¢ SUBMIT IN TRIPLICATE KRU 1F-11 General Workover Procedure Changeout of Wellhead and Couplings Pre-Rig Ooerations 1. Open C Sand. 2. Set plug in D-Nipple to isolate A-Sand. 3. Obtain C-Sand BHP after seven days. 4. Ck)se C Sand. Rig Operations 1. -3. . Se MIRU Nordic #1. Displace well with completion brine. ND tree. NU ELOPE. Pull tubing hanger to floor, pickup storm packer and set below hanger.l'. Changeout the tubing hanger to 5000# equipment. Pull storm packer. POOH with tubing, changing couplings to AB Modified. Rerun completion assembly. Release rig. Completion Fluid = NaCI/NaBr Expected BHP = 3aoo Psi Anticipated Start Date = (/o //'t/.,~ ) ANNULAR PREVENTER § PIPE RAI'IS 4 BLIND RAHS 5 TUBING HEAD · , , . 10. 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSI STARTING HEAD 11, 3, 11"-3000 PSi X 7-1/16"-5000 PSI 12. TUBING HEAD 13. 4, 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 14, 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMLILATOD RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES, 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 WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. OPEN PIPE RAMS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR lO MINUTES, BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE 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 BORE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. J6 JULY 28, 1986 (NORDIC RIG 9-5/8") ATTACttMENT 1 PAGE 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FIRST QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES NUMBER NUMBER INITIAL PROFILE,/ PROFILE/ PROFILE/ COMPLETION TAKING 50-029 INJECTION SURVEY SURVEY ~URVEY WATER INJECTION BWPD '>~1A-13 20700 02/0h/83 03/26/87 SPINNER FOLLOWUP A&C SS A&C /~1A-15 20711 03/01/83 03/25/87 SPINNER FOLLOWUP A&C SS A&C '~1F-02 20881 10/15/85 01/13/87 SPINNER FOLLOWUP A&C SS A&C 1F-05 20807 10/28/85 03/08/87 SPINNER FOLLOWUP A&C SS A&C ~'~"1F-10 2098~ 08/13/8q 01/27/87 SPINNER FOLLOWUP A&C SS A&C "~1F-11 20993 08/12/8~ 03/09/87 SPINNER FOLLOWUP A&C SS A&C 'X'1F-13 21020 08/16/8h 03/19/87 SPINNER FOLLOWUP A&C SS A&C 10-09 21001 09/15/81~ 02/23/87 SPINNER FOLLOWUP A&C SS A&C "-.----/ 1G- ltl 21017 08/2tl/8tl 02/2h/87 SURVEY FOLLO~UP A~C SS C 9100 ~1R-15 21387 11/10/86 02/25/87 SPINNER INITIAL A~C SS A~C . .--~ .... 2T- - - -~-~ 16' 85: ~'~:0~~ - ~.~U~EY';~%~'~ ~FOLLO~'UP": .... ,~-S~ ,,~,; '., ~260~ ska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton· Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1987. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have an~ questions concerning the information reported, please contact me at (907) 263-4262. Sincerely, B. B. Berg ~ Operations Engineer BBB/SPT:pg:O069 Attachments d O: 1907 Alaska 0ii & Gas Corm. Commi~si0n Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany May ~ V.' Chat.'.- ,ton · 1986 ",.i~-' Page 2 · ATTACHMENT I ~ .-.v. r KUPARUK RIVER UNIT INJECTIO~ LOGS _ . ,-,~_ ,_ ~.. ._~ ..... 'j~. ~..~INITIAL INJECTION PROFILE~'::~:':-~ Well Number Date of Initial Injection Date of Injection Profile 1A-7 3/21/83 3/25/83 1A-9 3/1/83 3/22/83 1A-11 3/7/83 3/21/83 1A-12 3/1/83 3/6/83 1A-13 2/4/83 10/17/83 1A-14 2/22/83 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 -- 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 '1E-23 1E-27 · . 1E-30 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Well Number Date of Initial Injection Date of Injection Profile 1F-10 8/13/84 10/30/84 ~ :IF'I I- 8/12/84 9 / 24/84 1F-13 8/16/84 9/25/84 1F-15 8/16/84 9/26/84 - .Well Number Date of Initial Injection Date of Injection Profile ~ 1G-3 1G-6 1G-9 1G-i4 1G-16 10/25/85 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 ARCO Alaska, Inc.~ Post Office I~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE 01-28-86 TRANSMITTAL ~ 5533 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 /TrAnchorage AK 99510-0360 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ One * of each /~F-11 5" DIL/SFL 12-05-85 Run #1 0150-8588 2" DIL/SFL 12-05-85 Run $1 0150-8588 5" Den/Neu (poro) 12-05-85 Run #1 7750-8563 2" Den/Neu (poro) 12-05-85 Run ~1 7750-8563 5" Den/Neu (raw) 12-05-85 Run #1 7750-8563 2" Den/Neu (raw) 12-05-85 Run #1 7750-8563 Cyberlook 12-05-85 Run #1 7950-8300 5" DIL/SFL-GR 12-11-85 Run ~1 2" DIL/SFL-GR 12-11-85 Run #1 5" Den/Neu (poro) 12-10-85 Run ~1 2" Den/Neu (poro) 12-10-85 Run $1 5" Den/Neu (raw) 12-10-85 Run #1 2" Den/Neu (raw) 12-10-85 Run #1 Cyberlook 12-10-85 Run #1 5" DIL/SFL-GR 12-19-85 2" DIL/SFL-GR 12-19-85 5" Den/Neu-GR (poro) 12-19-85 2" Den/Neu-GR (poro) 12-19-85 5" Den/Neu-GR (raw) 12-19-85 2" Den/Neu-GR (raw) 12-19-85 Cyberloo~ 12-19-85 1650-7565 1650-7565 3800-7332 3800-7332 3800-7332 3800-7332 3800-7332 Run #1 1690-8089 Run #1 1690-8089 Run #1 4490-8064 Run #1 4490-8064 Run #1 3647-8064 Run #1 3647-8064 Run #1 7250-8089 '3F-12 ~/ 3F-13 Receipt Acknowledged: State of AK*bl/se NSK Clerk*bl Alaska 0il & Gas Cong. Commission Drilling*bi Rathmell*bl D & M*bl Vault*films ARCO Alaska. Inc. is a Sul3$idiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office'~ '~( 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 12/20/84 Transmittal No: 4926 RETURN TO:' ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box~100360 T~r~ns/~mchorage, AK 99510 itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. - 'su smw s Camco iG-10 12/05/84 " 1F-9 12/04/84 " 1F-8 11/27, 28/84 " 1H-4 11/25/84' /cat Receipt Acknowledged: B. Currier D~illing BPAE Geology Chevron Mobil D & M NSK Ops. 1985 DISTRIBUTION W. Pasher G. Phillips Phillips 0il J. Rathmell Anchorage State of AK Sohio Union Well Files ARCO Alaska, Inc.~-.. ~-.-.:.~ O~.~:e _~× 360 AT;chorage. Alaska 99510 Teiephone 907 277 5637 Date: 8/17/84 Transmittal No: 4690 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 tted herewith are the following items. Please acknowledge receipt urn one signed copy of this transmittal. PL FINALS/Schlumberger 1E-30// EPL "Spin/Temp/Tracer" ~ 1F-11/ EPL "Tracer" lF-16 w' EPL "Temp/Tracer" ~2A-3 / EPL "DDL/Tracer" 2A-3 CL Cement Retainer S&Sq. Gun "CBL" 2A-3 ~ CCL & Perf. Record 2A-3 CCL Cement Retainer "~L/RTS/CBL" Run 4 5/26/84 6750 - 7080 Run 1 6/24/84 8150 - 8550 " 6/23/84 8000 - 8809 " 6/11/84 6700 - 7050 Runs 1-3 6/15/84 Run 1 6/17/84 " 6/15/84 6850 - 6975 2A-3 CCL Product. Packer I "RTS/CBL/Perf" ~2A-4/ EPL"GR/CCL/Tracer" " 6/18/84 6880 - 7010 " 6/08/84 7730 - 7950 /cat ~ Receipt Acknowledged' B. Adams F.G. Baker P. Baxter BPAE DISTRIBUTION D &l~ Drilling Geology -Mobil W.¥. Pasher G. Phillips Phillips Oil J.J, Rathmel! C. R, Smith Sohio Union Chevron Well Files · ~ ARCO Alaska, In¢ ~-...= Off.'c~_ ec, x 36~ ;-.r,c.ho:age. Alaska 995~0 ~elephone 907 277 5637 Date: 9/04/84 Transmittal No: 4712 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 mitted herewith are the following items. Please acknowledge receipt eturn one signed copy of this transmittal. PRESSURE ANALYSIS/PBU SURVEYS & SEQUENCE OF EVENTS 1E-12~ PBO "BOOm'! 8/17/84 1E-15~ .... S'Ti~'iE~-~HP 8/05/84 1F-2 ~- SIBHP 6/04/84 1F-3f' ~,~B~ 4/30/84 1F-4~ SI~HP 6/04/84 1F-5-' ,;-/_~U.f'~ 5~08~84 1F-6 ~ SIB~ 6/05/84 1F-? ~' SlBHP 12/19/83 1F-7-'- SIB~? 6/05/84 1F-7-- SI~? 4/30/84 1F-9~ GAS LIFT SURVEY 4/29/84 1F-9~' .... ~PBU/DRAWDOWN SAND 12/26/83 1F-10 ~'[i~P~U/DR~WqS-6~ 12/20/83 1F-10--~ D?~_WDOWN 12/21/83 1F-11-. ~BU~-~ 12/23/83 1F-11--~CPBU/DRA-~-~WN-~-3/15/84 1F-11-~' '~BO/DRAWDOWN~ 12/24/83 1F-12 ._- PBU/DRAWDOW-N-A 3/09/84 1F-12~' ~Bu-"A" SAND-/> 7/03/84 1F-12'- PBU/PDD 3/10/84 1F-12~ PBU/PDD "A" 3/09/84 1F-13~-~ C~f0-"A" S.a_ND?3~ 5/03/84 1F-137-~/ SIBHP_-_NEW_JLC]' 1/26/84 1F-16~~ "A" SAND__> 5/04/84 Receipt Acknowledged: 1F-16w" 1F-16 -- /cat DISTRIBUTION B. Adams F.G. Baker D&M Drilling P. Baxter Geology BPAE Mobil LOGS & PBU_"A" SAND ~/04/84 , ~ . Date' .-, '~ ;~_~,,~ --~ · ' ' W.V. Pasher C. R, Smith G. Phillips Phillips Oil State-of Alaska Sohio J.J. Rathmell Union R & D Well Files Chevron KSK Opera tions ARCO Alaska, ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 21, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent following wells at the Kuparuk River Well Action 1F-2 Fracture 1F-10 Conversion 1F-11 Conversion 1F-13 Conversion 1F-15 Conversion 1G-3 Fracture 1G-4 Fracture 1G-5 Fracture 1G-6 Fracture 1G-6 Conversion 1G-9 Conversion 1G-14 Conversion 1G-16 Conversion 2C-7 Fracture If you have any questions, please call notices on the Field: Date Performed 8/23/84 8/13/84 8/12/84 8/16/84 8/16/84 8/10/84 8/3O/84 8/10/84 8/12/84 8/28/84 8/24/84 8/24/84 8/24/84 8/14/84 me at 263-4253. Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASK/~ OIL AND GAS CONSERVATION ~OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~( OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, 4. Location of Well SURFACE LOCAT I ON. 511 ' T11N, R10E, UM BOTTOMHOLE LOCAT ION- T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 109 ' , 12. ALASKA 99510 FNL, 504' FEL, SEC. 19, 778' FNL, 4100' FEL, Sec. 7. Permit No. 8:3-115 8. APl Number 50- 029-20993 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 1F-11 1 8 11. Field and Pool KUPARUK RIVER FI ELD I6. Lease Designation and Serial No. KUPARUK RI VER O I L PAD 80' ADL 2.~.~ ALI( ?5'78 POOL Check Appropriate Box To Indicate Nature'of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). q , On August 12, 198/5/', Kuparuk well to a water injector. No downhole being injected into both the "A" 1F-11 was converted from a producer changes were made and water is and "C" sands. 14. I hereby certify that the foregoing is true and correct to 'the best of my knowledge. Signed Title OPERAT IONS COORD ! NATOR The space below for Commission use 9/19/84 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir/~'''' Post Offic= ~Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 10, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached following in duplicate are subsequent notices on the wells at the Kuparuk River Field: Well Action Date Performed 1F-11 Fracture 6/25/84 1F-12 Perforate 6/29/84 1F-12 Fracture 7/08/84 1G-6 Re-perforate 8/01/84 1G-7 Fracture 7/29/84 1G-8 Fracture 7/23/84 2B-7 Perforate 7/24/84 2B-8 Perforate 7/25/84 2B-9 Perforate 7/27/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED AUG l Oi~ ¢x Gas Cons. Commissior~ ,~.achomge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~--~ ALASK~ OIL AND GAS CONSERVATION t~OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. N~r~:C~)p~E~,al~s KA, INC. 3. A~r. eSSO o BOX 1 00360 , ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 511' FNL, 504' FEL, SEC. 19, T11N, R10E, UM BOTTOMHOLE LOCATION- 778' FNL, 4100' FEL, Sec. 18, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 109', PAD 80' 6. Lease Designation and Serial No. ADL 25652, ALK 2578 7. Pe~r~it~o1 5 8. AjDI2.g.,_..2,.0p ~h,,.,-,~.r 9 9 S 50- 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL 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 [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation J~ Abandonment Repair Well [] Change Plans [] Repairs Made -;~ Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 25, 1984, the "A" sands of Kuparuk well hydraulically fractured and propped to improve treatment consisted of 326 BBLS of gelled water fluid and 25,000 LBS of 12/20 sand as proppant. 