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Home My WebLink About180-140 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 12/04/12 Inspector: Jeff Jones Operator: CPAI Well Name: WSW -01 Oper. Rep: M. Walters PTD No.: 180 -140 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: n1878 .bconocophillips.com If Verified, How? ier (specify in commei Onshore / Offshore: Onshore Suspension Date: 10/16/11 Date AOGCC Notified: 12/02/12 Sundry No.: none* Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 100 Photos Taken? Yes IA 175 OA 100 SCANNED APR 1 1 2013 Condition of Wellhead: Location verified by CPAI feature location map. Condition good; valve handle missing on OA. Condition of Surrounding Surface Good; scaffold & barrier in place, cellar full of snow. Location: Follow Up Actions Remove snow from cellar to allow inspection and replace missing valve handle. Needed: * AOGCC determination; changed well status from Observation to Suspended Attachments: photo (1) REVIEWED BY: Insp. Supry ier2-44. it Comm V gp — l ct I\.f1`i left Ab€cc PLB 08/2010 2012- 1204_Suspend_KRU_WSW -01 jj.xlsx . 0 • Suspended Well — KRU WSW -01 (CPAI) PTD 1801400 Photo by AOGCC Inspector J. Jones 12/4/2012 N . ■ , / ( • glir' 1 iii i l 11 .. ow _we- !w 0'"r _. _. --.7. 107 . awl II now OM .- t 1 1 ',... la , . 1 t 1 Mirk up++ i . . . 111) STATE OF ALASKA AL.A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Fbrforations r Perforate r Other pr Suspended Well Rill Tubing Stimulate - Frac Wa iver Inspection Alter Casing r 9 r r r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Development r Exploratory r _ 180 - 140 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service .r — 50 029 - 20537 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025648 WSW - 01 9. Logs (List logs artd submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 3190 feet Plugs (measured) None true vertical 3190 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 2587 true vertical 0 feet (true vertical) 2587 Casing Length Size MD TVD Burst Collapse CONDUCTOR 50 16 82 82 1640 630 SURFACE 2184 10.75 2210 2210 3580 2090 PRODUCTION 2903 7 2927 2927 4980 4330 LINER 398 4.5 3152 3152 5350 4960 Perforation depth: Measured depth: Open hole wire wrapped screen from 2937 RECEIVED True Vertical Depth: Open hole wire wrapped screen from 2937' -3152 DEC 0 6 2012 Tubing (size, grade, MD, and TVD) 3.5, J -55, 2652 MD, 2652 TVD AOGCC Packers & SSSV (type, MD, and TVD) OTIS "RH" PKR @ 2587 MD and 2587 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): MAR 1 1 2013 Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service F7 Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X 'S GSTOR r WINJ r WAG r GINJ r SUSP SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A Contact Martin Walters / MJ Loveland Email n1878 c(Dconocophillips.com Printed Name Martin Walters Title Well Integrity Supervisor Signature tin &— j i( Gi lit Phone: 659 -7043 Date: 12/4/2012 RE DEC 06 1011 '� /'�2 z - 6'It Form 10-404 Revised 10/2012 ( Submit Original Only die - • I V' • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 December 4, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit WSW -01 (PTD 180 -140) Dear Commissioner Seamount: Enclosed please find the initial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well WSW -01 (PTD 180 -140). The followin g documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, Oaft Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk River Unit WSW -01 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 180 -140 API Number: 500292053700 Operator: ConocoPhillips Date Suspended: Pending Surface Location: Section: 321' FNL, 201' FEL, Sec 9 Twsp: T11 N Range: R10E UM Nearest active pad or road: KRU DS1 B Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good. Scaffold and barrier in place Pad or location surface: Snow covered gravel Location cleanup needed: None Pits condition: NA Surrounding area condition: Good Water /fluids on pad: NA. Snow covered Discoloration, Sheens on pad, pits or water: NA Samples taken: None Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Good. No flowline connected. Valve handle missing on OA Cellar description, condition, fluids: Snow filled Rat Hole: NA Wellhouse or protective barriers: Good Well identification sign: Good Tubing Pressure (or casing if no tubing): SITP = 100 psi J Annulus pressures: IA = 175 psi, OA = 100 psi Wellhead Photos taken (# and description): 1 of wellhead Work Required: Remove snow from cellar for inspection. Install valve handle on OA.� O/ C Operator Rep (name and signature): Martin Walters A. //UCC AOGCC Inspector: Jeff Jones Other Observers: NA Inspection Date: 12/4/2012 AOGCC Notice Date: 12/2/2012 Time of arrival: 13:00 Time of Departure: 13:30 Site access method: Highway Vehicle • • ARCO Alaska, Inc.A Kuparuk WSW -01 WSW -01 TUBING API: 500292053700 Well Type: WS PBTD: 3,179 ftKB SSSV Type: Orig Completion: 2/5/81 TD: 3,179 ftKB PROD. CASING Annular Fluid: Last W /O: Max Hole Angle: 0 deg Last Taq: Last Taq Date: Angle A TS: deg (rD. Rev Reason: New Schem Last Update: 3/7/98 Angle (8 TD: deg a 3190 Elevations BHA KOBE Grd 163 ft I Original Rig RKB 1 Casing String - CONDUCTOR Item Btm Jnts Wt Grd Thd 16.000 in CONDUCTOR 82 65.00 H - 40 Casing String - SURFACE Item Btm Jnts Wt Grd Thd 10.750 in SUR. CASING 2,210 45.50 K - 55 TUBING 7: Casing String - PRODUCTION SBR ve Item Btm Jnts Wt Grd Thd 7.000 in PROD. CASING 2,927 26.00 K - 55 Casing String - LINER Item Btm Jnts Wt Grd Thd 4.500 in LINER 2,783 11.60 J -55 PKR 4.500 in BLANK LINER 2,937 11.60 J -55 4.500 in WIRE WRAPPED LINER 3,152 11.60 J -55 OD to 5.15" Casing String - OPEN HOLE (Underreamed to 12 ") Item Btm Jnts Wt Grd Thd 12.000 in OPEN HOLE 3,160 0.00 12.000 in OPEN HOLE 3,179 0.00 Tubing String - TUBING Item Top Len Jnts Wt Grd Thd 3.500 in TUBING 35 2,512 9.20 J -55 BTC 3.500 in TUBING 2,567 85 9.20 J -55 BTC Perforations NIPPLE Interval Zone Status Feet SPF Date Type Comment 0 OPEN HOLE Other (plugs, equip., etc.) - JEWELRY Depth Type Description ID 2,547 BHA KOBE Jet Pump 0.000 2,569 SBR Otis 2.810 2,587 PKR Otis 'RH' 2.970 2,620 NIPPLE Otis 'X' Landing 2.813 2,651 CATCHER SUB Otis 2.992 2,652 REENTRY GUIDE Otis 2.992 CATCHER SUB 3,152 UPPER TATTLETALE 4.500 3,162 LOWER TATTLETALE 4.500 3,179 BULL PLUG 0.000 REENTRY GUIDE General Notes Date Note 2/11/81 Note on Older Schematic: PBR Assembly has pulled apart and there is 14 ft. of Seal Assembly between the Kobe BHA and PBR. LINER BLANK LINER WIRE WRAPPED LINER P 4 1 UPPER TATTLETALE OPEN HOLE 4 LOWER TATTLETALE OPEN HOLE BULL PLUG is S' Keep 5' clearance from all flowlines due to high voltage electrical lines. If you need to get closer, contact R &P: 7948. THIS DRILL SITE IS CONSIDERED TO BE (( AN H AREA ,l / MANIF �� O SKID ;`f; RESERVE PIT i�j� le . 7REC Y r V XFRMR ■ WS12 WS11 WS10 WS9 WS8 WS7 WS6 WS5 WS4 WS3 WS2 WS1 ' ' �> ❑ I O ❑ 0 0 0 0 0 0 0 ❑ ❑I —1 ❑I ;` F21 ;;`�S �CD I- 82'80' — 1 ! -80' 1 531' -59 1- 61'60' + - 160'- 60'- 1- 59'-F— '+,, In PILE co - 28' 26' 18' 16' ONLY 40' 73' 12' ( 17' 31' 1 1 O O 1 13' ;■ r 1- 160' -1- 160' -1- 160' -1- 118' —I - 6 1 131 I I 77' I I I 102' I �I -63' 1 ,4 1 1 UNE i e 9 u10 t11 1. 2 3• A. • As • '� 18 ' •• � I• ••• RI k A 6 _L 1 I I 4 13 14 5 15 • 7 .16 `'! 1 BULK � Q o • CHEM i♦ ., I L— N . L h i. O RESERVE PIT l� I F INE ROAED FEATURE LOCATIO\ LEGEND LEGEND ELECTRICAL CABLES rillr - CLEAN SNOW DUMP AREA, ALL EQUIPMENT. ® RESCUE EQUIPMENT EXISTING PRODUCER III * SCBA LOCATIONS NOTE CA 5.:5,- - ENVIRONMENTAL AREA -NO SNOW DUMPING, Y EXISTING INJECTOR 1 1 I DESIGNATED SAFE AREA (PRIMARY) CONVERTED FROM BLOWER NO SNOW IS TO BE PLACED IN - INE -WATCH CLEARANCE!!, BLOWERS MAY HIT LINES WITH DISCHARGE. 1 2 1 DESIGNATED SAFE AREA (SECONDARY) PRODUCER TO INJECTOR ANY RESERVE PIT OR LINED PIT. W...', - SNOW BLOWING AREA ONLY. N IEL EVACUATION ROUTES DEPENDING ON WIND I ABANDONED CONDUCTOR LOUNSBURY I;•:•:• :• :•3 - NO SNOW DUMPING AREA. r WINDSOCK )isf EXISTING CONDUCTOR & ASSOCIATES, INC. I.....1 BARRICADE/ESCAPE ROUTE F �� FIRE EXTINGUISHER ® PARTIAL TREE SURVEYORS ENGINEERS PLANNERS vta ,a 0 THERMOSIPHON FORM: ASIZEL 7 2/4/10 Add Thermosiphons /Per K100021ACS RDN JFC ConocoPhillips REA :1B MODULE:XXXX UNIT: D1 6 5/6/09 Add Elec Coble Locations /Per K090054ACS AJR MJH Alaska, Inc. APPROVAL: _ DS1B FACILITY i EXPANSION 5 9/13/08 Chonqed Legend & Hatching, Per K080095ACS JFC MRT DATE: RF A TURE LOCATION 4 7/27/03 Add Wells 20, 101, & 102, Per K03106ACS MRT BGM 10/02/96 1 8 11/16/10 Add Thermosiphon 17 /Per K100118ACS JLS MLO I DRAWING NO. PART: REV: 8 _O AP DATE s REVISIONS BY CBK EVER EN '. • • ' ••• !: .., e , •',.,3 li -'. .. „. . , ...,.. N , . ...,.... - °‘''. %k '• ) . )". ' „ - 4. , , '' .. ..,.,..........„...„.„., ...„ . , . t,....„-... . , •,, ', - .... - , .. .,. - t ... , ,14, 11.. ..., 11111 Mk " .- ''''''':- , -,, . . .., , ...... . Ft ..3 -- '''..-7.-- ".. 4 • ■ , , .... , - - -I , . • ■'t - ....:-.-;-471; . li., . - # '''' 7 11111w. , 74 , 70 7 !S vs HEIN:L74-2, 10'..;!: .' 7 ! . , , . ''---. I '''.-•.$:' ' ' ' ii i4iit -- 4. 4 ' ' - - ail") )14,0005).611))*Milla ,_,_ , ,,,,, t ;.;,,ii, ..,,- ,g;;;;Iflelfr .„, , . vit r /ow 0 41111111:11 IIV -a -alikk' . .. .L. • •_!.... , , ..... # .. 1 , r ,.., .... - .t. „ ,...,,.. ,,- , ,..--................_.,...,_.....