Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
188-125
WELL LOG TRANSMITTAL 4905894946 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Packer Setting Record: 2Z-21 Run Date: 8/16/2019 3 135 4 October 16, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburcon.com 22-21 Digital Data in LAS format, Digital Log file RECEIVED 1 CD Rom 50-029-21877-00 OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com tUDate: Signed: vvvs-\2 RLeEivEct) 1111 1:1. % MAY 10 2U1u WELL LOG TRANSMITTAL#903079535 & G CC To: Alaska Oil and Gas Conservation Comm. May 6, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED e, Anchora Alaska 99501 5/1.w2o1G Anchorage, ivl. K.BENDER RE: LeakDetect cwith TMD3D and ACX: 2Z-21 tet Log Run Date: 1/25/2016 and 1/26/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-21 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21877-00 Leak Detect Log with TMD3D and ACX 1 Color Log-each 50-029-21877-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Stna Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ,a,za yra✓ / .."%11'_''-C kM(-X25 • • 2-G 14242. 3 5 WELL LOG TRANSMITTAL#902806404 DATA LOGGED /l0/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 6, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 scosEp RE: Multi Finger Caliper(MFC): 2Z-21 Run Date: 10/4/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-21 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21877-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAiza,./e404_, eiet.eat WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 21, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: SpectraFlow Log/Water Flow Log: 2Z-21 Run Date: 5/19/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z-21 Digital Data in DLIS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21877-00 Water Flow Log(Processed print) 1 Color Log 50-029-21877-00 %ANHE SpectraFlow Log(Field print) 1 Color Log 50-029-21877-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 1t 3 t2. Signed: 1 / !1g-125 'ASS WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 4, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey/Leak Detect Log: 2Z-21 ` CANNED Run Date: 9/30/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z-21 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21877-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 10 9 1t Signed: gilt AA. 1 Ima~Project Well History File' C( e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J ~- ~ _~ _~'Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [3 Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: .~ OVERSIZED (Non-Scannable) [] Other: , NOTES: [] Logs of various kinds [3 Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /SI ScanningPreparation __~ x 30 = ¢.~+ T~TAL PAGES BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCAN NING PREPARATION: I"~YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAy$CAL.I= OR COLOR IlVlAGES) ReScanned (individual page [special attention] scanmng completed) RESCANNEDBY: BEVERLY BRE~SHERYI~ MARIA LOWELL General Notes or Comments about this file: DATE: /SI Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 30, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2Z -21 Run Date: 11/29/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z -21 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21877 -00 Bottom Hole Pressure Survey Log L 1 Color Log 50 -029- 21877 -00 ED FEB PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood it t 6 6900 Arctic Blvd. Anchorage, Alaska 99518 O 5 - 7D Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: >: ; Signed: eg Alaska Ci -; r J".. LSS • COI'1 ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~r . », : ~ +. m ..~ .. . ._. t . , a- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRt~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15`~ and 23`d 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~` 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perty Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~'' Gi`~` MJ Loveland ~ __I SEP 0 ~ 2009 Al~~k~ ~il ~ f~~ G~na..