1F-11 were production. The as pad and carrying Prior to pumping, equipment and sand was tagged with R.A. tracer performance. lines were tested to 5540 psi. The to aid determination of job RECEIVED ALJG 1 ]984 Alaska 0il & Gas Cons. Commission Anchorage 14., hereby certify that the foregoing is true and correct to the best of m~,~O~/~.K j~~.,~/~ OPE RAT IONS COORD I NAT OR Signed Title The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission 8/10/84 Date ..... I Form 10-403 Rev. 7-1 °80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In( Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 25, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are notices .of intention to convert Kuparuk wells from producer to water injection: 1F-10, 1F-11, 1F-13, 1F-15 1G-6, 1G-9, 1G-14, 1G-16 If you have any questions, please call me at Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) the following 263-4253. RECEIVED JUL ~984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AllanlicRichfieldCompany ~-~. STATE OF ALASKA ~ ALASKA IL AND GAS CONSERVATION C ¢IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WELL FNL., 504' FEL, SEC. 19, 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-115 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20993 9. Unit or Lease Name KUPARUK RIVER UNIT 4. Location of Well SURFACE .LOCAT I ON: 51 I ' T11N, R10E, UM BOTTO~-iOLE LOCATION' ~778' FNL, 4100' FEL, Sec. 18 T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 109', PAD 80{ OTHER D 4~ 6, Lease Designation and Serial No. ADL 25652, ALK 2578 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OI1' 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 [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 1F-11 be converted from a producer water injection well. Currently the well produces from both the "A" "C" sands. Downhole equipment will be unaltered and water injected both sands. to a and into ANT I C 1 PATED START DATE' August 13, 1984 uooectuent Work l{eported RECEIVED J U L 2 5 1984, Alaska 0il & Gas Cons. commission Anchorage 14., hereby certify~/~ ~ -~/~that the foregoing j,s true and correct to the best Of m~l~,~K /~ ( ~'--'~L:x'~////"~ ~ r~ ~/'/~ OPE RATIONS C OORD I NAT OR Signed , Title The space below for Commission use Date 7~25~84 Conditions of Approval, if any: Approved by 91' LON~IE C. SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field: Well Action Date Performed 1F-1 Fracture 6/1 0/84 1F-3 Fracture 6/11/84 1F-5 Fracture 6 / 12 / 84 1 F-9 Perforate 6/16/84 1 F-9 Fracture 6 / 19 / 84 1 F-1 0 Perforate 6/14 ! 84 1F-1 0 Fracture 6/1 8/84 1F-11 Perforate 6/19/84 1F-1 3 Per forate 6/19 / 84 1F-1 4 Perforate 6 / 22 / 84 1F-1 4 Fracture 6/23 / 84 1F-15 Per forate 6 / 17 / 84 1F-1 5 Fracture 6/21/84 1 F-16 Perforate 6 / 19! 84 1G-7 Choke 5 / 4/84 1G-1 0 Perforate 5 / 29/84 1G-1 0 Fracture 5 / 30 / 84 1G-12 Perforate 5 / 29/84 1G-12 Fracture 5/31/84 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA --- ALASKA L AND GAS CONSERVATION CL 'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION- 511' FNL, 504' FEL, SEC. T11N, R10E, UM 19 BOTTOMHOLE LOCATION' 778' FNL, 4100' FEL, Sec. 18 T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 1 09' 12. 7. Permit No. 83-115 8. APl Number 50- 029-20993 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL , PAD 80' ADL 25652, ALK 2578 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations E~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Farm 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). On June 19, 1984, the "A" sands of Kuparuk well 1F-11 were to optimize stimulation. After testing the lubricator to well was shot with a wireline conveyed gun. The well was to improve'hole orientation for upcoming fracture treatment. Interval (MD)- 8460' - 8500' (2 SPF) re-perforated 3000 psi, th re-perforate, RECEIVED J U L 0 3 ]984 Alaska 0il & Gas Cons. Commission Anchorage Signed Title . OPERATIONS COORD I NATOR The space below for Commission use 6/28/84 Date ,~ Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Dale Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir Post Office. Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 19, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are notices of intention to stimulate Kuparuk wells 1F-11 and 1F-12. If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JUN 91984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... ALAS~~ DILANDGAS CONSERVATION '~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLI~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-115 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20993 9. Unit or Lease Name 504' SEC. KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION- 511 ' FNL, FEL, 19, T11N, R10E, UM BOTTOMHOLE LOCATION' 778' FNL, 4100' FEL, Sec. 18 T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 109', PAD 80' 6. Lease Designation and Serial No. ADL 25652, ALK 2578 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL 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 [] AIt~r Casing [] Perforations [] Altering Casing Stimulate ]~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1F-11 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant and pre/post frac logs are included in the treatment program. Fluid. 400 BBLS water Proppant- 24,000 LBS 12/20 sand RECEIVED JUN ! 9 ],984 Almmi(m 011 & Gas Cons. Commission ANT I C I PATED START DATE- June 2 2, 1 9 8 4 Anchorage 14.1 hereby certify that the foregoing is true and correct to the best of m~O~:~X~.~k The space below for Commission use Date 6/19/84 Conditi'ons of Approval, if any: Approved by Approved C.,_: :; ',' Returned __ By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir' Post Offic= Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 15, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are notices of intention 1F-11, 1F-12, 1F-13 and 1F-16. to perforate Kuparuk wells If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED J U N ! ~' ]984 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~. ALAS , OIL AND GAS CONSERVATION OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-115 3. Address 8. APl Number P, O. BOX 100360, ANCHORAGE, ALASKA 99510 50_029-20993 9. Unit or Lease Name 504' SEC. KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCAT I'ON: 511 ' 'FNL, TI'IN, R10E. UM FEL, 1 9, BOTTOMHOLE LOCATION' 778' FNL, 4100' FEL, Sec. 18 T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etC.) I 6. Lease Designation and Serial No. RKB 109', PAD 80' I ADL 25652, ALK 2578 12. 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER F! EI.D KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate jX~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon I-3 Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] - Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 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). it is proposed that the "A" sand in Kuparuk well 1F-11 be re-perforated to optimize upcoming stimulation. Procedures call for the well to be.' perforated with a wireline conveyed gun under a lubricator. PROPOSED INTERVAL (MD)- 8460'-8500' (2SPF) ANT ICI PATED START DATE- June 17, 1984 RECEIVED Subsequent Wor~k Reported JUN 1 1984 Alaska 0ii & 6as Cons. Commission Anchorage 14.1 hereby certify~ ,¢~/¢that the foregoing is true and correct to the best of r~Lik~k Signed //'//~~~ Title O PERATI O NS COORDINATOR The space below for Commission use Date 6/15/84 Conditions of Approval, if any: ORIGINAL StGII[B'_ 8Y l. OfiHiE C. SlglTll Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Date ........... Submit "Intentions' in Triplicate Form 10403 : Rev. 7-1-80 and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING Date: ~, Cl~ Well Name: Transmittal Date Run ~L , ~/~o ~/,~ I ' °/, o / ~ I (°12-/~ 3 I Ioq.fl, n q com. pSrw,.,l ,, DISTRIBUTION NSK Operations Dr il 1 ing Geolbgy /Ken State of AK Bluel~ne Bluel ine Film Blueline & Sepia n & return ~'e copy as receipt of" '! ,,: :,, " ~,,,, "95'. , .... Return to: ARCO ALASKA, INC. ATTN: yAu~ ~.w¢~r;~ ATO-1115B ?.0. Box 100360 Anchorage, AK 99510 mw 'F'INI~ L KUPARUK ENGINEERING These prints replace the previous ones sent in January, 1984, please destroy the old p~ints as the elevation numbers were in- ' correct. Date: ~- ~-~< Well Name: ,.~~~~ DISTRIBUTION NSK Operation Blueline Dr i~l ing Bluel ine Geology/L. J. B1/Se R&D Blue! ine cs~te .~. Baker Blue. line D.B. Schaf er Blueline G eology/Ken Film Sign & return the attached copy as re~.ce~pt of,aa"'' .... t,a ...:'';i \!'~'~"i-~., J Return to: ARC0'ALASKA..,.;orI~Ci ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 OHFinal KUPARUK ENGINEERING · . Well Name Transmittal Date Run ~ DISTRIBUTION NSK Operation Blueline -Dr i%1 ing - Blueline Geology/L. J. Bi/Se . R&D Blueline D&M ... Blueline State Bi/SE F.G. Baker Blueline D.B. Schafer Blueline G eology/Ken Film Sign & return the attached copy as receipt of data. Return to: ARCO ALASKA, INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK Ei~GINEERING TO' ~~ FROM: D. Fay A1 lison WELL NAME' soe below Transmitted herewith are the following: PLEASE NOTE'~- BLUELINE~ SEPIA, F - FILM, T - TAPE, PC - PtlOTOCOPY Well Descript ion /~/--' ~ L~. //-_/~ ~ ,, Dar e Bun ~//PLEASE RETURN RECEIPT TO- ARCO ALASKA, IliC. ' :' ':'~-'' '"-,'.!!~i -'~-,,.~ ATTH' D. FAY ALLISON-- ATO/l115=B ..~....~,.;....,.. i;c:n.m,' ..... :,~,~ P. O. BOX 100360 .. -.~, .... ~' ~' AK. 995].0 Ah~.HO~,,~oE, ARCO Alaska, inc. Post Office b .... 360 Anchorage, Alaska 99510 Telephone 907 277 5637 L. January 9, 1984 Chat Chatterton State of Alaska Oi 1 and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat' Commission Attached in duplicate are subsequent on the following wells at the Kuparuk Well 1F-10 :-Well 1F-11 Well 1F-12 If you have any questions, please call Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (Duplicate) notices of acid stimulation River Field' me at 263-4527. STATE OF ALASKA ' ¢''' ALASKA ~JIL AND GAS CONSERVATION CbMMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, TNC, 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 511' FNL, 504' FEL, SEC. 19, T11N, R10E, UM BOTTOMHOLE LOCATION' T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 109' PAD 80' 12. 778' FNL, 4100' FEL, Sec. 18, 6. Lease Designation and Serial No. 7. Permit No. 83-115 8. APl Number 50-029-20993 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL ADL 25652¢ ALK 2578 POOl 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 Puli. 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 Abandonment see 20 AAC 25.105-170). "C" Sand was stimulated with acid on 11-25-83 using not flowed prior to stimulation. Post stimulation of 2,812 BOPD, GOR 568. Volumes used: HCL 137 BBLS Nitrogen 1500 Gallons Diesel 23 BBLS 12.5% HC1. Well had well test showed rate RECEIVED ~ ,,'-, r, ~ "~; ;j 'if"-' lC', ¢,',-,., r 14. I hereby certify th, at the for~egoing is true and correct to the best of my knowledge. Signed ~~~~'~ WI~~' Title ~U~RUK The space below for Commission use OPERAT IONS COORD I NATOR Conditions of Approval, if any: By Order of COMMISSIONER the Commission Date ..................... Approved by Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. J ~ Post Office B,.._. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 9, 1984 Mr. C. V. Chatterton State of Al ask~. Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton: Attached are Sundry Notices of Intention fol lowing Kuparuk Wells: 2C-1 Mud Flush 2C-2 Acid Wash 1Y-2 Acid Stimulation 1Y-10 Acid Stimulation 1Y-15 Acid Stimulation 1F-10 Perforate "A" Sand 1F-11 Perforate "A" Sand 1F-12 Perforate "A" Sand for work on the If you have any questions, please call Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) me at 263-4527. ARCO Aiasks. inc. is a st;bsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-115 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20993 OTHER [] 4. Location of Well SURFACE LOCATION' T11N, R10E, 511' FNL, 504' FEL, SEC. 19, UM BOTTOMHOLE LOCATION' T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 12. 