___ • • Iv ConocoPh l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED' October 26, 2011 NOV 01?; 20/ Commissioner Dan Seamount Alaska U�3 & as Cons. Corr��iSSiOtY t 4'F tv Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 / Anchorage, AK 99501 1 8 0 - I Lto w5 - oI Commissioner Dan Seamount; Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 9/11 and, 9/12, 2011. The corrosion inhibitor /sealant was pumped 10/15, 10/16, 10/17 and, 10/18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, fita/// 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 10/26111 1A,1B,1C,1D, 1E & 1Y PAD Corrosion • Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1A -22 50029221270000 1910030 SF N/A 18" N/A 2.55 10/18/2011 WSW -01 50029205370000 1801400 • 20" N/A 20" N/A 2.5 10/16/2011 WSW -02 50029208120000 1821370 710" N/A 2'10" N/A 6 10/16/2011 WSW -03 50029208170000 1821420 12" 1.00 20" 09/11/2011 4.25 10/16/2011 WSW -07 50029208610000 1821880 SF N/A 19" N/A 1 10/17/2011 1C -170 50029231540000 2030780 19'3" 1.20 10" 09/11/2011 18.74 10/15/2011 1C -174 50029231400000 2030270 7' 1.00 8" 09/11 /2011 14.8 10/15/2011 1C -190 50029231360000 2030030 9'4" 1.50 8" 09/11 /2011 15.2 10/16/2011 1D-08 50029220266000 1770530 5'2" 1.20 6" 5/28/2011 3.8 10/15/2011 1D-12 50029229480000 1990840 18" N/A 18" N/A 3.4 10/15/2011 1D-41 50029232880000 2051880 16" N/A 16" N/A 3.55 10/15/2011 1D-123 50029229140000 1981700 11'5" 2.30 5" 09/12/2011 4.4 _ 10/15/2011 1E-11 50029207870000 1820510 22" N/A 15" N/A 1.2 10/17/2011 1Y -09 50029209350000 1830520 7' 2.00 5" 09/12/2011 1.7 10/18/2011 STATE OF ALASKA ,~. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other X 12. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 321' FNL, 201' FEL, Sec. 9, T11N, R10E, UM At top of productive interval 321' FNL, 201' FEL, Sec. 9, T11N, R10E, UM At effective depth 321' FNL, 201' FEL, Sec. 9, T11N, R10E, UM At total depth 12. Present well condition summary Total Depth: measured true vertical 3832' feet 3465' feet Plugs (measured) $. Datum elevation (DF or KB) 100' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number wSW 1 9. Permit number/approval number 80-140 10. APl number 50-029-205,37 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 3 7 2 8' feet true vertical 3367' feet Junk (measured) Casing Length Size Structural 8 2' 1 6" Conductor 221 1 ' 10 3/4" Surface Intermediate 2 92 7' 7" Production 2 43' 4 1/2" Liner Perforation depth: measured None (open hole gravel pack) true vertical Cemented Measured depth True vertical depth 395 Sx AS II 1 1 7' 1 1 7' 800 SX EXT Fondu & 2 2 4 6' 2 2 4 6' 461 Sx AS II 350 Sx Class G 2962' 2962' Gravel Pack 2937'-31 80' 2937'-31 80' Tubing (size, grade, and measured depth) 3 1/2" J-55 @ 2652' Packers and SSSV (type and measured depth) Otis JRE @ 2587' 13. Stimulation or cement squeeze summary Intervals treated (measured) RECEIVED AUG ! ~chora~ Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -0- Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations -0- (see attached explanation) 16. Status of well classification as: Water Injector__ Oil ~ Gas Suspended Service Water Disoo$~l 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE Kuparuk Water Source Well #1~_~'_~'~ This well is currently an idle water--well. This well has been freeze protected and has been used as a observation well in the Upper Ugnu. ARCO Alaska, Inc Post Office . 100360 AnchOrage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 8/30/85 TRANSi, iITTAL NO: 5305 RETU~4 TO: ARCO ALASKA, INC. KUPARUK OPERA?IONS ENGINEEkING RECOkDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, ~K 9951U TkANSMITTED RECEIPT AND bEWUENCE OF '--~ 2X- 10 ~--PBU ' ""~b~- 1 "ShBhP ---lQ-9--P~U C SAND ~2A-2.~ PBU A SAND tiERL%~ITll ARE THE FOLLO%~ING ITL2vlS. RETUP, N ONE SIGNED COPY OF THIS EVENTS PRESSURE DATA PLEASE ACKNOWLEDGE TRANS~ITTAL . 4/25/85 2/22/85 5/12/85 1/24/85 STRESS FRAC A SAND STI<E~S FKAC a bAND RE PORT RE P O kT REPORT . REPORT J-:"?~- '"~':" · RE PO RT ~2U-10 PRESSURE REPORT "'~2U-1t PRESSURE REPORT "~' 2U- 16'PRESSURE REPORT '" 2U-16 ~BOTTOM-HOLE-SA~PLE '"~2U-16'PBU C SAND ~2U-14' PBU A SAND ~2U-16~PBU A SAND ~2U-14'PBU C SAND ~2W-13 PBU C SAND ~2U-16 PRESSU~ REPORT RECEIPT ACKNO%qLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON ~OBIL* PHILLIPS OIL* NSK CLE~ J. RAThMELL* 12/6/84 12128/84 6/13/~5 6/13/85 6113/85 6/ 7/85 6/~6/85 5/27/85 5/27/85 5/29/85 6/13/85 6/ 6/85 6/30/85 6/16/85 6/17/85 6/17/85 5/29/85 DATE: STATE OF ALASKA* SOt:IO* UNION* K. TULIr~/VAUL~ ARCO Alaska. Inc. is a Subsidiary of AtlanticRichtieldCompany ARCO Alaska, Inc. , ...;.,,cr,~ ?.07 277 5~Z37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 /Transmitted herewith are the following items. and retUrn one 'signed copy of this transmittal. Please acknowledge receipt .PJtU '~VEYS/PRESSURE ANALYSIS /lC-1 /lC,6, /!G-10-' ~ tY-5 ~lY-7 / 5/11..12/84 Torque Turn (PresSure & Temp Surveys) 7/06/84 Camco 7/10.12/84 Camco 5/10/84 Otis 12/17/83 Otis Static 8/04/84 Otis 12/21/83 Camco 12/23/83 Camco 8/11/84 Otis 5/21/84 Camco 5/13,14/84 Torque Turn (Pressure & Temp Surveys) 6/26/84 Cam~o ~ Static ' 6/30/84 Canmo 5/26/83 Camco HP 8/11/84 Camco 6/28/84 Camco 5/18/83 Camco HP d~z/ . ~ /~ ..w~~ 7/07/84 Otis 12/27/83 --' .Otis Static 12/14/83 Otis 12/15/83 Otis 7/03/84 Otis ' :' :" ~"': ' 4/10/84 Cam~o Receipd~ac~nowledged: DISTRIBUTION B. Adams D & M · F.G. Baker Dzilling P. B~ter Geology BPAE Mobil Chevron NSK Operations Date: W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Enion Well Files ' , .. ;.',er,,L .: 77 5£37 Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~B~' 5/28/84 2c-1 11/09/83' " 2C-2 11/09/83 2C-6 11/08/83 2C-7 11/08/83 (2~i 4/18/83 Q2~..~ 4/24/83 ~Or~] 4/22/83 4/30/83 "([2,'~) 4~28~84 4129184 [2V-~ 5/04/84 '"fV'f-5 5/06/84' 2X-5 8/12/84 3C-6 %/19/84 3C-6 5/17/84 .. Otis Lynes - 'Lynes Lynes Lynes Camco Camco Camco Otis Camco Camco Dresser PBU Flow Survey (Gradient). Otis Static Gradient Otis Camco ., DrESser Dresser Mini Drawdown & Buildup Survey /o~t Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Union Well Files KUPARUK ENGINEERING TRANSMITTAL DATE' WELL NAME' TO: .~ FROM: D, Fay....A11 ison zo,s/z7 / Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE,~ PHOTOCOPY REC/~T.ACKNOWLEDGED: DATE' ~/~LEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 KUPARUK E~GINEERING TRA~ISHiTTAL # 2_/~ 7~ .. TO: ~~ FROM: D. Fay Allison DATE' /2- ~ ~' ~-~ WELL 'NAME' see belo~.z Transmitted herewith are the following' PLEASE NOTE' BL- BLUELINE, S- SEPIA, F-FILM, T TAPE,~~- PHOTOCOPY. Well /~-/ Des~ript ion,.. Date Run ?~/~ -? ~ ~/. RECEIPT ACKNOWLEDGED: DATE: '~PLEASE REIURIt RECEIPT TO: ARCO ALASKA, INC. ATTN: D. FAY ALLISON- ATO/1115-B P. O. BOX 100360 - AI-iCHORAGE, AK. 99510 ARCO Alaska, Inc Post Office box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1983 Mr. Lonnie Smith State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Subsequent Reports, Sundry Notices, Your Letter 10-12-83. Dear Mr. Smith: I have researched the wells you asked about and the status is as follows' Well ARCO Date Comments Kuparuk l-B1 1-8-83 A change notice was prepared. Copy dated 1-8-83 is attached. The clean out attempt was never done. Kuparuk 1-H1 4-21-82 This well number was changed to 1H-5. See attached notices for 1-H1 and 1-H5. Kuparuk 1-E28 9-23-82 Subsequent notice was prepared 4-5-83. See attached copy. Kuparuk WSW-1 8-5-82 I am collecting the injection dates and volumes. I will submit the subsequent notice within two weeks. Please call me at 263-4527 if you have Charles K. House Kuparuk Operations Coordinator CKH/kmc any questions. Attachments cc: W.L. Crandall/M.D. Schall R. S. May R. A. Ruedrich A~."c?J%'"'~B e's t ' ............. y .Oi ;',H3nlicRlchti~,IdCornpany OctOber 12, 1983 Mr. Charles House Zuparuk Operations Coordinator ARCO Alaska, Inc. P. O.. Box' 100360 Anchorage, Alaska 99510 Re ~ Subsequent Re~orts, Sundry· ~.otices and Reports on Wells (Form 10-403) Dear ~r. Souse For the following list of "~'otice of Intention Tot" Sundry- ~:;otices and Reports on Wells (form 10-403)'this o£fice does not have on record the "Subsequent Repozt of~" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. Wel 1 ARCO Date Zuparuk I-B1 10-22-$2 ~.i,_e£' DescriDtion o£i- Intention Clean out wellhore with coiled tubing unit. 08-05-~2 Inject water. Kuparuk 1E-28 09-23-82 Change kick-off depth. Fugaruk 1}{-1 04-21-82 · Change surfac~ casing settin~ depth. LC$/EJfl: 1 c ~ 105: D1 KIJPA .qUK FJ'~ I NEERi ~ TRA~$V, 1TTAL #~ D. W. Bose/Shelby J. ~tthews~ DATE: Transmitted herewith are the followin9- PLEASE I~[7I'E: BL- BLUELINE, S - SEPIA, F - PLEASE P,E-RJP~'4 RECE 1 Pr TO: ATfN: SHEIJ3Y J. N~I-I'} !~'¢3 - ATO/1115-B P. O. BOX 100360 AI',CHOP,/tGE, A.K. 99510 KUPAF~ ENS I NEERI NS Will i am'VanAI en D. W. Bose/Shelby. J. lVtatShews Transmitted herewith are the fol owing. ,. PLEASE INGLE. BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, ARQO ALASKA, INC. ATTN: SHELBY J. IVA-FI'HEI~ - ATO/111 5-B P. O. BOX 100360 AN~E, AK. 99510 KU?ARUK ENGINEERING TRANSMITTAL #~ TO- William V'~'n Alert Transmitted herewith are the following. FROM- D. W. Bose/Shelb~v j. Matthews PLEASE NOTE: BL- BL UELINE, S- SEPIA, F_ Fi LM, T - TAPE, PC~OTOCO~ ACKNOWLEDGED: · DATE :A!~k~ Oi! & Gas Cons. Commissiom AF, chs:'zge . . _ A'TTN. SHELBY j. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 995]0 KUPARUK ENGINEERING TRANSMITTAL TO' William Van Allen FROM: DATE' _ ~/-~-~ WELL NAME' Transmitted herewith are the following- D. W. Bose/Shelby J. Matthews · · PLEASE NOTE' BL -BLUELINE, S - SEPIA, F - FILM, T - TAPE, P~PY RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO:' ARCO ALASKA, INC. A~N' SHELBY J. ~HEWS - AFA/311. P 0 BOX 360 Alaska Oil & Gas Cons, Comrnissi6n · · Anchorage ANCHORAGE, AK. 99510 ALASKA OIL STATE OF ALASKA AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via .. /~) L _ is hereby acknowledged: . QUANTITY j l q 7 DESCR I PT ION RECEIVED: DATED: Copy YES sent to sender NO February 4, 1983 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Eox 360 Anchorage, Alaska 99510 Dear Mr, VanDusen: The Alaska Oil an~ Gas Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well is not on file with the Commission. The Oil and Gas Regulations require the operator to file, within 30 days after completion, .suspension, or abandonment of a drilling well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to see if the data has been submitted to the Commission and, if not, that you comply with the regulation with regard 'to the following wells, W. Mikkelsen Unit No. 2 Prudhoe Bay Unit DS 14-9A Kuparuk River Nit WSW- 1 Prudhoe Bay Unit DS 14-gAR Oliktok Point ['lo. 1 West Sak 28242 No. 24 West Sak 25631 No. 23 PBU No. Prudboe Bay St. No. 2 Prudhoe Bay Unit DS 1-22 PBU Ell een No. 1. Thank you for your cooperation in this matter. Yours very truly, Harry W. gugler ~' Commissioner .BY ORDER OF THE COMMISSION be STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PorcUpine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: STATE O'F AL~S,~A r,,~D G~S CDHSERVATt~H CO~]S~J!ON RE: Receipt of the following material ,. which was transmitted via is hereby acknowledged: · QUANT I TY DESCR I PT ION RECEIVED: DATED: Copy sent YES to sender NO ARCO Alaska, Inc. "~~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 6, 1982 C. V. Chatterton State of Alaska Oil and Gas Conversation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Enclosed is Notice of Intent for Kuparuk Well WSW-1 covering water injection. Sincerely ~ E. A. Simonsen slz Enclosure cc: L. K. Blacker AFA-330 w/o attachment L. B. Kelly AST-306 w/attachment L. M. Sellers ANO-332 w/attachment H. C. Vickers, Jr. AFA-326 w/o attachment Well File WSW-1 w/attachment RECEIVED AUG i 2 1982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieidCompany STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION CO ' ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I)(-I OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, ;[nc. 80-140 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 5o- 029-20537 4. Location of Well SL: 321' FSL, 201' FWL, Sec 9, T11N, RIOE, UM BHL: 321' FSL, 201' FWL, Sec 9, T11N, RIOE, UM 9. Unit or Lease Name Kuparuk River Unit 10. Well Number WSW-1 5. Elevation in feet (indicate KB, DF, etc.) |6.Lease Designation and Serial No. Kuparuk River RKB-98' IADL 25648 12. Check APpropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Kuparuk River Field Oil Pool 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 inject water, produced during testing of Water Source Weiis 2 through 12, into Water Source Weii 1. Injection is scheduIed to begin September 1, 1982 and continue through August 1983. This wiii require removai of a standing vaive with a wireiine unit prior to injection. No other changes in the weiibore compietion should be required. All pumping equipment will be pressure tested to beginning injection. 3000 psi prior to ?RS Subsequ~t Work Reported o~ Fma~i No. ~ Dated ~../.._/_. RECEIVED AUG 1 2 1982 Alaska 0il & Gas Cons. Commission Anchorage _ _ 14. I hereb, y certify t~hat the foregoing is true and correct to the best of my knowledge. L ~ ~~ Regional Operations Engineer Signed , _ _ __ Title Date The space ~low for Commission use/ Conditions of Approval, if any: Approved Copy Returned BY lOttll£ I. SBIII Order of Approved by. --- -~ COMMISSION[R the Commission Date __ Form 10-403 Rev. 7-.1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,~!! L STATE OF ALASKA ALASKA AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND R; ORTS ON 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, :[nc. See below 3. Address P.O.]Box 360, Anchoraqe, AK 99510 4 Location of Well See belOw 8. APl Number 50- See below 9. Unit or Lease Name See below 10. Well Number See below '. · · ;,.. 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. _See below I SeC below / 12. Check Appropriate Box -I:o Indicate Nature of Notice, Report, or Ol~l~-~'E)-J~-a--- ~5 .......... NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations o Stim u late [] Abandon [] Stim ula tion Repair Wel [] Change Plans [] Repairs Made -- Pull Tubing [] Other [] Pulling Tubing - (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other X[-'] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent'dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). During August 1981 ARCO Alaska, Inc. performed a water injectivity test in the Kuparuk Sands to gain pertinent reservoir data in preparation for its Increment I Waterflood of the Kuparuk Sands. Injection was successfully achieved in that Upper and Middle Kuparuk Sands in Well lB-2 but not achieved in the Lower Sand in Well lB-1. Reservoir pressure response was monitored in two wells, lA-3 and 1B--5%--.' Water for the test was produced from our water source wel-I--~-6. 1. A brief review of test is attached. Well API Number lB-1 50-029-20465 lB-2 50-029-20531 lB-5 50-029-20237 i 50-029-20615 ~ 5_0_~2902005~3_~ Location Sec.9 TllN R10E Sec.4 TllN R10E Sec.9 TllN R10E Sec.5 TllN R10E Sec.9 TllN R10E Elev. KB-98' KB-98~- KB-89.5' KB-100' KB=98' Unit Name Lease Designation ~ Kuparuk 25648 ADL 25648 Kuparuk 25648 ADL 25648 Kuparuk 25648 ADL 25648 Kuparuk 25647 ADL 25647 Kuparuk 25648 ADL 25648 ~ '----~ '¢ ' '"'~ t~c" · ~lssks 0il & ,~,,G¢'":~ ...-,,~,~orag,-~ Cons._ 14.Iherebycert¢~'~t the~oing t to the best of my knowledge. //" ~..._ Eng inee~,. The sp~_~,ow lot ,~l~lon u~. Condmons of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - At ta~hment Go Sundry Notices and Reports on Wells Kuparuk Water Injectivity Test The Kuparuk Water Injectivity Test began on~August ?, 1981 with injection into the Upper and Middle Sands in Well lB-2 at a constant surface pressure of + 1050 psi. Injection continued until August 24, 1981. A stabilized injection rate during this period of +1050 BWPD was observed. An average BHP of + 3850 psi during this period yielded an injectivity index of + 1.7. Injection profiles run during the test indicated that the majority (70%+) of the water was going into the Middle Sand. After completion of the steady state injection period, injec- tion was stopped for a pressure fall off test. Following this shut in period, a step rate test was run. Results of the step rate test indicated a reservior parting pressure of + 4320 psi. Having successfully demonstrated the injectability of the Upper and Middle Sands in lB-2, attention was turned to the Lower Sand in Well lB-1. On August 27 attempts were begun to estab- lish injection in lB-1. Two attempts to begin injection with surface pressures of up to 2250 psi were unsuccessful. A coiled tubing unit was used to displace wellbore fluids with diesel and again attempt to inject. This too proved unsuccess- ful. The well was flowed to be sure that the perforations were open. No further efforts to inject were made. It is felt that some sort of plugging is preventing injection in the well. The test was concluded on August 30, 1981. During the injectivity test, reservoir pressure response was monitored in. two offset wells, lA-3 and lB-5. A bottom hole pressure increase of + 3.7 psi and + 8.0 psi respectively was measured in the wells. Attached as part of this report are charts and plots of injec- tion parameters, step rate testing, and offset pressure response. HCV 10/26/81 2.3OO- 2OOO- 1500- 50O- · , ; KUPARUK I'.IATER INJECTIVtTY TEST IIIJECTIOI] RAI'E , KUPARUK 1D'2 · I , 4000,- 380O-. 3600- 340O- 3200~ 3000: KUPARUK WATER INJECTIVITY TEST II~JECTIO['~, BHP · I[IJECTIVITY II,IDEX · KUPARUK 1B-2 ' ' t 6 8 ·- .. 10 12' ~6 · ,. _5 18 KUPARUK WATE~ INJECTMTY TEST Step Rate Test INJ PRESS 750 1000 1250 1550 1800 2000 iNj RATE BHP 'TEMP A P II 0 3260 122. 336 3433 117. 173 1.94 692 3797 109. 537 1.29 1266 4068 100. 808 1.57 3060 4344 77. 1084 2.82 4648 4490 70. 1230 3.78 7968 4554~ 64. 1294 6.16 45OO 4250 4O0O ; 3750 KUPARUK WATER INJECTIVITY TEST STEP RATE' TEST,: : ;:~ii KUPARUK 1D-2: ! ii! .- kTJPARUK %~TER INJECTM~f TEST bDnitor Wells Pressure Response DATE KUPARUK lB-5 BHP T~4P 8 6 3261.8 8 7 3262.1 8 8 3261.6 8 9 3262.6 8 10 3263.5 8 11 3263.8 8 12 3264.4 8 13 3264.3 8 14 3265.3 8 15 3265.7 .8 16 3266.4 8 17 3266.9 8 18 3267.4 8 19 3267.9 8 20 3268.4 8 21 3268.6 8 22 3269.3 8 23 3269.8 8 24 3270.0 8 25 3269.9 8 26 3270.2 8 27 3270.3 8 28 3270.2 8 29 3270.2 157.1 157.1 157.2 157.4 157.6 157.6 157.7 157.9 157.9 158.0 158.1 158.2 158.3 158.4 158.5 158.6 158.5 158.6 158.7 158.7 158.7 158.7 158.8 158.8 I<UP~ lA-3 B}LP T~P 3173.4 158.2 3173.4 158.4 3173.4 158.6 3173.6 158.8 3173.8 159.0 3173.9 159.1 3174.0 159.2 3174.2 159.4 3174.4 159.6 3174.6 159.7 3174.9 159.9 3175.1 160.0 3175.3 160.1 3175.5 160.1 3175.7 160.2 3175.9 ~ 160.3 3176.2 160.4 3176.4 160.6 3176.7 160.7 3176.8 160.8 3177.1 161.0 Pressure Response _+ 8.0 PSI Pressure Response + 3.7 PSI ..... 3180.0 _ 3177.5 - 3172.5 3170 '0 - 3270.0 - .~ . .32,67. :,5 - 3265..0 - 3262.5 - 3260.0 ' KUPARUK W~T. ER. INJECTIVITY TEST .._ MOHITOR WELLS PRESSURE RESPONSE 2 4 6 8 10 12 Ir.,'· 16 ._ Kuparuk !A-3 --1 "-t =-=:I .... t 18 20 22 ...... 24 ' . ... . . Kuparuk 1B-5 2 ~ 6 8 In 12 14- 16 !8 20 ,.. ,..,, 24 KUPARUK WAT~R IIqJECTM?f TEST Steady State Injection DATE INJ RATE 8 6 0 3230,9 160,2 8 7 2448 3847,9 76 8 8 2398 3827,3 69 8 9 2273 3817,5 ~69 8 10 1520 3854,2 77 8 11 1254 3861,0 77 8 12 1210 3867,5 77 8 13 1301 3811,4 77 8 14 1297 3855,3 76 8 15. 