778' FNL, 4100' FEL, Sec. 18, I 6. Lease Designation and Serial No. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL RKB 10q'~ PAD 80' ADL 25652. ALK 2578 I POOl· CheckAppropriateBoxTolndicateNatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate the "A" sand with 4 SPF through-tubing guns at intervals of 8434' - 8442' and 8460' - 8500'. Expected start date' January 14, 1984 Subsequent W.o£k .~ep~orted on Form No./cd -~O~)ated -~'-~---'~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use 0 PE RAT I ON S COORDINATOR Conditions of Approval, if any: BY LOi'~NIE (L SJ~IIii Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate i KIJP~ EI'4S ! NEERING TRAI',~.AITTAL # ~.47 ~ TO: Wi ! I i am VanAi en FR~/I: D.W. Bose/Shelby J. Matthews DATE: WELL Transmitted herewi th are the fo ! I owing. PLEASE I',OT'E:~ BLUELINE,(~ SEPIA, F- FILM, T- TAPE, PC- R-tOfCX33PY RECE ! PT AE:KK~'¢! Fr'~ED: ' P~P~E RETURN RECEIPT TO: · ,' ' ..~-~'~- STATE OF ALASKA ALAS, ,L AND GAS CONSERVATION ..:MISSION WELL COMPLETION OR RECOMPLETION' REPORT AND LOG 1. Status of Well Classification of Service Well OILYi~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-115 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20993 4. Location of well at surface 9. Unit or Lease Name 511' FNL, 504' FEL, Sec.19, T11N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 3645' FSL, 3667' FEL, Sec. 18, T11N, R10E, UN 1F-11 At"~'otal Depth ~' 11. Field and Pool 3988' FSL, 3902' FEL, See. 18, TllN, R10E, UM ~"~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKBI ADL 25652 AKL 2578 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. ] 15. Water Depth, if offshore 116. No. of Completions 09/10/83 09/17/83 10/26/83I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8787'MD,6332'TVD 8674'MD,6250'TVD YES IX1 NO []I 1920 feet MD 1450' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/VDL/CCL, Gyro, CCL/Temp. Log. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 107' 24" 175 sx CS II 9-5/8" 40.0# J-55 Surf 2543' 12-1/4" 1100 sx AS Ill & 250 sx AS I 7" 26.0# J-55 Surf 8756' 8-1/2" 775 sx Class G & 1,50 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8200' - 8304' w/12 spf - 3-1/2" 8372' 8089' & 8;364' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE "~ 28. ; COP E DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate Rev. 7-1-80 GRUE/WC05 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 8201' 5925' Base Upper Sand 8293' 5987' N/A Top Lower Sand 8418' 6070' Base Lower Sand 8575' 6179' I 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 ~l~T~ I~" ~"- - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". 1F-11 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1330 hrs, 09/10/83. Drld 12-1/4" hole to 2565'. Ran 65 jts 9-5/8" 40# J-55 HFERW BTC csg w/shoe @ 2543'. Cmtd 9-5/8" csg w/1100 sx AS III & 250 sx AS I. Bumped plug w/2000 psi - floats held - ok. Performed top job w/110 sx AS I. Instld FMC csg head packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to ~- ok. Cont drlg 8-1/2" hole to 8787' TD as of 09/17/83. Ran triple combo logs DIL/SFL/SP/GR/FDC/CNL Cal f/8781' to 2539'. Circ & cond hole. Ran 210 jts 7" 26# J-55 HFERW BTC csg w/shoe @ 8756'. Cmtd 7" csg w/775 sx class "G". Bumped plug w/3000 psi - floats held ok. ND BOPE. NU tbg spool. ~e$]~_ 7"__packoff to 3000 psi - ok. Displ 110' of fluid out of well. NU tree Secured well and released rig @ 0800 on 09/19/83. HILL/DH44 10/17/83 1F-11 COMPLETION SUMMARY RU Dresser-Atlas. Ran GR/CBL/VDL/CCL. Ran Gyro. Set master valve and tubing adapter. Secured well. Accepted rig @ 1230 hrs, 10/19/83. ND tree. NU BOPE & tstd - ok. Perforated the following intervals w/12 spf' 8284 - 8304 8264 - 8284 8244 - 8264 8230 - 8244 8210 - 8230 8200 - 8210 RIH & set FB-1 pkr @ 8364' Ran 3-1/2" completion assy. Ran CCL & temp log; found leak in pkr/exp~nsion joint. Pulled 3-1/2" tubing. Repaired leak. Ran 3-1/2" completion assy w/tail @ 8372', pkr @ 8089' & SSSV @ 1920' ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set p~r. Closed SSSV. Set BPV. Secured well & released rig @ 1200 hrs, 10/26/83. GRU5/CS03' tw 0 : 0 0 . '. · , . I<LIPARLIt< ':ii}':i'/: OCTOBER 3, 1983 .JOB NUHBER AK-BO-30104 ALASKA .... KELLY BUSHING ELEV = 10'.9,00 FT. ' ,~ .~_--..! ~'", ~'?'~ ~. .: ~'; .--. ~ ~ ~'~- ~L~.~.:;,..~ ~.,.,....~.,.....::.::..+;.;.!.:~p..:......~ :;~k~: ¥! ............................................~:.~. ili!i:i~ !!!' ii~' ~i'"'" ...... '~"'~" ................. ;£:' " ........ ~ ....... ~ ............ ~'~ .................... ~"'~"~' ''~ .................. *.~tT:~r..~i~i~!~:`.~T:~!~.~..`:..`..~;~.~`..~B~.`;.~1~%..`.~i~i~i!!i~.F..!.~.~:.i~.~.~.`:~~~~..~.~ :::::::::::::::::::::::::::::::::::::::::::::::::: ::?:"' ~'*:: "' ~:!' !" ' ::.uu:.!i:?r:i:.?.?.ii:..::i.~..~:~ ~ii::iii::::!~':~ ..~ . .,,,. ,.~ ::x.ii ........... ' ..... : ..... :I ~;;i~,~.:::~i~!~::"':;J::~:::' '"'" 'i ~ :~ '"' .... iii:. ...... !iilq"i'"'"!:''''ui~~i':iqlit:!;:::~:.:;ihi~ii!i:::; i~Z:;ii!::~i':i':~;ii:'ii:ii:::i"i :'.i~U':;i:i]i~::i!i ;ii n.~,.~;.,.::,,.~;:.= .~:~.....,.':.~;:,'.,:¢.p:'.~, ,~:~.::: :::::::::::::::::::::::::::::::..,.:.::..~::::::: ..............: .~:' ................... ~:~,~: ~::..fx.~:~::~::.:.,:::.~~:....: ::::::::::::::::::::::::::::::::~ .... .,. ................ ....... . ................................... ~.~.:~'.i::,~!,~:::.;,,;!::w,;r:.. ::..;..::. :.=;.:.:: ..:. *. .........: ...': ............. :.~ ."n~xii!'"':,.:: :~:::'..=':...:::'.:=': .:..,. .... . ..... ~ · :'. :.:' . .. :.,: . :., . · ... MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEO MIN DEGREES DEC/1CIO NORTH/SOUTH EAST/WEST SECT I ON ..... ~ ....'"" ..... ~'%z%., '""~-- .r_.,.b~,,.~ll Vq.. - .-' & . v,,/,%,,, "b" & & ~ ~ ~' l l ,,I. .~r I. 'v~.~ m %~'T 300 300.00 191.00 0 15 S 65.69 E 0.06 0.3S S 0.79'E -0.78 400 400.00 291.00 0 7 S 72,30 E 0.12 0.51 S 1.10 E ,-1.07 ~ ....~..~.x::~.r..~r:.::T..?..:`.~;``~;~:~?~..~`..j`~ji~.`.~:.:~..~:.~.~.~:~ i~~~.~~...~ ............................................. ~?. ;:~:~.'..!:'.,~;'.':...,:.~,~ ~:~ ............. ,:...~r::!,~i~.,::~.~i:..~::.'.'~,:~:.~!:i~ti~*.'.~.'..:~t.~;':'.::.'.'.::-.',~:i:.~?.'.:P*:'... :.:.~¢~¢~.~i~: ~M ~: ~:..'.~:::."":*::,:".':':'"*.':,:,,~'::.'::;:;~'.~.':.:'.:..'..,; .?..'.': ::?::~:::::.'.'.':;.= ........ ~':':':':' ": ~;: '" "~:'~ :' .... ~'";:" ' ;'.'t, :. :' j..,~,~®~.. ,..,:~:~:..,....~.,. ........... .,,,~ ..: ........ ~ ~ .... .~,,...~,,, ......... . ~. ~;..,.~,~., ......... ~, ........ ~...,,~.... ~ ............... , .............. ~:~,....~. ..... ~ .... ...... ..~.. ~ ...... ........... .,: ....... . .... ..: .......... . ..................... ~:::~ ....... ~. ................. : ..... :~:.~.:::~t;~ , ......................... ~.~,. ............................................................. .,. ......... ~ .......... ~ ~, ~. .~:,.,.:,:~.~ : . ................ ,.,,,,., , ..,~.._,,~ ,.;,,;, ~.._,,;, ,' ............. ~...; ................................ ,;i.:.:...~..;;:.:.$;,,:~....::~.~ ......... : ....................................................................... .,:..o.; ............................................... ,,- .............. . 900 896.75 787.75 12 28 N 42.60 N 3, 09 32.58 N 30.07 W 44.12 1000 993,6~ 884.6~ ~ 0 N 39.8.9 N 3.59 51.12 N 46.23 W 68.66 .................. :.,.~.:.:..:..~: ~ ~ '"'" ~ ~,~~!~~ ~j~..~:~.,~:~ ~.~: ~~:~ ~,~ ~~i~ ~!...,..~,~~~,: ."::"..:.J' '"~i:> ~::' '~. .,.::' :.,.:' ~::.~..:,~. ::::..: . .:':: ::::: ~.:..'. : ::: .::.::x.:~,..,/'.' .¢" ": · :i ~: ,. ;:::::::: :::p.~:x..::~:::~.~,.~:.' .' . ........................................... :;":""~'::::':~ ........................... ':140'""= ................... ~'q:'::~::~::o'~:~::~-''': ................ :~'~2~S'::~:S:::~i® ,~;r ._, "~ "*~..',' w ---..-. ........... 1~00 14.4.8, 87 1339, 87 31 3 N 39', 80 I,'J 2, 0"5 .202, 72 N 180,89' W 270, 7.9 1600 1534.04 1425.04 32 8 N 39~ 19 W 1.13 243.1~ N 214.21 W 323.13 ~ -,.-..~. . , ~ -~ .~, , =~..-. .-, ~ .~ ~- ~.~ o~., _ ....... m-.:~,.,..~-..~.~, '.~ ..................................... ~ - -~ ......... · '~::"::.:~ :-..:'. '.: '~ I .... .:: ...................... ~ ...... ~.,'~?~:.':. ~ ...... ~ ....... .~ ........ ~:.~.:' ?' :~;~" ::?~i~::~:~::~;!~:::i~i!:i~ ..... .......... , ...... t c~ ......... ~ -..~ ................ !~ ~, ~ ................ ~.i!:~::~j~:.~:::~:~,'.~ii~ ':~ i!ii! ~::~.: , . .... ~ 2100 1912.51 1803.51 49. 26 N 36.89 ~1 3.83 497.40 N 414.73 W 646.87 2200 1976.29 1867.29 5 ~ 16 N 36.39 W. 1 . 87 559.18 N 460.69 W 723.87 ~,~'=.,.~.r'~ -~,",-'~,"'. a-~ ~ ~',.'-',c'z . a.-, ~'4 ,=a ..,- .....e"~,, . ./ ~.~,.~. .... ~:, ,.., ~ ~,r ~-,,-,...,,~_~:..~],~,~,~:~ ~. ~!.~:.._.~..~'.-..'::~::::' ~.:::*:::~.*:r.?:::~*:*..`ss:::.:..::..;.~....-.~`-.~......::.~.~..:.:::.:~::.::::.?.:: .-d ... .. :i::~ %... t'~' ,~,......~.:._:........,/~,;~,~.-.-.,..:~.:~:.....~,-.-,--..-'.:. ....... ,~.~._.a..~'~._._,~.,~f~]i'ii"i"?~'~'~ '"'!'.~' '' "':"'" :~':':" ...... '"' "~": ":':';"'":" i "'"" ...... :' ',- ...... .x ~'~' ~'..; ,':.;.::' '.:~x.:,x, ,:.: :.::':: .~. ,':.,,~ .:.,, , ...~. :,,. :..~: ,,:,,-×...:.>:.:.:.:-:-,,.,...,.~-x~,,...:..~.. ~.-.,.,,.,...~'~......~ ....... , ...... ,......, -~'~*'"~,,~--.-~'"--~ ...... ~ ~,~,,.,,.., ---~-~;",,,'~ ........... .,r..,,.'~;'",,,~ ............... .-,,~ ............. i;';,' ................. :'"~ .... ~...,';~'~u~"i,i ........~"~'~'*t .... o.i.,o, z~ r,i o-to. ~ w / ~70,~ 22e2.4.7 2:1.?.~.7 ~3 3~ N 3~,:1.~'1,,! . :1..2.~ ~7'~.12 N , ~'.:;,:2.77 w 111~.0~ t 2800 2341.44 22~2.44 54 ;z N 35,50 W -'; , 0.7~ 944.99 N 739.49 W 1199.76 ~:i .. '.' ~'.:: ..~. ' :'. 4::; ::]f:i:::....i'i:!::~i!:!:!!!:~J~i:i:~i~f~:~i~: ~ii~:!i:i.~!.]!q..'.>.:.:.:...::i.i.i;!:!.!q!:i~:~?i;~!:i,'¢:'~.~:~:~.:,: .... :~:.:~:~1:.~:f:~.~...:~:~::.~:rJ.:~::~:~:::p~:~?~:::~;i~::i.:.:::..:!::::~!.~:i:.;!~i:~:!;i:]:!:F.:..~:~:!:i:i:~i:!.?::::.:::~]` ~.p:~:::.'.:.::.::~'...*:.*~¢:::~: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :'-.,' ;...:~ ...... '::'. - © 0 © I~..UPARUK OCTOBER ~, ! ~.7_:t JuB NUMBER AK-Bu-~O ! c 4 ALASKA . , "KELLY BUSHING ELEV. = 107.00 FT. JJ.]J~J~::i;ili:!!i!!: ' T J I'r'~/~J ~'~J~'J~'J:''''.'~ !::;:,. .: !: ',:,', '; !.~i!!.~.,.i~J:]:i!:~J~j(":;~'~'J~l ~l~ji:~i[~J~J~J'~ ~,.'~,:?~:.~.~j!j'~J~.:./~ iii . :i;!: ~: ::~ ., :;:,i: :'i' ' iii? . ?,!i~;' . ~' ',' . ..:~7hi!;!:!;~!~i~::i!~:/::i:~hi::i~ii:::~i;~!:~!!~!F!~!!:.~!E?~E!:~!~.~i~i~i!iF~!~.i!..~iii!!i~!i~ii~!{~`i~ii:i!!i~i!!~.F.!~ ~i!!!i".! !i::i!;:i: ?.ii..i'>i,ii:~:i',',i!:! ~ii;'.!Fih:,!,::i:?' '::,i i'::!':":: :i:.::: :.'! ,': ' MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH · DEG MIN ' DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION :;;::'::~:::.~:::;;t,::;:,;;;u ' '.!~ ~ ' :::::::::::::::::::::: !;' . ' :':,i':', , :ti:; :;.:'.i:'f:i ';::::::;?. :,f:' ",,~' .'.!' . :'!,' t': ,' ' ,~ , . 3300 2641.31 · 2532.31 52 7 N 33.89 N 0 ~ 48 1273.37 N 967.94 W 159~. 48 3400 2703.2& 25~4.2& 51 18 N 32, 1~ W 1,57 133~. 15 N 1010.74 W 1677.78 +.:. '.' :.'': ' ~ , ....... ' ' '. ''...'..~ ........... ~'." .'*''...'..~.-...~ ., '".' '..~::.'.' ' ::::::::::::::::::::::: ....... ,:~.~ ..:...::,~::~:::~ ........... ~ : ,~:~:.:,~:~ ....... ~ ......... ~ . ..~t**:~:... :~....:~:~***~:< ':':[:~:' ~ .:?:~ .... ~::~ :... ~>. ~?~?' '.:~:~:. ..................... ................ , ......... ...... :z . ................. ....................... J 3900 3018.77 2909.77 50 2 ! N 31,39 N O. 35 1669.36 N 1214.22 W 2063.90 ~ 4000 3083.3~ 2974.36 49 11 N 3~.,0 W 3.70 1732.87 N 1256.54 W 2140.09 ==================================== ' ::::::::::::::::::::: ..... .:- ::' ':':'::. ':'*~';"~:':"~::~:.. ::' ". :.":':' .:::::i:~:~ ::~:':~::' .::'::~: .' .:::::: ::? :::' :':~::~ ,:~? .> '::.'::~> .:' : :~,~, ~:::~:~ ::: .:::*::... ::'::: :::::::::::::::::::::::: ': ::: ::':.: ': ':. ~:':'" :'.:.: :: :~ ~'~ ' · : -- .,..+ .;.,-~..,.,..... -.., . ....<,;,.;-..~ ..<,.:.. ., .. ,..,,, .,.,,,~,~...,....., . ... .... ..,.,. .:..c,,~,~..~ ...,., ..,....~.a,..... -.... .... ...:,~ :.,,...,..,~. <,,.x+~<,....,.,~..,>..,,....:,.~,~,.,~ ....... :. ,. ....... ., ..~,.,.,...,:..........-.,...~ +.>.,,...x~..,...-,.,.~......,.,..,.,? ,......-........ · .. ~ . 4500 3409.50 3300.50 48 16 N 39, 0 H 0.38 2028, 16 N 1493.96 W 2518.82 ,) 4600 3476.29 3367, 29 47 54 N 39.30 W o. 43 2085.88 N 1540.95 W 2593.19 :::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::: ':.8~::%: :': ============================== :~:~', "'::':::'::::' ::::::::::::::::::::::::::::::::::: ':~:::::::~":" ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ....... ::::::::::::::::::::::::::::::::::::: ........ ~:~:~"?"~::%: ....... ========================================================================================= :::::::::::::::::::::::::::::::::::: ~'~ ::' '~': :; 5100 3818.3~ 370~.38 ~5 46 N ~.~0 ~ 0.6~ 2368.00 N 1771.~3 ~ 2957.53 ~200 3888. ~1 3779.51 45 9 N 40, ~0 W O. 6~ 2422, ~4 N 1817.70 W 3028.72 · ,'. ::, ' . :" ...' '.' . ::. " ' :: ":;~:.?: h:~ ::;' ' ~ ": ":' :~:~;;-~:: ........ "<- :::' :':¥.....>'~:: '>~:<.'.~.~-:> ~::~' '"u:::':' .> ".,. >.." "'. ~: :":"~:~:: ,~.l:.:~<~i'.~;:-:i~:::~::: ......... >. <.. '>'"' ~"'-;~" ':- -"'"'" '": ..' '-".'::.~>-:::'i:¢-~>>~ .......... :' "." ':.. .... :. · ;:.'.... :::.:~. '::' '~ ...... ..... ~ ................... ~ ..................... ~ ,.~.<~. .......... ~ ............................ ~ :~"~'~ .~¥ ...~ .... . ................ ~ .......... : ....... ..~...~<<,~.<..~<~. ................. ~ ........... . ............... ". · I ....'~ ...... -¥..<<:.~ ...... . :- .............. ~-~ ~ ~' '<~'~.~.~..~ ...... · ............. ~.:~::~.~ ..................... ~, · . ....... : .... :~¥~:'.~:>~.~ - . ....... '~'~ '.': ~.:~ ...... ~,- . . ~., .: · - . , -~ - -.,, .<. ,.:.- .,..: c .:.: -..,,~ ..:, :.~,~.:.,.x.~4~:,~,..~::. +.. ,::. : .. -.., .,,~,:-<~+:~,~ ,,- .:,. ~..,..--~... ~ ..~.:..,-.,¥~.: c.. ,,-~<~.~,~>,~.>...,.~,.,...,:,~>>~~,~:.<.~<.,> .::.:.~:.:,,..x.:,.:,>:.~.,,,..~...>::.~, .:...~,:<.~> +:+..,..:,...:.~.:...,:..:.........:.:,.~. · ..:.:,:..:. ..... · . . ; 5700 4251. ~4 4142. ~4 41 45 N 40~ 1~ ~ · 0,2~ 2~84.85 N 203~. 1~ W 3371.44 5800 4326.81 , 4217.81 41 17 N 40, 0 ~ .:. 0.48 .2735,55 N 2081.89 W 3437.~4 · < ..... - ::::: ............. :: c:?' .~ ~'.':~::' >..:.:::<.:,>..<.~:.>.~ .......... ~': ............... -~. ¥~:: .~..~:~c~f~~?~<:.~f~:~:::P~<.:<::~:,~x:~'. ~~ ~-~~.~a~:~>~~.~:~.~-:... ~::~.....<.e~ ...... :~-~...,~:,~:.~.:~. ~ ~.,~".:....:::'::: · ........ .: .: ........... . .... :'.:.': ':~:" .:,':-.'...'. :.'' .'.:.'.,.' .~: ::.::..:'~.:<:.:<...:...< .'<~.. ~.:..~;~).:~..:.:~-:.:.~,,' ......... <..< ......... >...~.~ .... ~:~ ..... ~::~ ~ , .~ . .~.::::::~::: ,~a.~,~...,.:~..m>, . : .........: ......... :.>.-..'.:.:.::...a.:.:<:.:.:.:.:.~:.:....:..:.:.:.:.::.....:::.:.:.: .......... : .......... : ........'. · '; .: .......... : ::-'.': "::: '.:-~ '.'. :' .::: '. :' :. '.:.. '.'..:'.: .h~:..::~::~:~:~.~k.~::~:~.:~:~::.;~)~::.~:~.::~:~:~:~:~:::~:?:.:::::~ :.::~:~ ::~::::::~:.: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '.. ~: ::. : ::: .:::.::.....:',:.: : :.:':. ::: ': ....... : · '.: ~ ~ :~': :7:m~ ,~,. ,,, .__.~ ........ ' : "~::':?':?':':':::'."%:: ::':': '"::' ."? ' ". ?'.'":"::" :':::::': .... "-"~:":';?~::':: '::'~:~::" ..~:~?~:::..~~..~:::~:~.~::~:~:::;:~~~:::~:..:~:~:~:~:~?:~%::.::~:~.?.~:?:.::?::~..`...:.:: ================================================================================ ' :":":": : ::' .' ' · 0 0 © KUPARUK ALASKA i!! ,~i~i~ ................................ T ~'~'"~' i: ii~'~ ~ i ~ ................. AOE' 3 OCTOBER '3~ 1983 dOB NUMBER AK-BO-~O104 KELLY BUSHING ELEV. = 109.00 FT. ~ ',:::::~:::~:~k:::~x~8:~ ~. ~.~ .~.. ~ :.::: :':t'.:::~::',:',.~::',~',~, m:~.,', ,'.. ...... p:..:f::::~f.z:f:3:~ ,~Jz~:~r.~"4:.::'~:~:~ :',,,':...-'.,'.,,i,',: ,~f.::~:5:~:~.:~:W:~x:::m .m::~ .% ~. '.::~c~ ~:',~...:,~j::.,::r.::::.. 4::,:..:~.' ......... · ...... :.~,:.:,.~..:,:~:',::, ,,:' ~:., ': ,. ','. ~ "~ .','..',.' ..... ',,',,' ...... ".":,' ........... '-,'..~., .' ..... . ' ' :':w: ",~:~ ....... '...~.*.~ ....... ~ ,:,.,.,,:,: ~::x:,~ :.,~,: ................ , ............... ? .. :~.~ :,.,~ .~., :~ ........................ :,~.:,:,:.:~+:x',',::,.,':,~..,: . , ...: · ..,. : . , MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST SECT ION · .: : ,,~ :~... . . : ~!!.' , ::::::..~::::::~:::.. :: ::: ::: :~::::: :;:. .:: : : !:~:::::..:: . :.:::::::.' .: :::..::.~::: : . ...::;::..... : : :: . .. ..: *,, : :: · . : { .: 6 I% ':"::":~i~i: ~~:!i'~'i!:!:~':~i~:.i.:'::~:~ ~4,.:4~,,': ~:~;~?.~i:.~ii~i:~!:i~i:,~i~ii~i~i~i~ii~ .a6:~, I 6300 4704. O0 45~5. O0 41 39 N 39.19 W 1. ~9 2989. O1 N 2~0.39 W o765.5~ ~ 6400 4777.74 4~68.74 43 18 N 38.39 H 1.74 3041.64 N 2~2.70 W 3833.0~, :..~ ::~:~::~:.::..: :: . ~.:~:::.::. .::..~::... ~..~:~ ......... ~ ....~::::.~:~ ~,~.. ~. ...... ~. ~ ~ .......... ~ .......... ~ ~;~,"" ~..~ ~... . ,::::: .::::::~]~+, ,.,, : ..:::.::::::::':::~::::::~::..::.. :::~::::...:::',:::~.:,;:...,,:,. ~. :4: ....,.:,,,:::::::: :,:: :: :::::::.x::.': .:':': :,, ,:', .., ,:, ,.:: ,.... ::. ,.: ;., 6~00 5121,3~ 5012.39 47 58 N 37,19 H 0.44 332~.53 N 2553,72 W 41~5. 7000 5188.45 507~.45 47 48 N 37.30 W 0.19 3388.59 N 2598.63 W 4270.18 Ii 7600 5562.64 5453.64 55 2! N 36.19~W 1.03. 3762.12 N 28e0.~3 w 4738.39 :... .:, ............. ' ' .....:?.... ..... ..... ..... ®. ........ :.:" :.:: ~ 81 O0 5862.61 5753.61 50 44 N 34.89 W 1 · 03 4086.34 N 3114. ~0 W 5138.12 .~ 8200 5926.39 5817. 39 50 0 N 35.10 H O. 76 4149. 43 N 3159.07 W 5215.08 '_ ....................... =~.- ',= ................. ,~-, ~.~ ~.~:i:=:~..;=.~. ~ ~'~..~ ~ ~...:.,~ ~ ~.":.:~.,-:='-~.~'.:~z' ~ :' ....... ' ..... ,'~'.~.-~.~:~' ~:~'~ ~.~:`~.~b~.:~:~::~.~.~.~:i~:.~`~.::~:~:::::~ · ~': ' ~ ' .' .::: '~ '" .............. ~.:~':.":'.'":"~::~i~:~:~""'.. ......... ::~'~'"":~'"~'::~:~¥'~ '.."~:~7~.: '"'"::~:~: "'::::~ ..... ~:~:.:"'~::"-~::' ~. .~ ~::~' ~~::~" :..~ ~ ' c~:: ~:~:~ ~:~. '~::-:~::: ~:~:~ ..... .~:' ::~':.~':- :::;'. ~.~~ ~ ::': :.' '.. · '. · ' .~' ~.' .' .:.:'.::'.": :' '~:" ?:::::.: ~:'~:~:::~:~::~:.?:::'. ~i~.:?:":: · ~ :~::~:z.~::::~::~:~:~:~:~:~:`~:.~`~:~t~.~....:~:.~c~:::~:~.~.~:.:~.~:~.::::~:`~:~::~~~~~:~:~:~'.R~:~:~:~:~:~:::~:::~::~:~:::~:~:~:~:~:~:::~:~'-:~'-~'~:::~::~ ............... '.~:'~ ...................... 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O0 O, 22 S ??.i!':.,::':: ¢:!i~;~'" '"'" .......... !.:'ii:?.'":::~:":?' :'? ....... :':'"':' .: ~ .... : i':i ' !ii 98.3 .JOB NUMBER aK-BO-~0%04 KELLY BUSH%NO ELE~. = ~09.00 FT. ] 810 809, O0 700 · O0 i 912 909 · O0 800. O0 ......... ~ .................. . . ........ ~::~ ..:.:.~.-~ ................ . ........ ~.'.~ ............................... ~,~ ...... , .~..~: :.::~:::..'-..~:.::- :::..::. ~:~ :'M:::~.:~.~:~P:~. ;~:. ;' -~,:[:~ :~::~. ::~:~:8~:~::~::~ : ::::.' :::::~ ..~ 20.00 N 18,37 W 1,57 1.04 34.65 N 31.95 [4 3.56 1.99 ~1, ~"~ &.l. ~ d d 1,1_ - I ~--a .... ~ A.'~ ..... , . ~ , 1453 1409 · O0 1300. O0 184.41 N 165 · :58 W 1570 1509. O0 1400 · O0 230.96 N 204 · 27 W ·: ;" : :. ' : ::.: :::" ·., :: .... :::::~&"..';~.:::.. . w...::S, ,S< ,' ": .::- ' w::. ':::~:~$:~:::.~:>a'~: ~:~' ,~~:~. :::~.:.~":: .... ~. :~.:: :,:,.... ::~ .. ,: ~ ~ ~ ~ ..... .:.:~?~,:::~'~0~*,~*~<~,~..~:::~.~600:~:00.:~:~~ ..... ~" .-% :*%:~,~:*~ ..... :"."::: :~<~ :'~'.~.,~::~*~**~ .... ':: ~:' .: ::~. ~ 949 ,:' "':: :?': ~0~':::', ~.~:.:~<~:'x:.:.. ~.~x~:~>~:~;{~`~8.:.~.x~?:~;<~;~x~;~:~~x~xi~::~::~::~;~i~;~::~:t~ .x..,:..::...~..:.., · · .. .,. .:,.::x.: :~:.:...: :::t .: .:,:,~:~:x.~:~::::.~::.::..:.:~.:.~:.,:.:x.>.:::,~::.:: ..>:`.xx::`::::.S.:`::~.:.;.:.::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: I 44.53 14,04 61.43 16.90 © 0 KUPARUK ALASKA OCTOBER ': ":'"" ': ' ': "': ' ': ': ' : ' ""~ :<":.'," :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .':,:: :~::, ' ,'! ! ~iii:!:i !::ii~i!!~'i~i .. ", :::::::::::::::::::::::: .:: , ",:.: :' x,. '::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::~::::~':' .'~ '::::" h' ::: ::: ................. ,x ..................... ~ .................. ....................... TRUE SUB-SEA · i!: ~ ' ,' ~ii..!~!..~!~....i..:i,,~:.:::!~. :.~x~.i~!::!:....:i~ ~.i::...r.: i~.~:~i~..~ i:..: ..~.... :i!..:::: ~..'..~:i'.'..!i! ~i~l! !~: ,ii~ii! ~:. :~:~ .;. ~ . .::: , ~ '. :! :~: 1983 JOB NUMBER AK-BO-30104 KELLY BUSHINO ELEV. = 109.00 FT. TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ~ 20:P4 ' ~:~ ':' 1 ~0~0'0'~:~:i~i '~:?~':]~' O0~'~~ a ........ ' i~ii .. i!i~ ~ ?"~?~~' I~:~. ~"'" ~: ?" ~. ~: ¥". "*~i."~. *'": i'x' ~ ia~ ~ ~ ~ ~ ~ ~?~*.~':~ ~a: ?~:~" ~ :~'.~.'<~ ~?. :,~= ~a~::<'.~ .... 4 co ooo. co N . W oo oo 800:o4 N ::::::::::::::::::::::::: ~ . :',:..., ,.. ..' : ':::: ".' :::::::::::::::::::::::: ....... ::::::>' .'" ':'::::::::~::b~<~b%~:~':A.' 'x' ',~:. :::~::.:' ',. ,'.::.::::',. '.:::~: .~" :'"'"'"' :'V:." '"'"'.~':~ ,::~:::~:'"'":' ':~' :::::~:" ":' :::::::::::::::::::::::::::::::::::::::::::::::::: ":" "::.'::: ::"~:::::::::::::::::::::::::::::::::::::::::::::::::: :::.:.,':::,.:: :,, .,~ :..:.::,:..::,..:', . ,.'<,: .-.:,.~::.x~....:: .... ~ ::,':::': .":'~'~'~,;':':'~'~'"~:" <':'. .... :" .... ¥:':~.:': ...... ."~ ....:":' " :~.. ':'::':.. .'~ ~$'~ ' "'": ::: : : ~ ::: :': ~ :~: ' . ': :' :s :: :: .:x: ::': ::': ::::::::.::::. ' ,::' :, ':.::.' :.':. ::,:.,. :.,' ...................... ~, ~ ............ ~ ............. , ........ ~ ..: ................... ~ ........ ~ ~ ........................ ~ ...........~ ......~ ...... ~:.....~..~.~ ....................... ~ ....... ....................... .............. ~.~..~ ........ ....... ~ ,.~ ................... ~,~,.. ~,:~ .......... ,..,..~.-,.,..8~ "~,'~'8'"'~ ......... ~ '~8~~::~::~: :~ ~ ~'""'~: ~:~:~ :~ :S~:~ j~ ~'.~ ~ ~ ~:[~:~' ~ :: ~':'.' '5:::: ':" :':.:": :::'~:,:':' :~ ::~ ?::::~:::~:: ~:::. ::::::::::::::::::::::::: k.~'~'~:~:. :::..::~:~:~:~:~:~ ~:~:~:~:~:~.K:h. ::::::::::' F: "::::::::::::::::::::: :.:' :~:~, ~:.':~:~:i:~:~:~:)~:~:~:~:~:~::M:~:~ :~'~:, ,:~:...::L ..:~:::./~:::~::::~:~... <:~:::~:~:~. ::::::::::::::::::::::::::::::::::::::::::::::: .,::k,':E:,..'~:.~ .~:~:~-.:::'..~:~::~:L. ,:::::~:::~M:~:~:~:~8"P~.~:~ ~::~:::~:~:..::::...,::, .:~: .,:~::::' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ========================= ::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::: ::::. :.: :.: ::::::..' :. ::'. ' .,':: ': ,: ::,.:.: :., :.:: :: ', , ':: :.: ...'..' ::,',. :, : '~:':':':':': ::': :':': :'-':~'~ :'":': :':" ':':: ~ ~ ~ ~ ':: :i:i:, :::: ::...:xd::::::~ ~...:~ ~,::i:i:i'~ '~:%:::::::::::::::::::::::::::: ~ ~'::~:':':'m~.~:: :,:::::::'::::::~::::::_ :::.~:::..':~ ~::.s ~:::~ ~ ~:::.::: ::::::::::::::::::::::::::::::::::::::::::::::::: =======================:::::::::::::::::::::::::::::::::::::::::::: ~: ~:::~:~:::::: ::::::::::::::::::::::::::::::> x::::.::::::::::::::::::::::::::::::::::::::::::.:~:::~.::::~[<::~::::::::::::::::::::::: 340~1 2709. O0 2600. O0 1345, 21 N 1014.56 W 700.18 61 . 