1018 3850,1 76 8 17 1063 3846,7 77 8 18 1068 3843,7 77 8 19 1112 3848,9 76 8 20 1082 3842.4 76 8 21 975 3844,3 75 8 22 1063 3846,5 77 8 23 1050 3844.8 75 8 24 923 3860,8 78 Ap 617,0 596,4 586,6 623.3 630,1 636,6 580,5 624,4 619,2 615,8 612,8 618,0 611,5 613,4 615,6 613,9 629,9 II 3,97 4,02 3,87 2,44 1,99 1,90 2,24 2,08 1,64 1,73 1,74 1,80 1,77 1,59 1,73 1,71 1,47 Cumulative Steady State Injection = 22 MBW ALASKA ~,.,. AND GAS CONSERVATION C(, '~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DR ILLING WELL [] COMPLETED WELL [] OTHER r-)( 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 50- See below 4. Location of Well 5. Elevation in feet (indicate KB, DF, etc.) See below 6. Lease Designation and Serial No.. , See below See below 9. Unit or Lease Name See bel ow 10. Well Number See bel ow 11. Field and Pool Kuparuk River Field Kuparuk River 0il P0ol 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 r-~ 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). In preparation for its Increment I Waterflood of the Kuparuk Sands, ARCO Alaska, Inc. intends to perform a water injectivity test in two wells in late July and August, 1981. The purpose of the test is to gain pertinent data on the ability of the Upper, Middle, and Lower Kuparuk Sand segments to accept injected waters. In addition, reservoir pressures in offset wells will be monitored to attempt to determine response to the injection. We anticipate a maximum of three weeks of testing, injecting into the B-1 (Lower Kuparuk) and B-2 (Upper & Middle Kuparuk) wells. Continuous monitoring of pressures and periodic production logging will be used to aid in determining injection characteristics. Monitoring of reservoir pressures in three offset wells during the injection, the A-3, B-4, and B-5 will be used in evaluating reservoir response to the injection. Water for the injection testing will be produced from our water source well No. 1. W~.~cted start date is July 27 1981. ~ ~ API NUMBER L(~CAT~ON ELEVATIONS B-1 j~ 50-029-20465 Sec 9 TllN RIOE KB = 98' B-2 ~'/50-029-20531 Sec 4 TllN RIOE KB = 98' Kuparu'k B-4~¢~t. 50-029-20595 Sec 9 TllN RIOE KB = 98' Kuparuk B-5~'%~ 50-029-20237. Sec 9 TllN RIOE KB : 89.5' Kuparuk ~ Not~ssigned Sec 5 TllN RIOE KB= 100' Kuparuk ~ ~ ~ ~ TI~ RIOE. KB =' ' Kuparuk ~~/ ~-~ ~u~u: o~ 9 98 14. I hereb~ certify that the foregoing is true and ~rrect to the best of my knowledge. Signed__ ~~ /' ~].~ Title The spaC~low for Commission use Conditions of Approval, if any: BY [iARRY W. KU(~LER By Order of Approved by COMMISSIONER the Commission UNIT NAME Kuparuk 25648 LEASE DESIGNATION ADL 25648 25648 ADL 25648 25648 ADL 25648 25648 ADL 25648 25647 ADL 25647 25648 ADL 25648' Date g o Z..~-g ! Date O~ILqlNAL $1GltED "' "" "".~¥ W. I(UC-f. ER Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.\.[ Post Office Anchorage. ,-,iaska 995 Telephone 907 277 5637 March 18, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 4-8 DS 14-9A T-3C Confidential ~',~S-1 Dear Sir: Enclosed please find' · The Monthly reports of Drilling and Workover Operations for DS 4-8, T-3C and WS-1. 2. The subsequent Sundry Notice for DS 4-8. 3. The Completion Report for WS-1. 4. The Sundry Notice of Intent for DS 14-9A. Sincerely, p. A. VanDusen District Drilling Engineer PAV/KJG'sp Enclosures WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well . OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~3 Water Source 2. Name of Operator 7. Permit Number Atlantic Richfield Company 80-140 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 50-029-20537 4. Location of well at surface 9. Unit or Lease Name 321'FNL, 201'FEL, Sec 9, T11N, R10E, UM Kuparuk 25648 . At Top Producing Interval 10. Well Number 321'FNL, 201'FEL, Sec 9, TllN, R10E,-UM WS 1 At Total Depth 11. Field and Pool 321'FNL, 201'FEL, Sec 9, TllN, RIOE, UM Prudhoe Bay Field B. Elevation in feet (indicate KB, DF, etc.)'I6' Lease Designati°n and Serial N°' Kuparuk River 0il Field 98' RKB ADL 25648 I , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 1/13/81 2/1/81 2/5/81 ._Z --- feet MSL.I 1 17. Total Depth (M D+TVD) 18.Plug Back Depth (MD+I'VD} 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 3190 MD & TVD 3190 MD & TVD YES~ NO[] --- feetMDI 1900 (APProx) 22. Type Electric or Other Logs Run DIL/SP/GR, FDC/CNL/GR, CBL/VDL/CCL/GR, CAL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED '~ 16" 65# H-40 Surf 82' 24" 395 sx AS .II 10-3/4" 45~5# K-55 surf 2211' 13-3/4" 800 sx Ext Fondu & zl61 sx AS Iii' .7" 26# K-55 surf .2927' 8-3/4" 350 sx~Class G 4½" 11.6# J-55 2937' 3180' 12" Gravel Packed .... 241 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~" 2652' 2587' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ., . DEPTH I'NT~RVAL(MD) AMOUNT& KIND OF MATERIAL USED ' '' ' ~ '"' .... ~: '"' rlr/a · . -' 27. PRODUCTION TEsT Date First Production' I] Method of Operation (Flowing, gas lift, etc.) . Alaska 0]! & Gas Cons. · n/a I I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE sI~E-'/~G~AS-OIL~ RATIO TEST PERIOD I~ / OIL-B'BL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE I~ '. ; · 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Shot 19 sidewall cores f/3190'-2957'. Recovered 18 or 19. (No samples required) Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS ,, ., NAME Include interval tested, pressure data, all fluids recover~l and gravity, . MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ' ,,, n/a n/a · ! 31. LIST OF ATTACHMENTS Dri 11 i n§ Hi story , . 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, 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 tha~'., 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". WATER SOURCE 1 DRILLING HISTORY Spudded well @ 0600 hrs 1/13/81. Drld 13-3/4" hole to 2232'. Ran 53 its 45.5#, K-55 10-3/4" BTC csg w/shoe @ 2211' Cmtd csg w/800 sx 11.7 ppg EXtended Fondu & 250 sx 15.2 ppg AS II cmt~ Cmtd top job w/211 sx AS II cmt. Set 10-3/4" pkoff & tstd to 2000 psi f/15 min - ok. ND diverter & NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt to 2187'. Tstd csg to 1500 psi - ok. Drld cmt, FS & formation to 2242'. Tstd form to 12.5 EMW. Drld 8-3/4" hole to 2851'. R~n~ DI__L.../~.~_,~/'2851..2209'.. Drld 8-3/4" ,-ii'ole to 2950'. Ran 70 jts 7" 26# K-55 BTC cs~ 'w/~hoe @ 2927'. Cmtd csg w/350 sx 15.8 ppg Class G cmt. Set 7" pkoff & tstd to 2000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt to shoe @ 2927'. Tstd csg to 1500 psi - ok. Drld cmt, FS & formation to 3190' Ran DI'~L~/.S~ZG~B~,~.EDC/CNL/.GR, .CBL/VDL/ CCL/GR. Shot sidewall cores f/3190-~'9-5-7~~ Opened hole w/12" hole opener to 3180'. Displaced 10-3/4" x 7" annulus w/9 ppg KCL brine. Ci,rc & cond hole. Spotted 5 sx sand in 6-1/8" hole f/3180-3190'. Ran 4½" screen liner w/pkr & 2-3/8" washpipe. Attempted gravel pack but stuck washpipe in hole. Worked free but damaged pkr in process. POOH. Left 4½" liner & 14 jts 2-3/8" tbg in hole. Removed fish from hole f/2927-3180'. Ran Caliper Log f/2927-3180'. R._e~era,,,nui~4~" liner f/2754-3180' w/2-3/8" washpipe & gravel pack tools. Tstd tbg string- o~1 packed 4½" x 12" annulus to 2857'. Ran CNL Gravel Pack Log f/3179-2700'. ,D, isplaced well w/KCL brine. RIH w/RTTS, open FO & displaced 10-3/4" x 7 annulus w/KCL. Ran Reda pump and 2-7/8" x 3½" tbg w/tail @ 2650' & pkr @ 2464'. Circ warm KCL thru 10-3/4" x 7" annulus. NU test tree. Flow tested well thru separator. Ran HP Press Log. Reda pump qui.t due to circuit overload. Killed well w/8.8 ppg K~C~L~.brine. ND test tree. Pulled 3½" tbg w/Reda pump & pkr assy while filling ann w/8.3 ppg H20. Circ & cond hole. Ran gravel pack log & Gyro. Ar'ctic Packed 10-3/4" x 7" ann w/88 bbls Arctic Pack thru FO & closed FO. Set completion pkr @ 2587'. Ran 3½" tbg w/KOBE pump BHA. ND BOPE. NU tree & tstd to 3000 psi - ok. Tstd tbg to 500 psi - ok. Set & tstd pump. Displaced 3½" x 7" ann'w/diesel. Secured well & released rig @ 0800 hrs 2/5/81. Alaska Oil & G. a~. Cons. Cmnrnission ~nchorage C0::'Pt_ET!O?,I REPORT 'At, CO ALASKA [NC GYROSCOPTC .SURVEY '2AD!US OF' CURVATI,/RE ,ME_THOD OF COMPUTATION CO'4PtJTED FOR SDC BY FI',4 L INDSEY .& ASSOC RECORD OF SURVEY TRUE V, EAS. DRIFT VERTICAL SUB DRIFT D~PTH A. . , ,-,, ~.-~L E DEPTH SEA DIREC O ~4 DEG. TOTAL 22 APR ~1 KUPARUK B-WS-1 KB ELEV 98. FT. JOB NO ~453 COORDINATES ~ DOG LEG C L 0 S U R E S SEVERITY DISTANCE ANGLE DEG/IOOFT D M S SECTI D[STA~C~ 9 1 o 11 12 13 14 15 16 17 18 19 2.'] 21 22 23 24 0 3 0 0.00 -98.00 N O.OOE 100 0 10 09.99 1.99' N83.08E 200 0 5 199.99 101.99 S69.91E 300 0 10 299.99 201.99 S30.91E 400 C 10 3~9.99 301.99 S27~.,91E 500 C) 5 499.99 401.99 S85.91E 600 0 5 599.99 501.99 N56.08E 700 0 5 699.99 601.99 N30.O8E ~00 O 15 799.99 701.99 S39.91E O0 0 15 899.99 801.99 S21.9.