84 3568 2809.00 27~0.00 1450, 61 N ! 0~0.68 W 759.81 59.68 I a a ~ ~ " .... ' x ', "< ...... < ......... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ?'' 4348 3309. O0 3200. O0 1~39.81 N 1422, 22 W 1039.17 53.53 44~ 340~. 00 3300. oo 2027.73 N 14~3.61 W 10~0.25 51 . 08 . ............... ~ ~ ......... ~ ........... ~ -. ~.. ~.:.:..: <~.:::::.:: ....:, ~ ,.. : ..:.: .:::f::::::.-~.~'~. ~:.?,~:~2::::~':~:~:~x~ ~:....~.~...f<o...<~.-....,~.,~.,~+~...,>..:~...~,~g~T ~'~,~R~ ~<::::::::~':.:::~'"'~ .:~:-~ ~,~< ,:: :.~:,~ :.~x::~:::::~:.:::::::, .~:~::~, ~.: .~.,,:.~..:~::~:.:::.~:.~:.. ,,:.~ .'<~.:.:.:.: -: :,:.' :.: :.:-~:~.::~:::.~:::~ ,:;:.: :...:¥::'::'"':..~,":::.: :,:.:..~.::'~ .>~:' :~"'?':~,~,.~,~.>: :,:~, ~. .~<i~u~ ...~ ,~<:~::~.~.~.:~.:~,x,~,:~,~.~...~ ~. ~3~ '~:~ ~.:.:..'~ ~ ~ ~ ~:~:~::~:~:~:: ~.:.~:~:~:~:~:~:~:~K~: ~:~:~:~:::~:~:~::: ~::~:~¥~:~¥~:~:~:S~:::~:~:k~:~:::,~:::~:~:~:~.,. ~ ..... ,, ................................. ~ :~?: ~:~ ::~ ~: ::'~::~ ~ :, :: ~::?~::~ ~ ~:: ~?:~::?:~:?:~ ~?::~: ~ ~: :~ ~¥~:> :~.~:~'~'?: :.':::::?~:~:' '::'~:~ ~'~::: ::::: ::::::::::: :::::: :,: ~' :~'" :~::::.¥: ::':>~.~ ¥'~:~: :~. :':""5 :::::::~:~:.:~::::%..~..:.::::<:~:.::.:..:~:~'~:~ ::~.~: ~:::.::.:.t?:~:.~:~*~:~~~`~?~¥~:~:~~::::::~:.::~:.::::`~::~:.::~::::~:::.:~:.~:~?~~~.~:~:e:~:::::::~..~:.::::::~::~:~:~ ~::~:~:::~::~: ~' :~::~:~'::~'~':~:::~?~?~?:~?:i~::~::?:'~::::~::~::?::~??:~:,::''~:?:?:::<~:' ? ::¥':~:. ~''~' ':::::~.S..~. :'~.~ .... : :: ~:.::.~:~..A:~ ============================================================================= :~::~.~'.'.'.::x:~., <,'+.~:. ::::::::::::::::::::::::::::::::: "::~':~A~ . 0 0 KUPARUK I.-UI'IFU I M I ,~ UI~I LIM I ~.. OCTOBER 3, 1983 JOB NUMBER AK-BO-30104 ALASKA ~ KELLY BUSHING ELEV. = 109.00 FT. ,::. ::;: :~: .~:, ,;.:: :;: :::,..., .:::: :.. ,: ~x.;::.,:~ :::;::::: :::::~:: ~j: :::::::::::::::::::::::::::::::::::::::::: :;:~::: ,::::,::.:.::~:: :u ~ :::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:~:~:~::::~:~<:::~:~:::::::~:::~:~::::~:~:~::~:::::~:~:~::::::::::::::`:::::`:~:~:~:~:~:~:::~:~:::~:~:~:~:c~::~:~:~:~:~:~:~:~:~:~:~:~:~:~>:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~::~:~t~:~:~:~::~:~:`:~:~:~:~:~:`:~:~:~:~:~:~:~`~:~:~:~:~:~:~:~::~:~:~:~:~:~:~:~:~:~:~:~:~::~:~:~:~:~:~:~:~:~:~:~:~:~`~:~:~::~:~:~:~:~`~:~:~`~`~:~::~`~:~`~`~.~``~:~`~`~`~:~``~`~`~`~`~`~`~`~`~```~`~`~ . '~ ...... '" ' '"~""'" '" ' '" i ' T~UE SLID-SE~ TOTAL ME~S~ V~TZC:~L V~T ZC:~L ~OT~NeUL~ OO0~ZN~T~s M~-TV~ V~T ¢.:.m, :. :' ',::.:, ' x.. :,: ::: ,,:::.:.,,;:::.::,:,.:.:::.:,::,,:,'c.:,,.:,:., :~:~::~:~:~:~;~:~:~:~:~:~::~:~:~:~:~:.:~:~:::~:~::~:~:~:::~:~`~::~:::~:~:~:::~:~:~:~:~:~:::~::~: :~:`:.`~:~::~::~:~:~.~:~:~:~::~;~:~:~:~;:~:~:~:~:`:~:~:~.~:~:~:~:~`~ ::::::::::::::::::::::::::::::::::::::::::::::::: :;.:::::::::(::~:::: ::, ::::::.:,::: :::: ::~:: :::~ : ::::.::: ::: :::,: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::: . :. , ,: ,, . :;P,':::d,,;:;:'", ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::: ,':~:'%:::':'::: :,'::::,':',':::: ' '::'. ', : ,, . ~ ;.,' ' · ",;~::;,:.,,' '.',::',:'.;;::;;::t':;;::::::: .... ',.,,', '~,,,:~,,: ,,: ......... P..c.~...~.~.,.,;..:. ??,'"., ",:,, :.:,:.,"i,- ~,,~, ~.~ ~....::..~.....=:~ ~,,~.i, ~ ~i ............................ :.:,: ~ ~ .~ ~. :,:,:,. ~ ~i ................................................. ~ ~ ~ ~.:,:.:,:.:~ ~ ,~::, ~ 5:369 4009. O0 3900. O0 2~ 13.74 'N 1894.59 W 1360.51 40.4~ 5507 4109. O0 4000. O0 2S86.39 N 1 ~. 75 W 1398.41 37.90 ' ..:. ...x(,.:x.:., :~: ' 6174 4609.00 4500 O0 2925.27 N 2238 41 N 1565.33 31 92 , 6306 470~. O0 4~00. O0 2~2.45 N 2~3.20 ~ 1~7.~9 32.3~ , 7180 ~309.00 5200.00 3495.67 N 2680.80 W 1871 . 98 50.38 . . '2.:k.i:::. :..i ~.k. ~.: . ~ ~' ..2:1_ :~,.. :.~::.~:~:~:~.;~i~`~:~:~{`~:~}k~};~:~}~};~:~:~N~:~;~;~:~{.~:~ ~:::`:~L~:::~'~:~:~.~;~L~:~;~i:.~:~:~:~:~::.:?~.;~e.~:~: 2::~;:c::~s~:5:::~:~::n~. ::~::~:!~:: ~i~:.:::~!~ :::::::::::::::::::::::::::::::::::::::::::::::: ~:::~i::%;:. :::::::::::::::::::::::::: iii :{ ~i :/:};;,,}}ii',~ ~ ~':;;: ~ ~:~::~}}?,ii{}}'~':li~}!~:i}}~i!!!}{}}~}~}i!!~ii~:ii}ii~}i?::,:,i?~?} ?,'~!ii!}?:!}}i}}i':i!! !i!!iii!iiii}{ } !ii~iiii!i!!i! iiiil}i!¢i!ili l',i!}! }i}! ?,}i;}i!ili}ii}i ii iii{ ;i~:i!?:i!i!i!}i?.!i:i;}!i;}[i;;?!!iil;iiii!!i}i!',i;~.~;}ii{!ii?:!}? ?,ii '?:??,i}l}i;i ~:!i; ':{':i; i}i}?:~}!}![~?:~}!}ii}}}}?~i~i~i}i~i.:i~iiii}~}i¢i}~i}iiii~¢!~}i~i~:?~!?/:i?'}}!::~:~Ei~:~? iO.' ..E:?:i}!S'~~?,}:~!':}[:/'O~BER '::::: 2 ~ :"::. ;: ! ~e3: ::':: ,::/~;> :;::, KUP~RU~: OCTOBER 3, 1983 dOB NUHBER ~K-BO-~O104 ALASKA KELLY BUSHING ELEV. = 109.00 FT. :::::::::::::::::::::::::::: ':::;, .:.: .~: :;;,::.', ;:x;;;,;'.:;::::::~:~;~:::~::~:::~;::;;;~:'.~:::~;~',;;:,.~ ,L::;"::;.;;:::,'.;:;::,;::: ~::~:~;:;..~;~:~:..u::~..~;:~:~..~:~1:~u~:;~:`~:~ .,:, :': ;;;;::'.::;:,: : ~ ::,; :; : ;;;.:; ;,,< .';: >::~ ~ : ~ , , .:.:; ~ :.~,~ ~ :;,. , :;::..:,:: :: . ; , ~ ~ . TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD :.:"v :; , " "': .' : ::':;; ::':~:':':F?!, !~!:~`~:!~:`:;:~!~:``~!;;:~!~!;!~;~;!~`~!~E~:~;];~;!?~`..!~:!:~;.;!:!::;;E:~E:i~? ;!;::?::!':::";i: ;'.:,:< 8172 5909. O0 5800. O0 4132, 47 N 3147.1 ~ W , 2263. ~4 8326 bO0~. O0 5~00. O0 4228.11 N 3214.37 W 2317.7~ ............... /t?::?,~;~;~:~:;::~::~ :~:~':::',::: ti: :' ..... ============================= ................ ' :"':":::' ............... THE C:ALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN VERTICAL ~. 32 . ~ : ;;:~ ~.~ ~.~:.. ,--..~ ~ ..... ~. · <..~<;~.,...~. ;~:~:;;:.~,: .:~: ..,?.... . ~'.. © , 0 - ~?~ :~.:~ :'~:"'..~i::'~.:':~:: .~ .::~~V:..:.~...~.~' ..~. ~V~...~:~~?.~: ~:?~.~.~:¥.~.'.:~:::,~d~:~:'c::"::':~?.' '.~:~,~?'~.~:~.: ':'~':':':::'~:~'~ '.::~:'.~.~'.~:~:~: ..:..'.:'"~. :'?. ~ ~ 0 KUPARUK OCTOBER 3, 1983 dOB NUMBER AK-BO-30104 ALASKA ~x KELLY BUSHING ELEV. = 109.00 FT. I'RUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES ~ ::~.. ~ ' ' "" ~"?.::'.::'~' '"" ' ' '': '-- . "' ':: .:':' .? ?.:j;~?.].~ ~:~":~;:.~?.~,? ;': ': ::~ ': : :' ..~:'~] ~j~ ~:' ?:'.::'' '...:?..j :;:: :.. : ~.t:.':~j. ::::: :::] ~. j;j:.~: h~:~J:J]L .:;? ::. ........... :..::.;:::::':.??~:;:.?;~::?:'L'?::' :;.'.? ::]~t ~:' .'.~ ':~':;'. ~.. ':;~ ' .: { 8418 6070.07 5961.07 4283.59 N 3253.25 W TOP LOWER SAND { 8575 & 179.01 &070.01 437&. 4& N 3317. ~7 W BASE LOWER SAND · .': '' :' ,.' ,': .......... '... ~,'"'., ". "~' ','~:":.'.'.'" >'.t '. .... '. ·. ,'.. ,'.~,.¥'.'" ",',' ,' ' '..';~:'~T'::' '.. ,' ""' '"".': :,:'. ~,,,.~ .'.' ',,: ..... ' ~..,., ,,x,.,:,. ,:.. ,.~+~:.,:,~.:: ~ .:..:, ::::::::::::::::::::::: m;, ,: ::: -.x;.;.:'.: :,:~,:~,::::,, ;:::,,::: ::~:,~:;:~ ::;::~ ,:.. ', J,. ,:. ,: :,: ' t.:.,, ' . : ::;..,. : : :.. . . , t::..,: .. . ..,. .:.::: :::::::: ::.: , ~.,,~ ,:,,;:... :;::,:.;;;:;.:~;.;::: .. ,:::. . .,.::. , ::.:,.::,:~. ~ . . ;.;, ~ ; :'; :. ~::::,, ~ ~,:,,::u. . , ,,:,:: :::,,,,: ;':~ :~,.; ;,.:.: :: :..t :.~.: ~ ;.: ,,: ,~ :', ~ .' .: :. · :: .: :: · , , .'~:::':~,:.:] v.:.:, ' '.'.: .' ~.'.:L' ' :: :::::.~::: :~::::..'' , "~:. ,', .... :.m:.::.:::"'?;.::::~.::"': "¢" .::'",::,:'~' . ~;, ¥,.: ::::.;;. :.. · .... .~:::: .:;.......:::(,;:... ::::::::::::::::::::::::::::::::: ,. ::.,.:.., ~ .... :... :,, :r'. ,., '.'.::: : : : ,:.::. ~. : : ': .; , '.::.. 8787':. :..::633~.* O~,::~,?:,~,~:~.~i~D~.~:'~::.~?,::.,:~,~:~:~.~:~':~.'~ ~';~N':::~?~: ~i.:::~ H:: ~; ~ ~0~:: DEP~H";'D~:'~ER?~'~ ~'~ ;:~:~':~i ~':.:.~ .:"..' © 0 © DERIVED USING D IL DEPTHS AND SPERRY SUN SURVEY DATA ...... .? ............ ~ ..... ~...~..~. ......... .,,,.~.~ .............. . ........................ .: ........... ..?? ......... ~~ ~ .~ :, :...: . ~ · ~ x .:.. : ~ , ,~:¥:.t¥,~ : ~, ~ ~ , , ~.,. ,~ ~ .... '.,~ ~ ~A: ~ :¥s~" ' . .,,. ';,. , ,.. ,:, ,., ,;. ,;, ,,, ~,,,:::;,:..,.,,,..,:,, ..:?; :.,.:~;:~:,;,:~.;,:+,.;:.,:~;,;,:,x.:::.::¥.x,,.:. :... ,.: ,,.~..,;....:¥~:., :::,x.,.;.¥,;+:..::.¥t:;::;,:.x ,;.~s:~:¥~,;A,..:...x:~ ~:,~:~. ::: :;~:~:.:,:,A A::.x,~:~::::¥:,: ,~,:.',..,'. ,,:..'; ,.., ,, ,:.:.;..,'..'.:,', ~.:, ,,,:.x,x.~?,x,A.:¥:~...A'.~¥:¥~;::.,,:¢ ;,% .;:k<~.-. ';'~"¥A:~A,x~:;:;¥:..~.,::.....A.~;:~.,,'¥:;x~.x ,.S~:;::A.: x A'A:X;:;:.:;:.%:; x,::;:..,,,:;;¥::;¥;:::x.::;x;;A;:.t,:.x¥;:x,:.;:;¥;,;,A.A:p., ..x...:,;* .:,'.h~A ;,,,,.:~.;,',4, .',, x..,, ',~",x ".~ : :: :.'. ,' .x ',. ,,,,', :'... ,:.' :' .,, ', · ] PBTD ~674 . 6250.2~ 614~, Z5 443Lq, 77N o~,5.61W ~ TOTAL DEPTH DRILLER 8787 6332.05 6223.05 4499.02N 3398.30W ,.+ :~:~3A~ ~<~.~ ,.,.,,...,......,.,'.....',..,.., .....,....,,,,.......,,,.....,,,,,,,...,,<,.'...x,t< .~,....,%.,..,. ,,,'.'.....'..,.~......,'.... ',,&.'..>..,'.'.',.....,,....,,.'.'.' ,.,,.,,, .....',', .,,.,, ,,, ",,,.,.,' ', ",' ,' '," '" '.., ,'. ',' ,,,,., ,, ',' :.x.~:.x., ¥:,x. ,:..;.. ,x,;::.'... ,',...F:. ,' ..... ;, .x, .~ <. ,~_~ ~:::..~!~;:~. sjA::¥:;:~:..:~¢~?,: · · ~,. < ,:::A..x.. ~:.,,:..~ . ,,: ,:..... ~,. .,,.~..~, .,~:.x+~.k. ~....... ::,A,.,. x .~:., '..'-~.~,~.'.~ ....... ":',...'.,~.' ......... ;+..><*.:.,',~ .~:¢~¢~.[.-~,~:..', . 4q~,..~...'...' .. ~'~¥A~;~'~"' '""'"', '~':' '/P~'>'~'~' ~ ~' ~ ' ~'<' ':'""'"~'~'+:'+'~'"" i ?.::::==:=??:[='~}55~'::7[::?:;~:==.:~"rT:?C:::=7=~=;:5 i=,52~=*~=:~z:,~:,~=5:,:~}':~5~:=~':~::~[~==~5::[:=~¢~ :~<s~:,=~ .......... ¢ ........... ~*~::=:~'=~**~=~::~*::*~*~=~Y:==~'~:::~*~¢~'~:=~{=:~=~*=~=~¢=:gU=~ .......... ¢==~*==~*=~"==~e~¥~¢2~=~=~*=o ....... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ................... 4 ..................................................................... =m=~ ............... ~ ................................................. ' ............ ' ................. ,,=,:¥ .:,= ?v,:~ .......... ,,%:,, ........ ¥?; ....... ARCO Alaska, Inc. Job No. AK-BO-30104 'Well: ~1 F-ii (SEC 19 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: October 2, 1983 Operator: Samec Scale: 1" = 1000' -40~0.00 TRU~ NOSTH 8787 % -~o~o. oo -~o~o. oo -~obo. oo HORiZONTRL lOOO. O0 000.00 -2000.00 -1000.00 n oo I Surface Location 11 FNL 504 FEL l ooo. oo PFOJECT ! ON ARCO Alaska, Inc. Job No. AK-BO-30104 Well: .~1 F-Il (SEC 19 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: October 2, 1983 Operator: Samec Scale: 1" = 1500' 150_0~00 3000,00 4500.00 8000.00 ~7500.00 ~ 5638.23' @ N 37°3' W ~787 ! ~sbo. oo ~obo. oo ,~soo. oo ~obo. oo VERTICRL PROJECTI6N . ,(~,. (~' Suggested form to be inserted in each "Active" \'lell folder to d1eck for timely canpliance with our regulations. Ætò K~/r'fA& IF-I). Operator, 1 Narœ. and Number. Reports and Materials to be received by: / I-~ 3-!t.3 Date Required Date Received Remarks Canpletion Rep:>rt Yes Well History Yes " . _Samples Mud Log Core Chips Core Description -A. Registered SUrvey Plat Inclination Survey ()/ Directional Survey ~, 0./ Drill Stan Te.st Reports Prcx:1\!ctiðn . Tes t RePJrts Logs Run . , Yes Digitized Data BS # .~ ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 17, 1983 Mr. C. V. Chatterton State of Alask~ Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached are the notices of intention to 1F-11 and 1F-12 in the Kuparuk "C" sand. have not flowed since they were perforated. If you have any questions, please call me at Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) stimulate wells These two wells 263-4527. ARCO Alaskf. Ir~c. is e s~D'.,JdJary ~f A',tanticRJchlield,C:ompa~/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRI'LLING .WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-115 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-20993 OTHER [] 4. Location of Well SURFACE LOCATION' T11N, R10E, 511' FNL, 504' FEL, SEC. 19, UM BOTTOMHOLE LOCATION' T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 109' PAD 80' 12. 778' FNL, 4100' FEL, Sec. 18, 6. Lease Designation and Serial No. ADL 25652, ALK 2578 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1F-11 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (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.) SUBSEQUENT REPORT OF: (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 Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to acidize the "C" sand with a 12% HCL containing MSR-100 (mud and silt remover with iron sequestering agent) using a CTU. The treatment is designed to surge the perforations several times with acid to open as many perforations as possible. All lines and CTU will be pressure tested to 4000 psi. Fluid estimates are: 12% HCL, 150 bbls; nitrogen, 2000 gals.; diesel, 40 bbls. Well 1F-11 has not flowed since it was perforated. A similar acid stimulation on well 1F-10 resulted in a flow rate of approximately 1500 BOPD. Expected start date' 11/23/83 Anchora§o 14. I hereby certif, v that tJ~e foregoing is true and correct to the best of my knowledge. *he space below for Commission use OPERA]' IONS COORD I NATOR Conditions of Approval, if any: Approved by ORIG;I, hqL SIGNED BY I, OHNIE C. Sl~lIli Approved Copy J~efurned, '~'~0 rder of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 8, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1F-11 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report you have any questions, please call me Sincerely, · Gruber Associate Engineer JG' tw GRU5/L33 Enclosure for the subject well. at 263-4944. If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION CC..,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~x 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-115 3. Address 8. APl Number P. O. Box 100360 Anchorage, AK 99510 50- 029-20993 4. Location of Well Surface: 511' FNL, 504' FEL, Sec.19, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB 6. Lease Designation and Serial No. ADL 25652 ALK 2578 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1F-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data N©TICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). RU Dresser - Atlas. Ran GR/CBL/VDL/CCL. Ran Gyro. Set master valve and tubing adapter. Secured well. Accepted rig ~ 1230 hrs, 10/19/83. ND tree. NU BOPE & tstd - ok. Perforated the following intervals w/12 spf: 8284' - 8304' 8264' - 8284' 8244' - 8264' 8230' - 8244' 8210' - 8230' 8200' - 8210' RIH & set FB'I packer ~ 8364'. Ran 3-1/2" completion assy. Ran CCL & temp log; found leak in pkr/expansion joint. Pulled 3-1/2" tubing. Repaired leak. Ran 3-1/2" completion assy w/tail @ 8372', pkr ~ 8089' & SSSV @ 1920'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/diesel. Set pkr. Closed SSSV. Set BPV. Secured well & released rig @ 1200 hfs, 10/26/83. 14. I hereby certj~that the foregoiog is true and correct to the best of my knowledge. //~~.~ Area Drilling Engineer Signed /~j Tide The space f ission use Conditions df ApproCeq, if any: By Order of Approved by COMMISSIONER the Commission Date ..... Form 10403 Rev. 7-1-80 GRU5/SN14 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate .. K1JPA~qJK ENG 1 I",tEERING TRA~4 ! 1TAL TO: - William VanAlen ~: D.W. Bose/Shelby J. k~tthews Transmit ted herewi th are the fo ! ! owincj' PLEASE NOTE: BL -. BLUEL I NE, S - SEP IA, F - F i LM,~PC - OCT '1_ ? ~ :? '--' ~ ~ Alaska Oil & Ga~ C~ic, [;',re]mission Andiorag:~ DATE' ARCO ALASKA,. INK;. ATIlq' SHELBY J..MATRIBN5 - ATO/111 5-B P. O. BOX 100360 At.,E]-DP¢GE, /~(. 99510 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells- 1G-10 1F-10 1G-11 1F-11 1G-12 1F-12 1F-9 1F-13 Thank you. Sincerely, t Drilling Engineer JBK/SHIO' sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany ._ ~ .,'""- STATE Or: ALASKA ALASKA t.,- AND GAS CONSERVATION CC ,vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI · Drilling well [~X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3· Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well 511' FNL, 504' FEL, Sec. 19, TllN, R10E, UN at surface 6. Lease Designation and Serial No. ADL 25652 ALK 2578 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB, Pad 80' 7. Permit No. 83-115 8. APl Number 029-20993 50-- 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1F-11 11. Field and Pool Kuparuk River Field Kuparuk Oil Pool For the Month of. September ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks , Spudded well ~ 1330 hrs, 09/10/83. Drld 12-1/4" hole to 2565'. Ran, cm~d & tstd 9-5/8" csg. Performed top job. Contd drld 8-1/2" hole to 8787' TD. Ran logs. Ran, cmtd & tstd 7" csg. Displ top 110 of fluid out of well. Secured well and released rig ~ 0800 hfs on 09/19/83. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 40#, J-55 HFERW BTC csg w/shoe ~ 2543'. Cmtd w/1100 sx AS 7" 26#, J-55 HFERW BTC csg w/shoe @ 8756'. Cmtd w/755 sx Class "G" Ill, + 250 sx AS I. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL f/8781' to 2539' 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--R~ each ca!e0dar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and G~~ the 15th of the succeeding month, unless otherwise directed. Form 10404 ' v ~1 I I /MI~7 Submit in duplicate 1F-11 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1330 hrs, 09/10/83. Drld 12-1/4" hole to 2565'. Ran 65 jts 9-5/8" 40# J-55 HFERW BTC csg w/shoe @ 2543'. Cmtd 9-5/8" csg w/1100 sx AS III & 250 sx AS I. Bumped plug w/2000 psi - floats held - ok. Performed top job w/110 sx AS I. Instld FMC csg head packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 10.3 ppg EMW - ok. Cont drlg 8-1/2" hole to 8787' TD as of 09/17/83. Ran triple combo logs DIL/SFL/SP/GR/FDC/CNL/Cal f/8781' to 2539'. Circ & cond hole. Ran 210 jts 7" 26# J-55 HFERW BTC csg w/shoe @ 8756'. Cmtd 7" csg w/775 sx class "G". Bumped plug w/3000 psi - floats held ok. ND BOPE. NU tbg spool. Test 7" packoff to 3000 psi - ok. Displ 110' of fluid out of well. NU tree Secured well and released rig @ 0800 on 09/19/83. HILL/DH44 10/17/83 PHASE II - AS .BUILT. WELLS 9 thru 16 18 17 ~20. PHASE I EXISTING WELLS I thru8 NOTE; BASIS OF ELEV. IS TBM PER LHD & ASSOC. I MIDDLE. LOCATED IN PROTRACTED SECTIONS 19 8,20 TOWNSHIP II N., RANGE I0 E., UMIAT MER. '~ NOTE: BASIS OF BEARING IS MONUMENTATION ~-F MIDDLE AND I-F SOUTH $~ET BY LHD end ASSOCIATES DRlt--'.SITE I -F CONDUCTORS AS BUILT LOCATIONS WELL 9 Y = 5~958~895.613 X= 559,491 49? 630' F NL . Lat. 7'0° 17~55.1255'' Long. I49° 40 '48.661" 484' FEL WELL I0 Y = 5, 958, 95~ 679 X '- 539~48Q. 848 570' FNL · WELLll ¥ 5,959,015.762 X= '5~J9, 470.2t4 511 'FNL L~t. 70° 17'55.7070" Long. 14904d 48.96Z" 494' FEL Lat. 70° 17~56u?.8 B 7'' 504' FEL WELL i 2 Y= 5,~5'9,072. 920 X?' ,5~9,459. 577 4,52 FNL i. at. 70~l'~ 56.87tl" Loa g,~ 14=Je 40' 4~9,,.-365" 5i4 -FEL WELLI3 Y=" 5, 959,140,047 X= 559,855.596 387' FNL L~t. ?0°17' 575t20" I.c)r~'. 149°40'~8.650" 139" FE L WELL 14 WELLI5 Y= 5,9~9,081.057 X= §39~844.251 446'FNL - 1~3f.70° 17'56.93t2" Lo n g.,149 o4.0'3a.,,.34e' 129' FEL Y= 5,~59~022. QOQ I.=t .70° X.= 539, 85~.796 L cng. 14~-:'4U' 58.05" 505'FNL 119' FEL WELLI6 Y: ~958,9~2..891 L~t.'/'O° 17' 55.767~ X $3~,B65.4 9Z I-alg. 14e e40'37.74 8~ 564' FNL I Cg'FEL 6 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 · AUG 5, 19'83 18 '19 S. THIS SURVEY llSSOG, ARCO Alaska, inc. Kul~ruk Project North Slope Drilling AS DRILL SITE I-F BUILT CONDUCTOR LOCATIONS date' 8 -- II -8;5 drawn by ' P ~ tIClle: I": {00~ , dwg. no. NSK9.106.5 d4 .......... L_. MORANDUM State of Alaska ALAS¥~A OIL A}-~D GAS CONSERVATION COMMISSION TO: I~ C. ~.~'~tterton DATE: FILE NO: C~ssioner TELEPHONE NO: Septem~ber 15, 1983 108A:C3 FROM: Harold R. Hawkins ~_.~;{~,/ SUBJECT: -Petroleum Witness BOPA,' Test ARCO, ~upar uk Well I.~o. 1F-11 Sec. 19, Tll}4,R1GL,U~J, Permit [~o. 83-115. ~/onday_, septem.ber_!2, 1983= I left Drill Site 4, subject of another report to ARCO's Kuparuk, Well [,1o. IF-Il to witness a BOPE test. There was one failure. The up~er pipe rams failed and were changed out and tested to 5,000 psig. I filled out an A.O.G.C.C. report which is attached. In' summ~ry, I witnessed the BOPE test on ARCO's ~,uparuk, Well No. 1F-11. b~en the tests were completed, they were satisfatory. Attachment 02-001A(Rev. 10/79) ... 1~ 1,' ('~~! . . c, 9'-)Ä-Ýl ;t(f 1.0 ;1 Á ;j 5 frí9- ) K./ 11UPAIfIJ/1 UPIT +-.r"" /1 ¡}l //)/ jOEù ?ÆlTlrE~ 0/( ól( 01( 0% ()/~ 45: / -~'é ..- Iff Y Clf(~ /f.iI. f/ð(j D ;:::r¡ If/( J. / E' .II ()!fJ Y' 3 ~//ç ~5'"'-Y3 ßð/J þ£¿J.J44,f/ 3/ô¿; J?"oõ j( ~rõjÅçtJ!J~çdß ~j(7d ð/l 01} 33- 5ð ClI'\ <71\ /õ'óó 3 Ó¿;fð Yðð CJ Y~1ðO ,.J t)' 06 --) ,.~)ððð ?tJðO ~ :l lð'~ 3¿)oc> 30òo 7cJdô ~ ./oó¡j JððO ó¡fJE ðþt;!: d/( cJþþ dlr /ð 4f.JV 3 ,-----. TJlE- oP?£Aj7/~.E- Ij/tHf FA/£'£/J Apó jA/¿,C~.c=- JrE¡?/'¡jE:Eþ Â/VD T£5TE,tJ ¡Tõ J~¿}ð /Y5/~ T~.sT5 ;V¿:;:¡f~c 5A7'/5F/lf.~7ð/f/ ?e-4~/ ARCO Alaska, Inc~''~ Post Office ,.,~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 22, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1F-11 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on October 13, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Si ncerely, JBK/GRU4L26-sm Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '~'"' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CUMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-115 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21093 OTHER []X 4. Location of Well Surface: 511' FNL, 504' FEL, Sec. 19, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB I 6. Lease Designation and Serial No. ADL 25652 ALK 2578 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1F-11 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) (Submit in Duplicate) Perforate [~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 Abandonmentsee20 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. Selected intervals will be perforated within the ~uparuk formation and reported on subsequent reports~ 4) The well will be completed with 3-1/2", 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. Thel subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: October 13, 1983 14. hereby cer~i~ that the foregoing is true and correct to the best of my knowledge. Signed Title The space ¢--*~o/is~ usr Conditio~ of Approve, if any: ApprOved Copy Returned ~¥ [~i~[~ ~ ~]~'j~j By Order of Approved by COMMISSIONER the Commission Form 10~,03 Rev. 7-1-80 GRU4/SN13 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate August 18, 1983 Mr. Jeffrey B. KeWin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Kuparuk River Unit IF-Ii ARCO Alaska, Inc. Permit No. 83-115 Sur. Loc. 511'~L, 504'FEL, Sec. 19, TllN, R10E, U[~. Btmhole Loc. 778'FNL, 4100'FEL, Sec. 18, TllN, RIOE, Dear ~4r. Kewin: EnclOsed is 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 tm~formation shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~ny rivers in Alaska and their drainage systems have been 'classified as important for the spawning or migration of anadromo~s fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, A!amka Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, chapter 3, Article 7 and the regulations promulgated'thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to comanencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid u~ in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout Mr. Jeffrey B. Kewin Kuparuk River Unit iF-ii -2- August 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. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of susPension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Lonnie C, 'S~th Com~ssioner of Alaska Oil and Gas Conservation Co~ission be: 6:H/A Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Bu._ ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 7, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1F-11 Dear Mr. Chatterton' Enclosed are- ° An application for Permit to Drill Kuparuk 1F-11, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. o A diagram and description of the surface hole diverter system. o Diagrams and description of the BOP equipment. Since we estimate spudding this well on August 20, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, :~~g Engineer JBK/JG' tw GRU3/L64 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA U,L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL J~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface - '"¢j/ ' ' ~-~/~ ,. 511' FNL, 504' FEL, Sec. 19, TllN, RIOE, UM (~,; ~'0 '~'~ At top of proposed producing interval q: ".~?:,~ 1320' FNL, 3706' FEL, Sec. 18, T11N, R10E, UN .¢,. .-'o ,~. , :-.-J. '"'E,'.~.~_~ At total depth '~:, (.. , 778' FNL, 4100' FEL, Sec. 18, TllN, RIOE, UM 5. Elevation i-~ f~et ~ndi~aate KB, DF etc.) I 6. Lease designation and serial no. RKB 109', PAD 80' I ADL 25652 ALK 2578 9. Unit or lease name Kuparuk River Unit 10. Well number 1F-11 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 13. Distance and direction from nearest town 32 mi. NW of Deadhorse miles 16. Proposed depth (MD & TVD) 9344' MD, 659~' TVD 14. Distance to nearest property or lease line 778' FNL ~ Surface feet 17. Number of acres in lease 2560 15. Distance to nearest drilling or completed F-10 well 60' ~ surface feet 18. Approximate spud date 08/20/83 feet 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2429 psig@ RO°F Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 50 Ol(see20AAC25.035 lc) (2) 2766 psig@ 6!59 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole 4" 2" 1/4" Casing Weight Grade 16" 65.5# H-40 9-5/8" 40.0# J-55 HF-ERW 8-1/2" 7" 26# J-55 HF-ERW ARCO Alaska, Inc , prOposes to dri Coupling PEB BTC BTC Length MD TOP TVD 80' 29' I 29' 2505' 29' I 29' I 9316' I 28' I 28' MD BOTTOM TVD 109' 109' 2534'12200' I 9344'16593' I (include stage data) ±200 cf 1200 sx AS III & 250 sx AS I 424 sx Class "G" extended _ ~ I 577 sx Class "G" neat __ 11 a Kuparuk River Field development well to approximately 9~44' MD (6593' 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 9-5/8" 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 is 2429 psi. Pressure calculations are based on latest reservoir pressure. 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 comple- tion of the job, 1F-11 will be 60' away from 1F-10 ~ surface, ~h~ere are no closer wellbores anywhere down- hole. Top of cement for the production string will be placed~~M-~, approx. 500'MD above the West Sak sands, Reserve pit fluids will be disposed of down the 9-5/8"x 7" annulus.~=rl?e 9-5/8" x 7" annulus will be left with a ~hon-freezing fluid during any interruption--in the disposal process. SIGNED ~ ~,/~$~.~' TITLE Area Dri I l lng Engineer D A T E ~//,/~/~.~/,/~'~' The sp ace bel/~-f7 C~m~, i o n--u se / -- CONDITIONS OF APPROVAL Samples required ! Mud log required UYES I ¥ES Permit number Approval date Form 10~01 GRU3/PD43 Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 18, 1983 by order of the Commission Submit in triplicate ARCO Alaska, Inc. ~ ~" Post Office B~,,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 17, 1983 Mike Minder State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1F-11 Permit Application Dear Mi ke: As we discussed yesterday afternoon, if hydrocarbons are detected in the Ugnu Sands, cement will be brought up to 500' above the top of the Ugnu or to the shoe of the 9-5/8" casing (2534' MD). If you have any questions, please call me at 263-4944. Sincerely, '0, Gruber Associate Engineer OG4/L19:sm cc: G, L, Alvord, ATO 1492 Nell File Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany , L Surface Diverter System i. 16" - 2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double studded adapter. ¢. 20" 2000 psi drilling spool w/!O" side outl ets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automat'ically upon closure of annular preventer. 6. · 20" 2000 psi annular'preventer. 7. 20" bell nipple. 2. Maintenance & Operation Upon initial installation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close annular preventer in the event that gas or fluid flow to sur. face 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 11 BLIND RAMS · I0 PIPE ARMS ) ) PIPE7~. , HD 2 CSG HD O IAGRAM 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. 7-1/16" - 3000 psi x 11" - 3000 psi double 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 spool 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 rmms 11. 13-5/8" - 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 WITI.! 1SO0 PSI OOWNSTREAM 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 NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND i200 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- ET). PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHF. JqO. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER ANO._CHOKES ANO BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO o~ANO~ HOLE FOR 10 MINUTES. BLEED TO ZER 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE 7. INCREASE PRESSURE TO _~P~t2 ANO HOLO FOR 10 MINUTES. '8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTEO MANIFOLO VALVES, IF -ANY, WITM 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI ANO HOLO FOR MINUTES BLEEO 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 ANO 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. 15. 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. ANNULAR PREVENTER 9 BLIND RAMS 8 PIPE RAMS 7 PIPE ARMS CSG HD _ . D[AGRAM fl 13-5/8" 5000 PSI RSRRA BOP STACK 1o 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 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8' - 5000 psi blind rams -9. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK ANO FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2, ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI OOWNSTREAM 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. RECORO ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 4S SECONOS CLOSING TIME ANO 1200 PSI REMAINING PRESSURE, 10. 11o 12. 13-5/8# BOP STACK TEST 13. 14. 15. 16. 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. Zo ,CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- El). PREOETERMINE DEPTH THAT TEST PLUG WILL SEAT AND'SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAO. 3. CLOSE ANNULAR PREVENTER AND CHOKES ANO BYPASS VALVES ON MANIFOLO. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. ~ $. INCREASE PRESSURE TO ANO HOLE FOR I0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO .O~IDANO HOLO FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAJq OF VALVE AND ZERO PSI OOWNSTRF. JLM. BLEEO SYSTEM TO ZERO PSI. OPEN TOP SET OF PIPE RAMS ANO CLOSE, BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 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. OPEN BLIND RNLS AND RECOVER TEST PLUG, MAKE SURE KRNIFOLD 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 ANO SENO TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE OAILY. CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ITEM APPROVE DATE (1) Fee (2 thru 8) 1, 2. 3. 4. 5. 6. 7. 8. (3) Admin ~C' ~-~-~,~ 9. ~(9'-thru '11) 10. 11. ( 4 ) . C a s g ~~,~/z (12 thru ~0)'x (5) BOPE ~.-~.~/~, ?~/~O~ / 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Is the permit fee attached .......................................... ~ Is well to be located in a defined pool ............................. ~ Is well located proper distance from property line .................. ~f Is well located proper distance from other wells .................... .7~ __ Is sufficient undedicated acreage available in this pool ............ /~ Is well to be deviated and is well bore plat included ............... ./~ Is operator the only affected party ....................... , ......... ~ Can permit be approved before ten-day wai't .......................... 5~( Does operator have a bond in force ................................ ,. Is a conservation order needed ...................................... Is administrative approval needed · ee,eeeeeeeeeeeeeeeeeeeeeeeee,eeeeee Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ................. ,... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... REMARKS Is a diverter system required ....................................... z~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~z Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. ~z A ? / , ~ ~ o ~-~o Geology: WVA %~ JAL Engine er~ing: LCS~ BEW ~ MT~~ rev: 12/O6/82 INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. , ' LIS TAPE VERIFICATIObl LISTING LVP 010,H02 VERIFICATIOi~ LISTING PAGE ** RTEL HEADER ** SERVICE ~AME :EDIT DATE ORIGIN : REEL NAM~ :135870NT CONTINUATION # :0! PRE%IIOUS REEL : CO~ENTS :LIBRARY TAPE ** TAPE HEADER ** SERVICE NAME :EDIT DATE :8]/10/10 ORIGIN :0000 TAPE NAME :8566 CONTINUATION PREVIOUS TAPE : COMMENTS :[,IBRARY TAPE ********** EOF ********** ** FILE HEADER ** FILE NAME ~EDIT ,OOl SERVICE NAME VERS~O~ # DATE : MAXIMUM LENGTH : 10~4 FILE TYPE PREVIOUS FILE ** INFORMATION RECORDS ** MNE~ CONTENTS CN : ARCO ALASKA FN : KUPARUK RANG~ ~0~ SECT: 19 COUN: N, SLOPE STAT: CTRY~ USA ** COMMEWTS ** UNIT TYPE CATE SIZE CODE 000 000 0t6 065 000 000 005 065 000 000 008 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 004 065 LVP 010.H02 VERIFICATION LISTING PAGE 2 ************************************************************************************ , SCHLUMBERGER * , ALASKA COMPUTING C~NTER * ************************************************************************************ COMPANY = ATLANTIC RICHFIELD COmPaNY WELL · 1F-il FIELD = ~UPARUK COUNTY = NORTN sLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC{ 68566 ~UN #1. DATE L~GG~D~ 17-SEP-~3 LDP: ~GH C~SlNG TYPE FLUID DENSITY VISCOSITY FLUID LOSS = 9 625" ~ 2539' - BIT SIZE = 8.5" = X~ POLYMER = 10.1 LB/G RM m 37.0 S RMF = 9.0 ~MC = 6,~ C~ R~ AT BHT 3,650 ~ 66.0 DF 4.410 9 66.0 D~ 2.640 ~ 66'0 DF 1.752 9 145.0 DF ~ATRIX SANDSTOr{E LVP 010,H02 VERIFICATION LISTING PAGE 3 ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE 4 8 4 9 4 0 1 MNEM SERVICE SERVICE [INIT APl I~ ORDER # DEPT FT 0 0 SFLU DIL OH~M 7 0 IbM DIL OHMS 7 0 ILD DIL OH~ 7 SP DIL wV 7 GR DIL GAPI 7 31 NPHI FDN PU 42 68 DRHO FDN G/C3 42 44 RHOB F[)~~ G/C3 42 35 MCN[, FDM CPS 42 ~4 FCNL FDN CPS 42 34 CALI FDN IN a2 28 NRAT FDN 42 4~ RNRA FDN 42 0 GR FDN ~API 4~ 31. REPR CODE ENTRY 66 1 7~ 60 65 ,lin 66 0 ~P! APl APl FILE SIZE PROCESS SAMPLE REPR bOG TYPE C£,~S$ MOD NO. LEVEL CODE 0 0 0 4 0 1. 6~ 0 0 0 4 0 1 6g 0 0 0 4 0 1 68 46 0 0 4 0 1 68 0 0 0 4 0 1 68 ~2 0 0 4 0 1 6~ 2 0 0 4 0 1 6~ 0 0 0 4 0 ! 68 ! 0 0 4 0 1 68 92 0 0 4 0 1 6B 93 0 0 4 0 1 68 3 0 0 4 0 1 68 0 0 4 0 1 68 0 0 4 0 I 68 32 0 0 4 0 I 68 DEPT 8721 5000 8FI, U SP 0!8540 GR ~HOB -~8736 0000 NCNb NR~T ] 6855 ~NRA DEPT 8700 0000 SFLU SP -~,0156 GR RHO8 -18736,O000 NCNb N~AT 3.6855 RNRA DEPT 8600 0000 SFLU SP -19,0935 ~R RHOB 2.4336 ~CNb NRaT 3,8145 ~NRA 2 0273 '77i5625 't342 0000 FCNL 3,7559 '77.5625 N~HI '13,4~,0000 FCNL 3,7559 115i3750 NPHI 207~ 0000 FCNL 3,9844 G~ 2,0137 "357, CALI -77,5625 2,28~623 ILD 46,82 DRHO -357,2500 CALl -77,56~5 2,5215 ILD 48,4375 DRHO 520,5000 CALI 115,3750 2 673~1 '1886~i0000 5000 2,2070 -18864,0000 ~,4922 ,4277 ,0317 968'7 LVP OlO,H02 VEP.IFICATION LISTING PAGE DEPT RHOB DEPT SP RHOB DEPT NRAT DEPT SP RHOB NRRT DEPT SP NRAT DEPT RHOB ~HOB DEP'T RHOB NRAT DEPT SP ~HOB NRAT I oooo 37 0000 GR 2 3320 NCNb ~. 