~1E O0 0 10 999.99 901.99 S 4.91E O0 0 20 1099.99 1001.99 S17-08W O0 0 20 1199.99 1101-99 S37.08W O0 0 20 1299.99 1201.99 S37.08W O0 0 25 1399.98 1301.98 S36.08W O0 O 30 1499.98 1401.98 S35.08W O0 0 35 1599.98 1501.98 S35.08W O0 C 25 1699.97 1601.97 S36.08W O0 0 20 1799.97 1701.97 S42.08W OO 0 20 1899,97 1801,97 S51.06W OD 0 20 1999.97 1901.97 S28.06W OO 0 25 2099.97 2001.97 S52,06W O0 0 35 2199.96 2101.96 S41.06W O0 1 24 2209.95" 2201.95" S31.06W O0 l. 10 23~9.92 2301.92 S35.06W 0.00 S 0.09 N 0.07 ti 0.06 S 0.31 S 0.42 S 0.39 S 0.28 S 0.26 S 0.63 S 0.99 S 1.42 S 1.93 S 2.40 S 2.92 S 3.57 S 4.35 S 5.06 S 5.56 S 5.96 S 6.41S 6.91 S 7.50 S 8.91S 10,92 S 0.00 W 0,08 E 0,30 E 0,46 E 0,61 E 0,78 E 0.92 E 1.02 E 1.26 E 1,49 E 1.57 E 1.53 E 1.26 E 0.91 E 0,52 E 0.06 E 0.48 W 0.98 W 1.40 W 1.82 W 2,19 w 2,61 W 3.24 W 4.26 W 5.57 w 0,00 S 0 0 0 W O.CO0 0.13 N 41 32 30 E 0,167 0.31 N 76 7 46 E 0,083 0.47 S 82 30 26 E 0.083 0.68 S 62 43 4-2 E 0.009 0.89 S 61 22 26 E 0.083 1.00 S 66 59 52 E 0.054 1.06 S 74 19 28 E 0.037 1.29 S 78 11 0 E 0.167 1.62 S 66 50 52 E 0-078 1.86 S 57 51 40 E 0-083 2.08 S 47 6 59 E 0.167 2.31 S 33 11 49 E 0.116 2.57 S 20 53 45 E 0.000 2.97 S 10 12 8 E 0.083 3.57 S 0 58 55 E 0.083 4.37 S 6 19 19 W 0.083 5.15 S 11 4 0 W 0.167 5.74 S 14 8 3 W 0.083 6.24 S 16 59 51 W 0.052 6.77 S 18 52 21 W 0.133 7.38 S 20 41 40 W 0.083 8.18 S 23 21 31 W 0.167 9.88 S 25 3~+ 51 W 0.833 12.27 S 27 2 25 W 0.083 0,00 -0.11 -0,12 -0.01 0.21 0.30 0.24 0.12 0.06 0.39 0.73 1.16 2.81 3.52 4.37 5.15 5.71 6.17 6.67 7.23 7.92 9-4'7 ....... 11.66 ,/i ~ 0 ~U~ ARI, JK WS-1 " ., T,::D VALUES FOR I'~'~TF::tP(~I-A ~ TRUE '..IF ASUR fid VFRT I CAL {)F o T !-'.1 DE P T H 100~ 999. 2000 1999, 30()0 2999 EVEN GYROSCOPIC SURVEY JOB NO 4453 1000 FEET OF MEASURED DEPTH, SUB SEA TOTAL COORDINATES 901, "t~i. 0,99 S 1901, 6,41 S 2901. 23,34 S 1.57 E 2,19 W 4.76 W 22 APR 81 AR'CO, I,{t.IPARUK WS-L ".:[ASUqFD :.')[PTH AN..r) OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB FEET OF .qEASUR ED DZP 198 298 39.8 4.0 P., 59~ 698 798 :?98 1008 1198 12o8 139!3 149~ 159~ 16c)~ 1 lqqq 20 q ?, 21. OR 230q 24 q ~ 2598 27om 209 ,fl TRUE VERTICAL SUB. MD-TVD DEPTH SEA DIFFERENCE 198, 100 0 298. 200 0 39~, 300 0 498, 400 0 598, 500 0 698. 600 0 798. 700 0 -., 298. 800 O' ,998. 900 0 ].o98. 1000 0 1198. 1100 0 1298, 1200 0 1398, 1300 '~.0 1498, laO0 0 1598, 1500 0 1698, 1600 0 179~, 1700 0 1898, 1800 0..: 1992, 1900 0 2098, 2000 O 2198, 2100 0 2298, 2200 0 2398, 2300 0 2495, 2400 O 2598. 2500 0 2698. 2600 0 2798, 2700 0 2898, 2800 0 2998. 2900 0 VERTICAL CORRECTION . 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0- 0 0 0 0 0 0 0 0 NO SUB 4453 SEA TOTAL 0 0 0 0 0 0 0 0 0 1 1 2 2 3 4 6 6 7 8 10 12 14 16 1,6 21 23 DEPTH, COORDINATES · 07 N ,05 S · 31 S · 43 S ,39 S · 28 S · 26 S · 63 S · 98 S ,41 S · 92 S · 39 S · 91 S · 56 S · 33 S .04 S · 56 S · 96 S .40 S · 90 S · 49 S ,86 S · 86 S · 73 S .70 S · 56 S .62 S .07 S · 30 S 22 0.29 E 0.46 E 0.60 E 0.78 E 0.92 E 1.02 E 1.26 E 1.48 E 1.57 E 1.53 E 1.27 E 0,92 E 0.53 E 0,07 E 0.46 w 0,98 W 1,39 w i.S1 W 2.18 w 2.59 W 3.22 W 4.23 W 5.53 W 6.82 W 7.90 W 8.29 w 7.7O W 6.29 W 4.79 W APR 81 A~%0, KUPA.°,UK WS-1 GYROSCOPIC SURVEY JOB NO ~453 22 APR 81 RECORD OF SURVEY TRUE :.~EAS, DRIFT VERTICAL ~)EP TH A'.IGL E DEPTH r) v.. SUB DR I.:F T SEA DIREC DEG, TOTAL COORDINATES 2500 1 15 2499.89 2401.89 S34,06W 2600 1 19 25.99, !~7 2501.8'7 S23,06W 2700 0 50 2699.85 2601.85 S 1,23E 2.~ 00 I 40 27-99.82 2701.82 S32,53E 2900 1 34 2899,78 2801.78 527,83E 3000 I 30 2999,75 2901,75 S40 · 1..3E 3050 ] ].9 30/+9.73 2951.73 12.78 S 6.85 W 14.76 S 7.93 W 16.60 S 8.28 W 18.66 S 7,66 W 21,ii 5 6,23 W ' 23,34 S 4.73 W 24.24 S 3.89 W ~?OTTO:4 ~tOLF. CL. OSURF,.,.. 24,55 FEET AT S 9 6 58 W CLOSURES DISTANCE ANGLE D M S 14.50 S 28 12 23 W 16.75 S 28 15 17 W 18.55 S 26 31 41 W 20.17 S 22 19 13 W 22,01 S 16 27 26 W 23.81 S 11 28 17 W 24,55 S 9 6 58 W DOG LEG SEVERITY DEG/IOOFT 0,083 0.084 0,500 0,834 0,083 0.084 0,333 SECTION DISTANCE 13.6° 15-£, 17.68~ 19.62 21.82 23,79 24,55 Check Form for timely compliance with our regulations. 0perator, Wel 1 Name and Number Reports and Materials to be received ~by: 3- D~te Completion Report Well History Samples Mud Log Core Chips Core ~scr%ptzgn Registered Survey Plat' Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Required Yes Yes Yes Date Received Remarks , STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION C, ~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well IX] Workover operation 2. Name of operator 7. Permit No. Atlantic Richfield Company 80-140 3. Address 8. APl NUmber P.O. Box 360, Anchorage, Alaska 99510 5o-029-20537 4. Location of Well at surface 321'FNL, 201'FEL, Sec 9, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 98' RKB ADL 25648 9. Unit or Lease Name Kuparuk 25648 10. Well No. WS ] 11. Field and Pool . ~_-.-__-__,, :_..- :. ~]~,-~, Kuparuk River Oil F~el~l For the Month of. Jan & Feb 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] ]/]3/8]. Dr]d 6-l/8" hole to 3]90' (2/l/8l). (See attached Drilling History) Completed well 2/5/81. 13, Casing or liner run and quantities of cement, results of pressure tests 16", 65#/ft, H-40 cOnductor to 82' Cmtd w/395 sx AS II cmt. 10-3/4", 45.5#/ft, K-55 BTC csg w/~hoe @ 2211'. Cmtd w/800 sx Ext. Fondu & 461 sx AS II cmt. 7", 26#/ft, K-55 BTC csg w/shoe @ 2927'. Cmtd w/350 sx Class G. (See attached Drilling History) 14, Coring resume and brief description Shot 19 sidewall cores f/3190'-2957'. Recovered 18 or 19. 15. Logs run and depth where run Ran DIL/SP/GR, FDC/CNL/GR, CBL/VDL/CCL/GR, CAL, Gyro. ,1 6. DST data, perforating data, shows of H2S, miscellaneous data Gravel packed 4~" tbg x 12" formation f/3190'-2857' 2 (See attached Drilling History) 0il & Gas Cons. Anchora~ 17. I hereby certify that the for~g_is tlue and correct to the best of my knowledge, SIGNE~/~4~j~,, ~.I~.~,/. TITLE Di st. Drlg. Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 35th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate R,:,v WATER SOURCE 1 DRILLING HISTORY Spudded well @ 0600 hrs 1/13/81. Drld 13-3/4" hole to 2232'. Ran 53 its 45.5#, K-55 10-3/4" BTC csg w/shoe @ 2211' Cmtd csg w/800 sx 11.7 ppg Extended Fondu & 250 sx 15.2 ppg AS II cmt~ Cmtd top job w/211 sx AS II cmt. Set 10-3/4" pkoff & tstd to 2000 psi f/15 min - ok. ND diverter & NU BOPE & tstd to 5000 psi - ok. Drld FC & cmt to 2187'. Tstd csg to 1500 psi - ok Drld cmt, FS & formation to 2242'. Tstd form to 12.5 EMW. Drld 8-3/4" h~le to 2851'. Rain DIL/GR f/2851~209'. Drld 8-3/4" h~le to 2950'. Ran 70 its 7" 26# K-55 BTC csg w/shoe @ 2927' Cmtd csg w/350 sx 15.8 ppg Class G cmt. Set 7" pkoff & tstd to 2000 psi - ok. Tstd csg to 1500 psi - ok Drld FC & cmt to shoe @ 2927'. Tstd csg to 1500 psi - ok. Drld cmt, FS ~ formation to 3190'. Ran DIL/SP/GR, FDC/CNL/GR, CBL/VDL/ CCL/GR. Shot sidewall cores f/3190-2957'. Opened hole w/12" hole opener to 3180'. Displaced 10-3/4" x 7" annulus w/9 ppg KCL brine.. Circ & cond hole. Spotted 5 sx sand in 6-1/8" hole f/3180-3190'. Ran 4½" screen liner w/pkr & 2-3/8" washpipe. Attempted gravel pack but stuck washpipe in hole. Worked free but damaged pkr in process. POOH. Left 4½" liner & 14 its 2-3/8"'tbg in hole. Removed fish from hole f/2927-3180'. Ran. Caliper Log f/2927-3180'. Reran 4½" liner f/2754-3180' w/2-3/8" washpipe & gravel pack tools. Tstd tbg string - ok. G~we~~ packed'~4~" x, 12" annulus to 2857'. Ran CNL Gravel Pack Log f/3179-2700'. Displaced well w/KCL brine. RIH w/RTTS, open FO & displaced 10-3/4" x 7" annulus w/KCL. Ran Reda pump and 2-7/8" x 3½" tbg w/tail @ 2650' & pkr @ 2464'. Circ warm KCL thru 10-3/4" x 7,' annulus. NU test tree. Flow tested well thru separator. Ran HP Press Log. Reda pump quit due to circuit overload. Killed well w/8.8 ppg KCL brine. ND test tree. Pulled 3½" tbg w/Reda pump & pkr assy while filling ann w/8.3 ppg H20. Circ & cond hole. Ran gravel pack log & Gyro. Arctic Packed 10-3/4" x 7" ann w/88 bbls Arctic Pack thru FO & closed FO. Set completion pkr @ 2587'. Ran 3½" tbg w/KOBE pump BHA. ND BOPE. NU tree & tstd to 3000 psi - ok. Tstd tbg to 500 psi ok. Set & tstd pump. Displaced 3~" " . - 2 x 7 ann w/diesel Secured well & released rig @ 0800 hrs 2/5/81. Alaska Oil & G~c Cons. Commission L WELL, WA~. SURFACE L TOP OF KU . source: fi..,S P U D D ATE, z/].4/st OCATION: 321' FNL, 202' FEL, See. 9, T~.ZN, R].0E P ARUK: UA BOTTOM HOLE LOCATION: =NA KB ELEVATION' _,98,o , GROUND ELEVATION: ~n - '. ., . ALL DEPTHS MD-RKB 16" H-40 65# @ 82' · F O in 7" csg 10 3/4" K-55 45.5# @ 2210' PaCker @ 2464' @ 1809' UPPER SAND' MIDDLE SAND' LOWER SAND' Reda Pump Assy (Pu~ps, Intake & Motors) Reda PSI Unit @ 2583' · Top of Liner @ 2754' . Packer '@ 2757' '3' 1/2" 9.2] N-80.BTC Tbg 2 7/8" 6.5# N-80 EUE Tbg 2 3/8" 4.7# J-55 BUE Tbg Otis 7" RDH Packer 2 3/8" 4.7# J-55 EUE Tbg Otis 1.875" ID "X" NiPple 2 7/8" 6.5~ N-80 EUB Tb~ Reda Upper Tandem Pump Reda Lower Tandem Pump "' Reda Pump Intake Reda Seal Assy Motor Protector Reda Upper Tandem Motor Reda Center Tandem Motor Reda PSI Unit HOWCO Bundle Carrier ,. 7" K-55 26~ . .' .:,. @ 2927' ~:": :' '--. · Underreamed Co 12" · 4 1/2" 11.6# 3-55 Blank Liner from 2783' to 2937' ' 4 1/2" 11.6~ Wire Wrapped to 5.15" OD Liner from 2937' to 3152' Reda Retta Red ~2 Cable 4 1/2" x 5.15" Upper Tattletale from 3152' to 3160' . 4 1/2" x 5.15" Lower Tattletale from 3162' to 3178' · . · 4 1/2" Bull Plug ~ 3179' ; · · NA NA NA O' to 2400' 2401' to 2433' 2434' to 2464' -' @ 2464' 2472' to 2482' 2483' 24~5' to 2549' 2550' to 2567' 2567' to 2583' @ 2583' ~-' '2584' to 2590' 2590' to 2610' 2610' to 2630' 2630' to 2635' 2637' to 2645' ~.' REVISION NO. D ATE, - · . .. , 0 KO'P~UK ~IVEE FT~W~ C~ET~CEOU$ ~ DEIA-v'E~B ~ TEST Production testing on the cretaCeOus WS-1 well is completed. The w~ll test.and completion report is currently being~i~inalized..~ The following ~ of events includes preliminary test results: A 3,180,'M.D. well was drilled on B-pad and completed with '257' ~of open_hole gravel pack'~. ~-tubing suspended Reda Pump, hung below a Daul Packer, was set 100' above the gravel pack liner. · Heated brine cir- culated above the packer provided freeze protection. The well was on production a total of 28 hours. Cumulative production was 5,000 bbls of water. The well flowed stabilized at 4,700 BWPD ~for 10 hours with a measured productivity index of 37 BWPD/psi and a ~.R of 11 SCF/bbl. The first production period was followed bY ~a 12 hour pressure buildup.~ Shut-in reservoir preSsure"'~at'~3,050'~iTVD~is 1'342'psi~'~' Bottom-hole samples were collected. The~welI-flowed' without'?~i~al lift at 1,000'BWPD for 6 hours~with flowing tubing pressure ~of '10 psi, ~ The third production period included stabilized flow for half hour increments at 7,730 BWPD, 8,000 BWPD, 8,120 BWPD, and 8'830 BWPD? Average productivity index measured at 49.5 BWPD/psi. Sand production at the 8,830 BWPD rate cause a B~da Pump failure. The Reda~ completion was pulled and replaced with a 'Kobe Jet-Pump completion.. The formation was produced without sabot production for 30 minutes · at 2,750 BWPD. Prelim/nary water analysis indicates ~,~-3~mg/ liter sulfate,~and 2 mg/liter barium,'~ The well was suspended with the Kobe- pletion and diesel placed' across the 'permafrost. .... NORTH SLOPEENG]I~TM~RZNG Date: F~L ~% /~/ From: J. J. Pawelek / Leo Lash Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, I i~L._ ~ IS, F - Film, T - Tape ~-' ~. 13 ..:N~: --~ 4 EN(: 1 GEC ' ~TAT' ---~'-STAf-; CONF:R: FILF: ARCO Alaska, Inc. . Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIYED FEB 1 ? ]9.8] DATE: R!~J'; '",il & ,Cas ~,,~. Commission An~omge. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton~ Chairman Thru, Lonnie C. Smith //i~3~i~f commissiOner ~ Doug Amos ~ Petroleum Inspector January 26, 1981 Witness BOPE Test on ARCO 'S Kuparuk ~'WS-1 Wel 1. Sec. 9, TllN, R10E, UM Pe rmi t No. 80-140 on Parker Rig 141. Thursday January 15, 1981: I departed my residenCe at 7~30 am for an 8~140'~a~ a~p~k~~ on arco's charter, arriving Prudhoe at 10:30 am. Friday Janua~ 16~ .1981: The BOPE test commenced at 6:30 am and W~s cOnClUded a~9:~0~am. I filled out an A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the BOPE test on ARCO'S Kuparuk B-we-1 well, there were no failures. I filled out an A.O.G.C.C. BOPE test report which is at~ached. DA:mm O&G #4 4/80 ~ STATE OF ALASKA ALASKA.OIL & GAS CONSERVAT.ION COMMISSION B.O.P.E. Inspection Report Inspector Operator... Well ~ Rm~ Location: Sec Drilling Contractor Location, General Well Sign General Housekeeping, Reserve pit Rig BOPE Stack Annular'Preventer Pipe Rams I Blind Rams ~ Choke Line Valves H.C.R. Valve Kill Line Valves_ ~Check Valve Date JA~u ~; ~O Well ~~~.-. ~, _ ~ Representative 3o~ ~;~!~ Permit # ~° ~O . I~' ~asin%Set @ ~6D! ft. # ~ Representativ~'~o~4 ~'~ ACCUMULATOR SYSTEM Full Charge Pressure__~~psig Pressure After Closure~pslg 200 psig Above Precharge Attained: ~ min lO sec Full Charge Pressure Attained: ~ min ~ sec N2 ~,~,~91~. t~gn psig. ~ Controls: Master b~ Remote ~ Blinds switch cover~ Test Pressure ...Kelly and Floor Safety V, alves ~pper Kelly ~ Test Pressure Lower Kelly '1 Test Pressure Ball Type I Test Pressure Insidei~O~ ~ Test Pressure. Choke Manifold I Test Pressure No. 'Valves -~. ~ ~ No. flanges ~1 Adjustable Chokes Hydrauically operated choke hrs. ~ days and Test Results3 Failures ~ Test Time '~ Repair or Replacement of failed equipment to be made,within Inspector/Commission office notified. Remark s: Distribution orig. - AC&GCC ~ cc - Operator ~' cc - Supervisor Inspector December 9, 1980 Mr. P. A. VanD~sen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Kuparuk 25648 WS-1 Atlantic Richfield Company Permit No. 80-,140 Sur. Loc,: 321~F~L, 201~FEL, Sec 9, TllN, R10E, Bottoadlole Loc.= 321~PNL, 201~PEL, Sec 9, TllN, R10E, UM. Dear Mr. VanDusen~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not re~uired. A directional survey is not required. If available, a tape containing the digitized log information shall he submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Ala. ska and their drainage systems have been- classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordtnatorts office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulation8 promulgate~ thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 2.564 8 WS-1 -2- December 9, 1980 co~mencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38,40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of ~is permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. 'we would .also like to be notified so. that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe', is drilled, 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, Ho~ H. Hamilton Chairman of BY O~!~ O? T~i~ CO~'~SSION Alaska Oil & Gas Conservation COmmission Enclosure cc= Department of Fish & Game, Habitat Section. w/o encl. Department of Environmental Conservation w/o/eno1. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. HHH = be ARCO Oil and Gas r '~pany Alaska Distri~ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 1, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' Kuparuk Cretaceous Water Source Well, WS-1 Dear Sir' ARCo Oil and Gas Company proposes to drill the above-mentioned well with operations commencing on approximately January 1, 1981. Attached please find the Application for Permit to Drill along with the BOP stack diagram, diverter drawing, as- built survey, well-bore proximity map, pressure calculation, and $100.00 filing fee. Very truly P. A. VanDusen District Drilling Engineer PAV'sp Attachments RECEIVED DEC ]980 ~.. Alaska 0il & Gas Cons. Commission Anchorage ARCO Oil and Gas Company is ;4 Di,,,i,,;i,3n oi Form 10-401 REV. 9-1-78 STATE OF ALASKA la. TYPE OF WORK DRILL r~l DEEPEN FI b. TYPE OF WELL Water OIL GAS WELL 0 WELL 0 OTHER SOUr¢o Wel 1 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 321' FNL, 201' FEL,'Sec 9, TllN, RIOE, UM At proposed prod. zone 321' FNL, 201' FEL, Sec 9, TllN, RIOE, UN SUBMIT IN TRIP '~E~ (Other instructio .... A ALASKA OIL AND GAS CONSERVATION CO[~..~_,~'O~ 1980 PERMIT TO DRILL OR DEEPEN Alaska 0il ,& Gas Co.s. Coi';~i'iilSSiUl Anchorage SINGLE~ MULTIPLE ZONE ~ ZONE (Straight Hole) 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 30 Miles Northwest of Deadhorse 14. BOND INFORMATION : Oil and Gas Bond TY~EStatewide S~etyand/o, No. #8011-38-40 (Federal Insurance Co.) 15. DISTANCE FROM PROPOSED * 16. No. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 4960 (Also to nearest drig, unit, ff any) 18. DISTANCE FROM PROPOSED LOCATION 2560 19. PROPOSED DEPTH 3120 TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 684 21. ELEVATIONS (Show whether DF, RT, CR, etc.) lundra = 63' / Top of Pad = 71' / RBK = 98' API #50-029-20537 6. LEASE DESIGNATION AND SERIAL NO. ADL 25648 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kuparuk 25648 9. WELL NO. WS-1 1 °P ~"~(~%1~ 9R Kuparuk River 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 9, TllN, RIOE, UM Amoun, $5oo,ooo 17. NO,ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 12-15-80 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement ' 24, 16 65# H-40 .,.80_+ MD Cmt to surface - ApprOx, 200 ft3o 13-3/4" 10-3/4 45.5# 'K-55 ' '.220(~+-MD cmt to surface- Approx 17§0 ft° 8-3/4" 7 26# K-55 2850± MD Cmt w/approximately 100 ftj 12" 4½ .qcreen 11.6# J-55 2650-3100 Gravel b~cked annu)us Atlantic Richfield Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool water source well to approximately +3120'TVD. A 20" x 2000 psi annular diverter will be installed on the 16" conducte~ (as 'per attached diagram) while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack (diagram attached) will be installed on the surface pipe and will be tested upon installation and weekly to 3000 psig. Following installation of 7" casing, preventers will again be nippled up and tested while drilling the liner interval. A 4½" gravel pack screen liner will be run to TD +3100 and gravel packed. The interval will be tested with a downhole pump set below a-production packer on 1 II · ~ 9 2# J-55 Butt. tbg. Non-freezing fluids will be left in uncemented annuli thru the pe rma fro s t i nt~r~ ~PACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subdu~face locations and measu~.d and true v~tical depths. Give blowout pzeventer program. 24. I here.~ that the Forgoing is Trg~nd Correct (This space for State office us~) SAMPLES AND CORE CHIPS REQUIRED nYES DIRECTIONAL SURVEY REQUIRED OYES ~'NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG ~N [] YES O OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE S~B- o ~.¥-~3-3 "7 PERMIT NO ~'~0 "/~ ~ APPROVAL DATE BY. ORDER OF_.1~ CO~I~.~$SIOH *See Instruction On Reverse Side _nec3av_._her 9, 1980 12/09/80 DATE . .® Surface Diverter System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. -20" bel-I nipple. -Maintenance & Op..eration ~ · 1. Upon initial installation close annular I preventer and verify that ball valves ! have opened properly. I 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. 3. Close annular preventer in the event 16" Conductor that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. _. Do not shut in well under an~ circumstances. RECEIVED ~daska 0il & Bas Cons, Commission Anchorage IRNNULRR PREVENTOR 9 BLIND RRHS' 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lin6s 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular ACC~1ULATOR CAPACITY TEST PIPE RRHS 7 I SPOOL PIPE RRHS 5 TBG HD 3 CSG HD .. RECEIVED [,'EC- 1 80' 0ii & Gas Cons. Commission Anchorage CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCU~IULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAI4 OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN, ING AFTER ALL UNITS ARE CLOSED WITH CHARGI-~G PUMP OFF. 4, RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST l. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETE~,IINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3, CLOSE ANNULAR 'PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR l0 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR lO MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREN,! OF CHOKES. BLEED DOWNSTRE~.I PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~IAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. - 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR lO HINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND R~,IS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLI;;G POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOiIEY PUHP. 15. RECORD TEST INFO~.~TION ON BLOWOUT PREVE~iTER TEST FORM SIGN AND SEND TO DRILLI~;G SUPE~- VISOR. 16. PERFO~-I COiPLETE BOPE TEST ONCE A WEEK FUNCTIOI~LLY OPERATE BOPE DAILY. r: · IJ II II I II II I I I I I - ' ~ ARCO AIImka, Inc. '~ ~~_"~,~ ~: KuptrUk ProJ.ot . North t. le,pe [ ~ ~~' ; ::. t ' " '"' ~,~ '~ ~~1 "" :: 'date.: /~-~-~Z ~eale.: / ~' ~ i i i i . ~ ~Mi~ drawn by:~ dwe. no. Nf~ ~ II I I I I I PRESSURE DETERMINATION WS-1 is being drilled as a water source well which will require artificial lift during production, the zone of production lies about 2850-3100' below ground level. From other wells drilled on the Pad (West Sak 7 and B1) it is known that formation pressures are less than 1500 psi to 2850' as the intervals have been safely drilled with lO.l#/gal mud. In the unlikely event full reservoir pressure (1500 psi max.)should be applied to our 13-5/8 5000 psi W.P. BOP stack, pressure could easily be contained due to the pressure rating of the equipment. Pressure integrity can be assured while drilling to 2850 as the stack will have been tested to 3000 psi prior to drilling out at' 2200 the day before. ~[aska Oil & Gas Cons. Commission Anchorage ~ ~ ~: ~ '~ . ~ '" , ., { V ' V' V V V ~ V ' " ~.~' e? .:,?/.." . ..)~ .., .-. . ~'- . , , WELL 'l Y = 5,969,646.72 WELL 1;7 Y ' 5,969,647~31 X = 549,457.40 X = 550,1~**,~ LAT = 70°19~40,290'' LAT = 70°19~40,2[q'~ LONG . 149°35'56.O5~'' LONG = 149°35'35~O35'' WELL /~2 Y = 5,969,647~44 WELL ~8 Y = 5,969,646~98 X = 549,577~73 X =. 550,297~7q LAT = 70°13'40~2qO'' kAT = 7OO19~,40~237'' kONG~ 149°35~r.~2.543'' LONG = 149°35'31~522" WELL i~3 Y = 5,969~646.,.89 ! HEREBY CERTIFY THAT I AM X = 549,697~h7 PROPERLY REGISTERED AND LICENSED LAT * 70°19'40.27~'' TO PRACTICE LAND SURVEYING IN L'ONG = 149~35~49~O4~'' THE STATE OF ALASF~ AND THAT THIS PLAT REPRESENT5 ANg AS- WELL .:~4 Y ~ 5,q69,647~31 BUILT SURVEY MADE BY ME, AND X = ¢49,817.62 THAT ALL DIMENSIONS AND OTHE~ LAT = 70°19:40~272'' DETAILS ARE CORRECT, kONq = 149°33'45 539" -DATE t/~/~ '--'" -' . o ....='~' - C. .'' . ,... WELL ~5 Y ~ ~,969,6~7,2~ .~.4.. ., .. = .~0,057.33 .-' ..- LaT = 70° ) 9' 40,256" Alaska 0il & Gas Cons. Commission ,.. · -- -' ~o ~ Anchorage "',-- ' ..... = ' "'."-- ..... -' . m · · I Ill mil I I m i -P.~. ~, WELL~ 1 -8 LOCATIO~ A~' BUILT ' ' 'o,.co ZZ:v' * ............... Atlantic~ichfi ~ATE: ~AWlNG No: NOaT. AMEriCAN PaODUC~Ua D~V~SiON I/~/80 ..... ALAS~ D,ST~,CT- KU~A~U~ .. .... ,, ...... . , , ,, ,,. -' m,i ........... --' CHECK LIST FOR NEW WELL PERMITS Item Approve (1) Fee (2) ¢¢¢ (4) Casg- (5) BOPE ~ Date / % - ~,-~. 1. 3. e ~~y Yes No Is the permit fee attaChed ..................................... Is a registered survey plat attached ............................ . Is mi1 located proper distance frcm other mils .. ~, Is sufficient undedicated acreage available in this pool ............ q~ ,, Lease & Well No. ~~.~ k Remarks /, 7. Is roll to be deviated ................................ ~~ i 8. Is operator the only affected ........... / 9. Can pemit be approved before ten-day wait ......................... /%-~-~. 10. Does operatOr have a bond in force .......... - ........... ........ '11. Is a conservation order needed .................. 12. Is administrative approval needed ............................. ..... 13. Is conductor string prov ....................................... 14. Is enough cement used to circulate on conductOr and surface ........ ~ 15. Will cement tie in surface and intermediate or production strings . .~?~ 6. Will cermnt cover all known Productive horizons .................... ~ 17. Will surface casing protect fresh wa~_.r zones ...................... ~~- 18. Will ali casing give adequate safety in collapse, tension and lm.rst.~~ 19. Does BOPE have sufficient pressure rating - Test tO ~-o o psig .~ Approval RecGmnended: Additional Requir6ments: Geology: rev: 03/05/80 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. LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil & Gas Well WS-1 Field Kupa~uk County,State North Slope, Alaska Date 5-19-81 Curve Name '(Abbreviated) Standard Curve Name Logs Used Scale SP Spontaneous Potential DIFL 0-100 GRI Gamma Ray ,,, DIFL 0-100 RXO Shallow'Induction DIFL .2-2000 , ,. RILM Medium IndUction DIFL ' .2-2000 RT Deep Induction DIFL .2-2000 GRA Gamma Ray BHC/AC 0-100 AC Acoustic BHC/AC 150-50 , , GR1 Gamma Ray ~,CDL/CNLOG -~ 0-100 CAL Caliper CDL/CNLOG 6-16 '-~EN Bulk Density CDL/CNLOG 2 3 CORR Correction CDL/CNLOG -.25-+.25 CN Compensated Neutron CDL/CNLOG 60-0 DENP Density Porosity CDL/CNLOG 60-0 .... GR2 Gamma Ray CDL/CNLOG 0-100 ~' E~C ~tIMBE~ ~72q. o00 ARc9 OIL A,X~D GAS ..... WS-1 K~.Jc~ARAK ..... NORTH SLOPE, ALAS~(~ HL~C 672q. 1. q- CURVES : SP GRI m)~O RILq ~T $~1 CAL DEN COR'Ri OENP CN GR'2 FRoM 292~.00 TO 3200.00 LEuEL RPACTNG 0.5000 lpS. ~AMPl ES PER RECORO mAr..,E ]. ARCO OIL AND <UpARAK ..... NORTH SLOPE, 3ATA EVERY 3.. S,a.~PLES Gn, S ..... WS-1 ALASKA HL&C 672q, SP 292~.00 14.35 292.q.u. 5 O 19.09 2925.50 23.60 292~,00. 25.49 ~92~.50 26.83 292'7.00 28.1'7 29'27.50 29.70 2929.50 33.53 2930,00 33,33 ~9'30,50 32.~3 293~,00 51,9~ 2932.00 31.77 82.~7 82.87 &2,~$ 81,75 80.88 80.55 80.22 79.95 79.7~ 79.73 79.69 79.67 78.96 79.1~ 79.52 80.5~ 81.08 29.3':. 00" :31 · Sq. 8. :~. 01 32.51 835.69 0.7& 1.06 1.37 4.35 ~.67 ~.40 5.57 6.17 &.28 6.33 ~.2~ 6.32 7.~2 B.02 7.58 7.~7 RILM RT GR:~ AC 14.61 2.10 BG.G~ 167.72 1~.~0 3.,,0,8 8.6..5~. 169.~5 12.~3 S.4~ ~..95.. 168.86 11.65 3.87 B~.,~2 16,5.81. 10.39 3.99 84.27 160.81 8.58 ~.51 83.87 165.71 7.69 5.88 B.3.7~ 170.1~ a,aA. a~,.3! 5.~,...~.~ .... !.7.8.57 9,~ 7.10 88,70162.~2 1~.63 7.56 82.58 I58.21 15,7o 17.o5 7,.91 ....... ~...,7~ ....... !7~.86 11,..9_8 .............. 7,.~ ............... ~..,~6 .......... !78,0.8 9,00 7 73 6.. 82 6,82': : 7.q~':9"": ::.8:::5. 95 .153.08 293~.00 35 3q. 85 ~7 5 60 ~0 G 09 8.4 5. 279131.61~15:0 35,78 86.22: 9.37" .: 21-~'59 · .:,::,-~,.,.- ;:.,:~,.~:.. ;.,:'2,.;'- ,.: " 2957.00 3~.58 86.63 8.95 2~.36 2.71 82.67 1~0.2~ ~'-~"5'~;'0'~ ~5,58 8'6, l 7 ::~':e ~A:'; :::::::::::::::::::::: S:~.:~:~o .:.. 8 ~:.:~: ~ ~. 29~:~.00 39.07 8~.57 6.65 6.3~ 9.90 BP..90 1~5.39 9_943.50 3~/..64 84'77 B'.35 1'52'~8 iB;d 6R1 88.05 59, 28 58, 09 8.7.05 82.65 82-26 ~, OB 8_!. 29 8i .29 8'1.8~- ~.~.. 71 51.71 BI.23 ,~q .52 ~6"~.. ~0.5~ 8~.25 _8..~... 98 ::89.75' 90.65 '~.o. 6.6 '9:d. 67 86.35 ~7,o6 ............. 87. q, 7' ,.< 861.28 85,13 .... d'-5'. ~ 5 82.96 80.29 81.39 82.81 8~. 05 ..... CAL DEN 7.33 1.96 8.31 1.96 9.~5 1.96 8.52 1.96 8.56 1.96 9.57 1.96 9.76 1.96 9.90 1.96 8.37 1.96 7.95 1.96 B.08 1.96 8.t5 1.97 8.62 1.97' 8.65 2.00 8.69 2.0~ B.57 2.07 8.61 2.06 8.6~ 2.05 8.69 2-05~ 8.56 2.0~ CORR O£N~ CN 0.03 36.99~ ~6.83 0..03 39.00 ~q.31 9.02 ~9.77.' ~.21 0,01 51o~9 ~.37 0.01 51o~.0 0.01 51'.85 ~5.06 0.01 55.90 ~.1~ 0.00 55'66-' 0,01 ~6.~8 ~.1~ o.o3 ~0.5~ ~5.2~ 0.03 ~1,,~9 ~5,9~ 0.01 ~.%9 ~8.1~ 0.01 ~l.to 50.a8 0.0~ ~5,9~ 50.~0 0.02 3~,88 50.79 ..... O.O1 ~.~,.~ 50..~5 o,,0! 88 ~9.~5 o.ol 0.02 351:,8~ ~9.78 0.02 ~-98 8.58 1.97. .0..02. ~!:,.58 .... 51.,.3.0 8.6,3 1.97 0.02 ~3:: 53.02 8.67 1'98 O, 0:2 87.81' 83'. 53 79:.76 79, 72: 80.13 82,06 8~.~0 8~+, ~5 8~:.7~: 8~.86 8~:. ~1 83,70 83;21 8~:, 08 8~.50 87. 87"~&: 88'% 75~ 8.80 8.84 8.92 B.97 9.02 8.95 8.97 9.35 10.~$ 11.12 I0.86 9.68 10.83 11.16 10.70 10.2~ 9.98 9.7~ 9.5._8 9.26, B.92 8.92 8.88 B.89 8.85 8.6q- 1.96- 1.96 1.96~ 1.96 1.965 1.97' 1'97 1.97'~ 2.02 2.0~ 2-0~ 2.10 2.09 2.12 2.16 2.18 2,20 2.21' 2.22 2,22 0.01 57.11 ~8.83 -0.01 57"92: ~9.82 -o. o 1 55';' 9~ 5o. 6~ .o_:.oo: 513~9i 0.01 ~3,'7~ ~.35 0.03 36,~5 ~.~.8~ o.o3 3~.e.5 ~.9~ o.o13~13~'~ ~.8.'017~' 0.'03 3~"171' ~9='89' 89,25 89.05' 88.~6.: 85~I2 83,53.: 82.8~ 82.0~ 8~. 01'.0.1 · 1311'9'~::: 50,501 '82.:'95'::: 0.01 31.61 51.21 82,00~ 0.01' 2'8','75 ~6.82 8e,99~ o:02 e?;:.i~ 8'5':.9:~ 9'02 28.02 50.71: 85,86~ 0'02 27'.5~ ~9.87 85,75 0.01 26.91 ~9.68 85.58 PAGE 2 ARCO KtJpAR/~' ..... NORTH ] AT/~, Fi'_ il E R Y !. OIL AND 3&g ..... WS-1 SLOPE, ALASKA HL&C 6724 SAq~LES 294g.50 2950.00 ~95n.50 295] .00 B5.53 80.77 ~g5.~.5o 35.98 75.54 ~95~.5o 55.~1 75.~5 2953.00 36.o~ 71.86 .295.~_,50 36.77 69.45 ~95.~__.0o 57.~ 65.!0. ~95~.50 41,29 G0.65 .... ~955.00 ~.29 54.96 ~955.50 ~5.84 5~.~9 295~.00 ~4,27 52.57 ........... 295~.50 ~.68 52.57 2957,50 45~35 53,95 07 57 ~ Sp $~! ~xO RZLR RT BRA AC 53.71 85.26 9.62 11.26 Z0.07 92.85 136.22 33.66 82.71 9' 45 6.79 9.2~ B,~,,,15. 1~8,85 33.71 81.71 9.45 7,06 8.92 9.49 8.19 79.47 129.70 S.56 ~4.08 7.92 77.,~5 ....... %33.,.98 9.~0 9.69 9.12 10,85 20.75 20.20 I~.I9 12.67 !2,29 11.53 9.53 7e.~q 135.67 9.60 9,32 70,13 137,38 12.26 1~,0.~ _ ~7..~6 20,59 58...,95 ......... 156.10 26,67 15.88 55,61 156.7~ 17.B1 12.74 5~,22 152,91' 2!.87 87.51 B7,99 ~..8__. 40 89.21 9_..8.., 86 88.10 86.85 83.88 76.99 71,1~ 60.~7 55.