7715 RNR~X 8400 0000 SFI,LI -24:9844 nR 2.3984 NCNL 3,1445 RNRA 8300 0000 SFI, U -39.0935 GR 2,4121 NCNb 2,6348 RNDA 8~00,0000 SFI. IJ 41,1875 GR 2.6211 NCNb 3,1309 RNRA 8100 0000 SF{.U -24:5938 GR 2,2500 NCNL 4,1016 RNRA 8000 0000 SFI, U ,9062 GR 2,3047 NCNb 3.7969 ~NDA 7900 0000 SFLU -43!3125 GR ~ 34]~ NCNb 3 5273 RNRA 7800 2 3 0000 SFLU 8437 GR 4004 NCNb fl22~ RNRA 7700 0000 SFbU . -37,0000 GR 2,9891 NCN5 4.0547 RN~A DEPT 7600, OOO S~LJ SP -3], 875 GR RHOB 2,37~9 NCNb NRAT 3,8555 RNRA DEPT SP RHOB NRAT 7500.0000 SFI.~U -41,2187 GR 2,41~0 'NCNb ~.1426 RNRA 16,2813 IbM 80,8750 NPHI 272~,0000 FCNL 9,7559 GR 3.8730 Ib~ 90.3125 NPHI 2376,0000 FCNI, 3,0840 GR R 7422 IbM 63,8750 NPH! 3114,0000 FCNb 2,6621 UR 4 0000 Ib~ 109' 3164,4375 NPHI 3,0000 FCNL ,3613 ~ 4,6172 IbM 252,1250 NPHI !840,0000 FCNL 4,2187 GR ~ 7500 1~6,8750 NPHI 1855,0000 FCNI,, 4.0000 GR 3 2754 IbM 17R,~500 NPHI 2028,0000 FCNL 3.4043 GR ~3713750 NPH! 2016 0000 FCNL 4 0313 G~ 39375 IbM 226i3750 NPHI 1857 0000 FCNb 4,55~6 GR 3,91.60 IL~i 124,3125 NPHI 1934,O000 FCNL 3.8359 GR 6 3750 105'2500 NPHI 2486,0000 FCNL 3.1855 G~ 13,6953 29,9316 989.5000 80,8750 4.1797 34.5215 770 0000 90~3125 7.8164 28,1738 1169.0000 63.8750 6,5391 34.6680 941 0000 109:4375 3,9395 52.~461 435,7500 ~52,1250 2 6523 46i3379 463 7500 !26,8750 3.1387 41..7~80 595 50O0 178:2500 7266 47~3633 500.0000 237.3750 3 5039 50:~7~9 407 , 500 ~26,3750 ,2793 4 .6074 504,0000 124,3195 4.9180 :33,2031 780,0000 105.2500 I LD DRHO CALl ILD DRHO CALl ILD DRHO CALI DRHO CAt, I DRHO CALl ILD DRHO CALI ILD DRHO CALl IbD DRHO CALl DRHO CRLI ILD DRHO CALl DRHO CALI 15,8984 0,0278 8,9219 4,0898 0,0205 10,2422 7,4961 0,0308 8,7t09 4,5703 ,.0,0044 9,9609 3,5195 0,0151 9,8906 2,6484 0,0400 10.1953 3 0859 10. O, 66 9,8047 3 4063 0i0474 10 265~ 3,0410 0,0181 10.0469 5,1758 0,8151 11. 078 LVP OlO,H02 VERIFICATION LISTING PaGE 5 DEPT 7400.0000 SFLU SP -35.4063 GR RNOB 2.3828 NCNt. NRAT 3.~637 ~NRA DEPT 7~00.0000 SFLU SP 24.5469 GR RHOB 2.3340 NCNb NRAT 3.7188 RNRA DEPT 7200 0000 SFLU . SP '38,5625 ~R RHOB 2,3809 NCNb NR~T 3.537i RNRA D£PT 7100 0000 SFLI! SP -43:4375 GR RHOB ~.4063 NCNb NRAT 3,5352 RNRA DEPT 7000.0000 SFLU SD -36.7813 GR RHOB 2,3848 NCNb NRAT 3,6934 RNRA DEPT 6900, 0000 $FLU SP -30i5625 GR RHOR ~ 1133 NCNL NgAT 3 330~ R!qRA DEPT 6800 0000 SFLU SP. -24:5781 ~R RHOB 2 3984 'NCNb DEPT 6700 ~000 SFLU $P -30:..219~ GR ~H00 2,3730 NCNL NR~T 3.5078 RNRA DEPT 6600,0000 SFLU SP. -28,8750 GR RHOB 2,3887 NCNL NRAT 3"0039 RNRA DEDT 6500.0000 SD, -3~,n313 GR RHOR .,.38~8 NCNL NRAT 3.3184 RNRA 156, 25~4 130. 2076. 3, 4, 2122, 3, 3 137, 2160, 3, 3 1.59! 2378 4. 4 172, 2024, 3. 3, X9 3, 93 2622 2768 3 DEPT 6400,0000 SFLU 3, SP. '37,1250 ~R 151. RHOB 2.3086 NCNb 2~18. 4580 3750 0000 1348 9727 1250 0000 7637 1133 0000 0000 6934 0o00 2500 0o00 9687 9805 7500 0000 0234 5195 5000 0000 1660 3828 7500 0000 5000 5273 3750 0000 5410 .~152 250 o000 0723 2695 8750 0000 8223 1406 8750 0000 NPHI FCN[. NPH! FCNL GR IbM NPHI FCNL GR NPHI FCNL NPHi FCNL GR IbM NPHI FCNL GR NPHI FCNL NPHI FCNL ~R NPH ! GR NPHI FCNL NPHI FCNL 1 5605 38:8672 824,0000 156,3750 3,0410 46,3867 551.5000 130,1250 3,7402 41,6504 574.5000 145.0000 3.0410 40.4297 544,0000 137.2500 .0918 4 ,1895 590,5000 159,7500 1,6279 39,1.113 876,0000 1.43,5000 ,5684 4 .6270 5~.,0000 1. .7500 3,0527 4~,4297 56 ,0000 210,3750 ,0137 3 ,4707 851,0000 9_,1250 2,5469 38,3301 724,0000 94.8750 3 0195 41:2109 632,0000 DRH0 CALl ILD DRHO CALI DRHO CALI· XLD DRHO CALl I bD DRHO CALl DRHO CALI ILD DRHO C.~L I IbD DRHO CALI ! bD DRHO CALl DRHO CAI, I IhD DRHO CALI 1 8,7500 3,1484 0,1431 9,1875 3,744! 0,1123 10.1797 3.1016 0,1279 11,6484 3,033i 0,057 10,3906 i 5459 -0!0059 9 3906 2,5039 0,0215 9,7813 2.9629 0,~356 I0, 56'3 3,~094 O, 425 9,6875 2,6152 0,0112 9,7813 3,0488 '0,.0063 10,3750 LVP 010.H02 VERIFICATION LISTING PAGE 6 NR~T 0EPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT RHOB NRAT DEPT SP RHOB NRAT DEPT R~OB N~AT O~T NRAT DEPT RHOB NRAT DEPT RMOB NRAT OEPT RHOB NRAT DEPT 3.5273 6~00.0000 SFI,Ii 36.6563 2.]203 NCNb 3,6172 6200 0000 8FLU , -32,~125 2,3145 NCNL 3,~910 ~NRA 6100,0000 -33.656] UR 2,]652 NCNb ].1348 ~NRA 6000 0000 8FLU -43:4063 2,3398 NCNL 3.3105 5900 0000 SFI. IJ -40:531] GR 2,3164 NCNb 3,5254 5~00'.0000 36.~75 4746 RNRA 5~00,0000 SFLU 34,6875 2.3379 3,2520 5600,00'00 SFLU -36,7188 GR 89! NCNb ]: 707 5500 0000 ,3750 GR ~930 NCNb 2'5801 RNRA 5~00,0000 2520 NCNb :5469 RNRA o.oooo 6,8~37 3,3496 gR 2 ]125 I[,M ~01,81~5 NPHI 2392,0000 3.7422 2.5117 2408,0000 FC~L 3.1934 GR 3.3262 IbM 86,1250 2606,0000 FCNL 3,4434 24941 106,3125 NPHI 2442,0000 FC~L 3,3301 GR 2,4434 102,3125 2376.0000 FCNL ],4395 GR 23281 71i0000 2514 0000 FCNL 3 5234 2 3652 ,3750 NPHI 2492,0000 FCNL 3,4199 2,4434 96,~000 NPMI 2218,0000 FCNL 3,4238 GR 2 48~4 '92:~875 NPHI 243~.0000 FC~L 8 ,,0625 NPHI 246~,00.00 FCNL .,4883 ~0~, 5 NPH! {51,8750 2.6]87 43.8477 639.0000 101,8125 2,5938 38,1348 754,0000 111,3125 2,9844 35,1562 756.5000 86,1250 2,6055 38.0859 733.0000 106,3125 2,5918 41,9434 690,5000 102,3125 2 7 :oooo 2,6172 36.6699 728,5000 9].3750 2 7480 40.:6250 647,5000 96,5000 2,6309 42,5781 684,5000 9~.1875 . 9766 4 ,8945 707,5000 89,062,5 3,2734 40,6250 CALI ILD DRHO CALI XLD DR~O CALX DRHO CALl DRHO CALX II.,D DRHO CALl XbD DRHO CALI ILD DRHO CALl DRMO CALI DRHO CA[,I ILD DRHO 2.7617 0.0142 9,6875 2 6270 0:0044 9,5703 3,0449 0,0381 9,6953 2 9~8359 2,6348 0,0225 9,8594 2,6719 0,0498 9,8437 26992 0:0234 10,1016 2,~555 O, 15! 10.0625 2,!1090 3,050B 1 , 84 3,404'3 0,0259 LVP 010,M02 VERIFICATION LISTING PAGE RHOB 2 ?656 NCNL NRAT 3:464B RNRA DEPT 5200.0000 SFLU SP -4].4375 CR RHOB 2.2305 MCNL NRAT ].1973 RNRA DEP? 5100,0000 SFt,U SP. -33,9062 GR RHOB 2,785~ NCNL N~T 3,6543 RN~A D£PT 5000,0000 SFLU SP -37,5625 ~R RHOF 2,2969 NCNL NR~T 3.5098 RN~A DEPT 4900 0000 SFLU SP -38:3750 GR RHOB 2.2617 NCNL NRAT ~,6B16 RNRA DEPT 4800 0000 SFLU SP -37!4063 GR RHOB 2 2871 NCNb NR~T 3,~586 RNRA D.EPT 4700.0000 SFLU SP '40,3125 GR RHOB ~.,2266 NCNL NRAT 3,66~1 RNRA , DEPT 4100.0000 SFLU SP 36,9062 ~R RHOB 2,~98~ NCNL NRAT 3,~813 RNRA DEPT 4~00 0000 S~I,U SP '-34:8,4~7 ~R ~HOB 2,.2168 NCNb NRAT 3,6250 RN~A DEPT 4~001,0000 SFLU ~HO~ . 2,2246 NCNb DEPT 4300.0000 SFLU SP -39.1250 GR ' RHOB , 2,4824 NCNb MR,AT 3,6270 DNRA 2322.0000 FCNL 3,7913 5 6055 ~2~0000 NPHI 2210,0000 FCNI., 3,089B GR 3.1133 ILM 90.81~5 NPHI 2072,0000 FCNL 3,6270 GR 2,9453 113.7500 2068.0000 FCML 3,4023 ~R 2 7129 IbM 105.8125 NPH! 2088,0000 2,0625 GR 3,4531 96,8750 NPHI 2140,0000 FCNL 3,5918 3,4941 IbM 88,3750 NPHi 2~S6,0000 FCNL 3,64B4 GR 3,0215 IbM 9~.12~0 NPMI 1968.0000 FCNL ~.2949 4.2266 91,5000 21,54,0000 FCNL 3.7227 GR 3' 68 IbM 93:,~6 500 NPHI . 1oooo 7246 GR 5.0820 IbM 70.0000 2074.0000 FCNL 3.6699 9,5156 IbM 614,0000 101,3125 4.8359 35.2051 715.0000 82,0000 3,3359 42,2363 571,0000 90,8125 3,1055 39,4531 607.5000 113,7500 2,7070 25,6348 1012,0000 105,8125 3,73~3 40.5762 595,5000 96.8750 3.7598 42 3340 59920000 9~,3750 3,4258 35,7422 597.0000 91'1250 4,5156 41,6504 57~,5000 91,5000 54 1855 ~9,5000 93,7500 6'203! 40,9668 565,0000 70,0000 11,5859 CALl DRHO C~L,! DRHO CALI DRHO CALI DRHO CAbI DRHO CA£.I IbD. DRHO CAlX DRHO c,~I IbD DR~O CASI IbD DRHO C~LI IhD DRHO CALl TLD 10,0078 4,8477 0,0190 10.4297 3,5586 0.0220 12,3516 3,3730 0.0610 12,7344 2,8555 0,0190 12,7031 0347 12,1484 4,8859 O, 498 1~,4063 11,8672 4,9883 0,0225 12,4219 4,0508 0,0098 12,7188 6,9531 ~0,0 1.2,4922 LYP 010.H02 VERIFICATION LISTING PAGE SP -64.9750 GR RHOB 2.3262 NCN5 NOAT 3.6016 RNRA DEPT 4100 0000 SFI. U SP -68~3125 GR RHOB 2.~656 NCNL NRAT 3,4063 RNPA DEPT 4000 0000 SFLU SP -51'9687 GR RHOB 2:3691 NCNL NRAT 3,39~6 ~N~A OEPT 3900.0000 SFLU SP -6~.0000 GR ~OB .)008 NCNb NRAT 3.4902 RNRA DEPT 3800.0000 SFI. U S~ -6~,3125 GR RHOB 2539 NCNL N~AT . 3:4785 RNRA DEPT 3700 0000 SFI, IJ 8P '72,0625 GR RHOB 2.2500 NCNL ~RAT 3.1934 ~NRA DEPT 3600.0000 SFI.U SP -71.3125 GR RHOB 2.21~9 NCNL NRAT 3.46~9 ~NRA DEPT 3500,0000 SFLU ~P. -66,7500 GR RHOB 2.~285 NCNL NRAT 3.9355 ~NRA DEPT 3400 0000 SFLU SP. -83,5000 ~R RHOB 2,0918 NCNL NRAT 3,5938 RNRA DEPT 3300.0000 SFLU SP -64.7500 GR RHOB ~.~148 NCNL MRAT 3.5605 R~RA OEPT 3200.0000 SFI,,U SP -80.0625 gR R~OB 2,13~8 NCNL NRAT 3.6172 RNRA 66 2414 g 72 2166 6 7~ 2054 .6250 .0000 .8281 96R7 .5625 ,0000 ,4043 ,7109 .5625 ,0000 ,1348 , 22023 8 52' 4616, 3, 8 62, 2200, 3. 9 1925, 1.4, 249], 240 , 3. 14 2620, 7969 6250 0000 5547 6250 9375 0000 4668 1406 9375 0000 3711 25 0000 4531 4219 5625 0000 8828 1797 125 000 754 6563 3125 0000 6836 5000 5000 0000 7109 NPHI FCNL NPHI FCNL NPHI FCNL NPHI FCNL IbM NPHI PCNL GR IbM NPHI FCNL NPHI FCNL GR NPH! FCNL NPHI FC~L IbM NPHI FCNL NP~! FCNI, ~R 41.6016 630.5000 66.6250 2.4922 .8.1836 636.0000 72,5625 6,7344 36,7676 655,0000 78,5625 8,6875 38,9160 635.0000 88.6250 9.1562 38.2813 635.0000 75.9375 10,7031 35,4492 1369,0000 52,9375 8.1016 39,0137 637.0000 62.8125 12.2422 47.2168 495,7500 83.5625 13.O313 41,4551 661,5000 68.3125 ~ 3125 40:3320 652.0000 71.3125 8 706,0000 43,5000 DRHO CALI ILD DRHO CALl DRHO C~LI II,,D CALI ILD DRHO CAI, I ILD DRHO CALl IbD DRHO CALI ILD DRHO CAbI IbD DRHO CALI DRHO CALI ILD DRHO CA[,I 0.0269 11.6328 13.7422 0 0190 11:sooo 7,3203 0,0552 13,9297 9 8281 0~020o 13.1406 9,8437 0,0298 14,0078 9,4219 0, 75 o: l 11,8 59 13 3906 0i0605 12 5078 13.1016 ~0,0029 1,6953 9,0703 0,0073 12.8203 1~,~00]1 , 044 11.5703 LYP OlO,H02 VERIFICATION LISTING PAGE 9 , OEPT 3~00 0000 SFI..U SP -72:8750 GR RHOB 2.t445 NCNL NRAT 3,7441 RNRA 11,7031 IbM 66,3125 NPHI 2250,0000 FCNL 3,8164 GR DEPT 3000 0000 SFLU ,5000 GR RHOB 2,0879 NCNL NRAT 3,4199 RNRR 16,5156 42,4063 NPMI 2436 0000 FCN[, ]:5508 DEPT 2900 0000 SFLU SP -7~:1875 G~ RHOB 2,~60~ ~CNL NRAT 3,5262 RN~A 10,2344 ILM 68,0000 NPMI 2!08,0000 FCNL ~,6660 GR DEPT 28.,00,~000 SD 67:0375 RHOB 2 801 .qCNL NRAT 3,9590 4:7227 Ib~ 6 9375 NPHI . 41:oooo re.r, .,. 1133 ~R O~PT 2700,O000 SFLU 8P -70,~000 GR RHOB ~, 980 NCNL NRAT 4,0977 RNRA 11 2031 ILM 50.1250 NPHI 2174.0000 FCNL ~.5430 GR OEPT 2600,0000 SFLU 8P. -78.31'25 ~R RHO8 2. 091.8 ~CNL NRAT 3~ 7012 Rr~RA 12.7266 IL~ 46.9062 NPHI 251~.0000 FCNL 3.6445 GR DEPT 2..5~0.0000 SFLU 8P 3.]750 C,,R ~HOB 2,3672 NCNL NRAT 3,5645 RNRA 8,5313 IbM 31.3281 NPHI 2364,0000 FC L 3,5176 ~R 8,~406 IbM 32, 750 NPH! 175~.oooo rC~b ,7305 ~R ** FILE TRAIt, ER ** FILE NA~E :EDIT .001 SERVICE NAME : DATE : ~AXINi.IM LENGTH : 1024 rILE TYPR : NEXT FIL~ NAME : ********** EOF 11 43 589 66 17 36 686 42 11 44 575 68 q 46 569 64 12 49 478 50 12 42 689 46 2000 ~3 672 31 2000 46 469 32 .7578 ,7988 ,5000 ,3125 ,7500 ,7676 ,0000 ,406] ,7344 ,6777 ,0000 ,0000 .6328 ,3867 0000 '9375 · .4297 .3652 .2500 .1250 ..]422 340 O000 29062 0000 i9453 0000 .328! o000 ,4355 ,0000 ,3750 ILO DRHO CALI ILD DRHO CALl ILO DRHO CALI !bD DRHO CALI DRHO CALI ILD DRHO CALI ILD DRHO C.aLI DRHO CAGI 12 7500 0~0073 12.4688 14,9922 12 8437 0:0068 13.6953 9.3439 ~0.0039 5.132~ 1~.4531 .0117 ~4,1797 13.8984 ~§.2266 .4517 8.9609 13.3906 =0. 4629 8.9375 TAPE TRAILER ** 5VP 01,0,MO~ VERIFICATION LIS~ING PAGE 10 SERVICE NAME :EDIT DATE :81/10/10 ORIGIN :0000 TAPE NAME :~566 CONTINUATION # :01 NEXT T~PF NA~E = COMMENTS :LIBRARY TAPE ** ~MEL TRAILER ** SERVICE NAME :EDIT ORIGIN : ~E~L NAME :135870NT CONTINUATION # :0! 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