~ .~.2_. 2 ~ 8,19 '~., 48 ......... 7.7_.,..8_0 ......... 1_5_2.., 73 .... 73.62 ~960,50 ~.0., 20 87',26 9. ":~i~i!;iiS;d:':."/"~:~, ~'2 ............. ~' ' '~',' .......... ~_6_8_,_5..0 ....... ~_, 7..0 85 0.0 ~. ~.7 ..... 9 ,.3! ................ 6~._9.~ .......... 81 .... 81.: ........ !~.6 ,._~ ~ ~_~6.~.._....0.0 ~.97 81.~.5 9.~5 9,~9 ....... 7...8.5 ........... ~.0 .~.5 .... 1..3~. 50. ~96~,50 ~,~0 80,05 9.55 9,.~7 '7'~ ........... ,~.:~6.5 ,._5.D ........... 35.32 79 ..91 9.96 10 93 _.9.87 .... BI. 76 _ 131..~5 .......... _8..~.6_6_,_~.0 .... ~5_. 5 ~ 8 !, ~! tO 0 ~ ~1.,_0! ...... 9, 56 ............ ~2._2;?; .......... ~2._15 2 6 51 82.99 10.11 1 51. · 8 ~ 10 ', ............... ~_6_S.5o ...... ~_0., ~o 88. ~5 Z O. o7 s, 6.5 ......... .......... 27 6 %_0_0 .................. 29.. 5 ~ ..... 89 .. 5.~ 10 . ~ 1 ..... Z...8 ~ .....8 .... 09 .................... B_~.~.3_8 ............ 132..~36 : 2969,50 28,26. 90.29 9 78 7 ~<~;~;~.:.; ~o 9.0 7~ s.5<~~ ..... ~.~.~._~ .... ~o ..... as.~t ~,.~ s.~o ~.~ .............. ~z_~_o.o ...... .~..o ~ .~7..~7e. z ~.~... o.~ . ~....2_~ ~..~. ~., ....... 31 8G, 9 .~:9~::~ 50 2~.~i 8~.8~ 9, ...~e ....... '~.~.?~,~,: oo ~o. i9 s~. ~ 9 i ~.. ........ ~_?7~__,_5_0_ ......... ~.0,.~ .87',~9 e, 79 ..... 9,52 32 L.8.3...~2 O~ .i ...S.~. , 96 05 __91.. 62' ___9~. 8.6 }.~:::? '. .... :.9 5. ~ 0 .95' 05 7 9..1_.9 ....... B_l . 7...9._ ........ 1.26 ,_72 ........ _9.1 CAL DEN 8.68 2,22 8,63 2,21 8.64 2,15 8.6~ 2,13 8.64 2.11 B.60 8.58 2.1~ 8.5~ 2,12 7.56 2,17 6.16 2,18 6.19 2,17 6.~3 ~.16 $.~$ 2'.10 6.21 2.10 6,21 2,08 6,22 2,09 6,23 2.09 6.23 2.,13 6,17 ~,19 6.18 2,22: A.16 2~21' 6.19 2.19 ...... 6.24 2.18 6,21 2.,17 SORR DEftp 0.02 27.15 0-02 28.0.8 ~....03 30.27 0,03 30,99 0,03 30,~M O,Oq ~0.89 0.02 0.03 37,05 0',0.~ 3~,.67 0.0.2 ,,30,9q~ 9.02 31-12 0.01 31,21 0.00 31.,,~? 0. O1 32' ~2 0.0! 3~, ~9 CN 50,~6" 51.52 .52..39 ~6.21 ~6.80 ~6.68 ~6,55 ~7,13 .~6,.5.5 ~,72: ~3'.17 O ,.01 o.o1 3q:,. 25 ~4.' 65 85.g9 86.15 86, 63 87'. Oq~ 86-70 sq,. 12; 80.7~ 7q.,77' 69' 24. 65,~0 61,55 58. q. 8 56- 05 Sq,. 58 53,20 51.39 52:. 5q,~ O..O0 28.61 _~6_..96.' 60.58 O.O0 26,06.. ~.7,~8 68,33: O. 05 99 0 ....00 25o .~.:3,' .............. ~9;..6.1.; 89.:..88 0. O0 . 2.6..58. ........... ~.6,'..65': 86,,. §5? ~. O0 83,8,1 6.2~ 6,.20 6.20 6.20 6,17 6.20 6,20 6,19 6.17 ~.17 6.17 6.17 6.14 6,15 6.16 6.13 6.17 6.17 6.17 ~.17 6.19 6.21 2.19. o.o~ 2..19': o.o1 2.19' 0.0.1 2,17; O, 2.15 2,15 O. O,1 2.1.{+ O.O1 2.1~ § .0.1 2.~ 1~ '' 16 O'O 1 2.19 O..02 ~.'. ~8 26- q. 91. 0~:' .25r.18.0 .~'.:9., .5.~. · 25,90. .52. 9~ 2.9.5'9' . 5.5'...19 3l- 9.5':: 55,5.1': 27.55; 51..87' 26,79 50_.93 02- ~o37' 82; 38: 8.~, ~ 2.. 8.5 =' ,,q. 5! 76 7O :95, ~0 95~ 87" 90.., 52:' 52: ,53 0 o. 02 2q,:, 65 86 91.38 0,02 22'q'4 50,15 91,8.9' 0.01 ......2:2.,56 50.33. 90_,90 °AGE A ARCO OIL AND KUPARAK ..... .~-]OR T H SLOPE, 3AT& E~/ERY 1 SAHPLES ~LASKA HL'AC 6724 . ..: SP $RY R~O RYL~ RT BRA AC $21 gAL ~97~.00 31.86 87.6~ 10.18 9.74 9.5~ 81.29 127.61 91.0§ 2975,50 32.86 87.70 10.57 9.86 9,81 50,80 130,76 91.,80 ?..9~..6.~ ...... 3~,29 87.B1 9.7~ lO.ll 10..~2 ..... 50...67 135,39 92,~0 6.22 29.~.7...00 3~.86 87.70 10.26 10.55 1Q.,3~ ......... ~..E,.6Z ...... 1.3~.,.37 92.,79 6,20 2977.50 35.1~ 87.70 11.15 10.58 9.96 80.68 137.87 95'13 6.16 297~.00 35.3~ 87.32 10.91 10.~ 9.85 80.9~ 137.90 93'~6' 2972.50. 35.5~ 86.98 10.70 10,12 9,8} 91,52 137.37 93,26 6.19 2979.00 35.79 87.33 10.38 lO.Ol 9_,B.~ 51._.7~ .... 1..36.5~ 9!,39 ~97q.50 35.58 87.09 1.0.26 .9..~9 9,6~ ~1,_~.9 ........ 1.~5.21 90,37 6.18 2980,50 33.~7 86.39 9.8~ 8.98 9.30 8.~.53 132.09 89.95 6.22 296t.00 32.67 89.20 9.52 8.7~ 8,57' 95,60 130.72 90.57' 6.23 298.~.50 31,67 90.30 9.67 B.SV 8.19.87,50 129..87 9[.,20 ~9~.00 30.5q. 91.86 9.99 8.39 8.05 99.11 1~9.25 9q,.lO 6.26 2983.00 2R.30 93.51 B.82 7.99 7.9~ 8~,~8 130,65 9~,06 6.21 2965.00 29.36 90.17 9.71 B.O0 7.39 87.77 1~5.1+0 97'. L~8 6.23 .................. ~-'~-'~":~"~ ............ .~-0:~7 .... ~'9.,'~ ' 9'2~'~ ....... ~':i"'~ .................... ~'-:'~-~'~ ............... ~"Y:~b ............. ~"g~'-:6'~ ~ 9~":~ 6. ~ DEN 2.26 2.26 2.27 ~.28 2.26 2.25 2.26 2,27' 2.28 2.26 21.25 CORR DENP CN 0.01 22o8W 0.01 $~,.2.$' ~8.75 0.02 2~...~5 ~.7'.85 0.01 25,56 0.01 23,62 0,01 2~,5~' 0.01 $!,!.5 50,39 0,0.2 .... ~,..0,,~ 0.01 1~.7~: ~8,77' 0.01 15.~5 ~9.$8 0.01 19,90 2;,~+. 0.Ol 85 5!.9o 2.2;5: 0,..01 51, L~5~ 89'. 2:1. 90,06 90.20 87.{+1- 87;22 87,27 87° 57 87-19 86- 3~ 92,, 1~- 9s.8~~ 96~- 5~ 97" 02 :: 2,25: 0.0I 2q." 15- 50.95~ 98'25! 2.25; 0.01 .2q.. 27 52,20; 97' 2.2~ 0.01 2~.65; 52-. 7~ 96r, 1~.~ 2:,25 0.02 25,03 52,62 ~.e~ o.o~ ~s.~6 s~.s~ 9~:, ~982.00 35.28 85.1e 10.55 8.79 8.78 80.~8 l~7.0G 2991..00 4+5.01 72.95 lO.1l 10.6,0 10.91 69.11 1~9.68 ( "- ~'~"~"~"-2"~-~ ...... ,~ 5 71.5 ~ 10,5 0 11, ~5 ii" O"i .......... ~'~"'2'-'~'~ ..... i-~-~"2' 0 0 e99~.00 ~8.51 71.80 10.57 11.76 11.23 !.0.92 10.80 1,0.82 10.80 10.68 11.03 7{+.73 128.43 10.7~ 10,78 75.28 129,09 6.1'9 6.20 6.20 6'.17 6.16'. G.16- 72.12 6.20 69. ~2 6,,. 2O ~'~'. ~9 6..:[7 6,17' 6.20 .6... P_O 2;. 20 6.17 2. ~ 0 '~:. 62 .6.16 2.21 95 6 19 2 22 8.:~:,' 5~6. ~ 3' 2:-23." ~ ..76 ~. ~ ~' 2:.22 3'. 99 6.17' 2. ~0 .~;':-~':~:.' ~. ~ ~:. ~o ~9:" 89': ~.~7 2.20 ~'~"~ ~ s ~. ~ 9 ~. ~9 2;,23' 2'.. 2~ 2,2.3' o..,..o.~. 2.5_,'~8 ..... s~. o6~86, o2, 2,22 0.01 25:~, S5: 52~08 '8':5':,52' 2,;21',. ..... o.:,. ol2.~.~O'!S~':': :.50';:'72: . a,,~o~ o..o~' ~6.:~:~' ' .5o.oz~:~. 2.:, t9 o, ~:~:',:O::i;.~. ~:.:~::~':~: 7o., 93:. ......... 2.16 0 .. 00 2. 7', 77 ~ 6. 2, 17 0. o 1 27', 66. ~ 4 · 53 67', 25 ~:.' ~o' o. o~:. 0.01' 26.06 q, 8.37' 0. o'1 25, 87' v8 .'i 3: 85-. 2:2.': 0 :. 02 25":.7'7; ~::8:::~-;;3 O' 8~;. 20 0.00 26.90 q, 6 ,. 62 85!. {42., 0-0! 28'.05. ~8..5'9':' 80.17" 0.01 27.5~ ~8.2~ 79.6.9: . PAGE ~ ARCO KUm&RAK ..... .NORTH DATA EVERY OIL AND $&g ..... WS-1 SLOPE, ALASK& HLA6 6724 S&MPLES SP ~00o.50 ~7.59 5001.00 ~8.02 5001.50 48.61 3002.00 49.28 25002.50 50.Oil 3003.00 50.83 3003.50 51.67 2500~,00 5.9..~6 ~00~ .=0., 53.66 5.0.05.50 55.99 3oo~.oo 5~.79 300~.50 57.08 25o07.00 56.5~ s007.50 5~.06 3009.5.0. 5I. 20 SRI qwO RILM 75,58 10.58 10.65 7q,SB 10,58 10.90 74. ~9 10.59_ ~!, 52 73.~9 70.1R 66.33 62.71 57.79 55.4~ 525.78 53.30 5~.90 56.15 57,59 RT BRA AC 11,12 7'O.O& 1~.97 1~,9~ ~?,70 ~5,1~ 10.69 12.~1 1~.g3 67.~3 127.32 10.80 11.15 11.70 65,25 128.,12 10.40 10.53 11.00 63.97 128.53 10.20 10.15 10.38 ~0.09 1~8.25 9.74 10.27 9.85 58.~! ~27.54 9.3! 9,52 9.5.8 ........ 55,92 .... 127.28 8.79 8.97 9.48 ..... ~5,27 ~27.05 9.43 8.89 9..2~, 5rS..%,rO ........... ~26.88 10.57 8.93 9.20 55.74 ~26.$8 11.36 9.12 9.40 5~.79 126.55 12.06 9.56 9.7~ 5B.5~ 12~.17 12.6.5 9.97 !0.56 ........ SO...~_O ....... 125.79 ............... 3__O_!_!.._,_P_P__ ....... 4 7,75 6 0 . 2 0 9,55 1.0 · 76 9. ,5.._.5. 53_,. 7.6 .......... 1..2.~ ..5.2 25011,50 47,75 59.87 9.76 10 8 · f iii ; 2' 6: ' :{6. .... .... lo.i'O'": ::.'iO .: ~g 57, s6 9-93. 9 97:.0 ......... ~.O.i._~_,_SO ............. ~.9..., 5~ 57,.87 l o. 2~ Z o ..!% ........ 9,.9..O ............ 5.?_,_~! .......... 12.6 ~_0_~..~_,_ o.0 .... ~ 9. ~ 5.7, $ ~ 1 o. 59 .... z 0.,.~ ~ z o ...e.~ ........ 5:~...Z5 .............. !26.9.9 301~,50 4g,.3q 57.88 10, 91 17 :'-63 55 i21 9.96 9;;9'1/ 9 -. .............. }_0!.7._._~9 ..... 5.1,74 57..59 50 2 98 57.15 . ........ ~_~_~.9_,5~ 5.2.51 60.825 .................... ~_Q~.~.._,__~.O .............. 5.?.,07 .... 6!.~6 ~o 51 ~7 ~0.2~..5n 45,~5 70.41 ....... ~.Q.2.~_,.O.O ............ ~,3.5. 75.51 502~..50~ ..38.98 78.19 i'.L ....~.., 10 o 22 10. ~.! ................. 9.92 ......57.. _7._3 '._1.25.99 1 0.257 10.68 10.. 0 8 ...... 57.._2 .~_ ......... 1.25 ,. 88 10.71 10,39 ..?,~ 10.71 9 10.:', 6.~ .. 9 '10.15 9, 10.39 10.0! 10.50 60.q,. 8 ......... 126.0.9 ! o...6_9 !..lO_ ._o.a ............. !..o.....5 o ............ ........ 1.a · , o. 85 9 ,.9.~ I0.9,5:: :9',, 10 95 9:' ; .10 I0196 10.9~ 9.67 10.1.8 ?1_~.1.8 .... 126.0.5 10.97 9.61 !0.. ~+2 7P__-- 87_ .... 125,87 10.85 9. ~5 !0. 80.38 83,80 . 8'~. 02. 83.58 82.~9 81.55 79.51 71,66 68.85 ._ .... 55.15 · 5 3.2 7' se.17' 52.8q.. ' 56.31 _59.75 ._6.~. 17 .... 6.2.57 ~63,. 91 e 6 ..66- 08 .6.8. 0 S~= ._.. .. 62,60 ..62,27 61,80 .61.. 50 .62' 62...96 _6~ ...5 ! 2:9 ..68., 59 !;7_2.53 CAL 6.22 6.25 6,18 6.22 6,19 6.18 6.21 6.19 6.22 6,30 6,37 6.38 6,38. 6.38. 6.33 6.~7' 6.27 6.27 6.27 6:.27' 6..27' 6.~5 ...... '6.23 6.23 6!.26 6,26 6,21 6.2.2 6,24 t'ii 6.2~ 6,2~ "!i! 6.27 6,26 6.2~ .. 6,23 &,21 6.25 6.25 .... 6.25 DEN 2.18 2.18 2.19 2.2.0 2.20 2.1_9 2.~5 2.10 2.09,1 2'.09 2.09 2.~0 2..~3 2..~ 2:;° 16~ 2.17 2.18 2 2'.15 2.11 2;. 1! 2.11 2.. 12. 2~. i 2 2'. 11' 2-1.1 2~.11 2:. 10 2% 1 2,, 09 2.,09" 2:. 08 2..' 09 2;, i0 2' 0'9~ 2' 09 ~.09 ~.09 0.01 27-. 6.7.' q. 8.18 0 . 01 2.7' 5..6. ~ ? ..15 0.02 27, %5. ~7; 26 0.02 27,&9 ~7'.71 0.,03 30.13 ~7.19 ~. O~ 3!. S5._ 0.'. 0 ! 33, 60 ..... ~ ~ - ~ 1 0-,01 3~.55 - 0 .'00 3~, 25' ~3:. 95' - 0.00 33.. ~i ~. 92 .-0. O0 30.90 ~.:, - o-. OO 30. ~.5.: ~ 7' 00 79'. II, 3' 79.27' 79'.12 79- 81 79, 12' 78,, 63 7~', O~ 61.3~ 58.10 56.54 55,1+8 5~- 98; 57'. ~0 59. 7% 0.0_!.. .29'.19...51 ..... .~.7'..1 5. 62:,°_50 O. 00 .471' 17:" 65...6~ O. O0 q. 7.';, 9 3:! 68, 0.01 70~. 98..': O~ 01 72;, 23:: 0... 01 72. 16::' O ..O.O 71., ~6:. 67' 0 ,,QO ...... .1.~.. 67;.18 o, O. 0 ..... 31:, .~2.;: ....... ~ 8 ,.1~':. .... 65. ~ ~ 30 6: 311.65' ...~7.13:1 3_0..,~.5: .... ~.7.:. 2.2 0%00 0.00 0o00 0-00 0.01 o-0 . 0.00 ,O,O0 -0.,._00 -0.01 -O.O1 -0.01 1-3.2 65.79 6.3;35 63~02.: 03' 32: 33'.0.2 .... ~.~.:, 9.8 ~'~-'-.-~,-! ...... ~6 . 1,5 :' 31.22; ~+.7,18 31- 0~:. ~7'. ~7: 65.00~ 88: 65:'. 57' 02; 62 80,'98