~o 'ssion ~mah0~i ~ ~ ~.,,s `-O ~ ~- ~`~ ~ ConocoPhillips Well IntegriTy Projects Supervisor ~ • P~=~ [A ~ ". ~+ ~ ~~ F F! ~t~ ~' o. "z . ~ ~ ~ ~ ~- ~ F ~~E~ ~~ ~ ?_(lCt~~ ConocoPhillips Alaska Inc. F":'~i~~.s`~ ~~~6 e+3 ~.i,€'~~ ~~'`M'~°I.~, ~RA~~~'C6?(EF'8 ~iiPe`,P.~fe6';ay5.°2 Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor , , Corrosion inhibitod sealant date bbls ft al -- 1J-03 50029230020000 2010240 22" N/A 22" N/A 4.1 8/29/2009 1J-09 50029230060000 2010440 28" N/A 28" N/A 6.2 8/29/2009 1J-10 50029230100000 2010710 12" N/A 12" N/A 2.3 8/29/2009 1J-133 50029233150000 2061060 3' N/A 3' N/A 23.8 8/30/2009 3G-24 50103201450000 1901340 18" N/A 18" N/A 5.1 8/30/2009 1A-19 50029221110000 1901610 30" N/A 30" N/A 3.8 8/30/2009 2Z-04 50029209650000 1830860 19" N/A 19" N/A 3.5 8/30/2009 2Z-05 50029209560000 1830760 12" N/A 12" N!A 2.1 8/30/2009 2Z-07 50029209460000 1830640 9" N/A 9" N/A 8.5 8/30/2009 2Z-15 50029213620000 1851080 9" N/A 9" N/A 2.8 Z-21 50029218770000 1881250 3' N/A 3' N/A 19.6 8/30/2009 1 J 3G 1 A& 2ZPAD PH,LLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 January 29, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2Z-21 (188-125) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 2Z-21. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 109 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service Kuparuk Unit 4. Location of well at surface 8. Well number 3209' FNL, 327' FEL, Sec. 11, T11 N, R9E, UM (asp's 529379, 5966828) 2Z-21 At top of productive interval 9. Permit number / approval number 28' FNL, 2316' FEL, Sec. 11, T11N, R9E, UM 188-125/ At effective depth 10. APl number 50-029-21877 At total depth 11. Field / Pool 5194' FNL, 2394' FEL, Sec. 2, T11 N, R9E, UM (asp's 527295, 5970113) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7797 feet Plugs (measured) true vertical 6409 feet Effective depth: measured 7516 feet Junk (measured) true vertical 6137 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 199 sx AS ,~ 115' 115' SUR. CASING 4344' 9-5/8" 1000 sx AS III, 450 sx Class G 4453' 3491' PROD. CASING 7669' 7" 200 sx Class G 7778' 6391' Perforation depth: measured 7261' - 7332', 7501' - 7520', 7466' - 7484' ~.~. ~ true vertical 5891' - 5959', 6122' - 6140', 6089' - 6106' ,:!~i: '.! i:i~ .~ i · Tubing (size, grade, and measured depth) 4", 11#, J-55 Tbg @ 4000' MD; 3-1/2", 9.3#, J-55 Tbg @ 7393' MD. ;:'.i~it~i~ i = Packers & SSSV (type & measured depth) TIW 'SS-BB' @ 7366' MD; AVA 'RHS-XL' @ 7165' MD; AVA SIDEGUARD (LOCKED OUT) (LOCK OUT BRAIN FOR WRDP 10/13/97) @ 1803' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 133 857 273 - 210 Subsequent to operation 152 1210 372 - 212 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Servi( 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~.../~//~~ Title Wells Team Leader Date ~'/~]~//~su~p Michael Moone~/ .. Prepared b~/ Sharon -Drake 263-4612 Form 10-404 Rev 06/15/88 · O[ I61NAL SUBMIT IN DUPLICATE Date Comment 2Z-21 Event History 12/28/01 PERFORATE 7466-84' (18' A4 SAND) WITH 2-1/8", 6 SPF, ENERJET STRIP GUN. Page 1 of I 1/21/2002 MEMORANDUM TO: Julie HueSser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 1, 2000 THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 2Z Pad Friday, December 1, 2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2Z Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with two failures observed. The surface safety .valve on wells 2Z-7 and' 2Z-10 had slow leaks when pressure tested. These two valves will be serviced and retested by the operator. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary: I witnessed the semi annual SVS testing at 2Z Pad in the Kuparuk River Field. KRU 2Z Pad, 12 wells, 24 components, 2 failures 8.3% failure rate Attachment: SVS KRU 2Z Pad 12-1-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2Z Pad 12-1-00 CS.doc Operator: Phillips Operator Rep: Emie Barndt AOGCC Rep: Chuck Scheve AlaSka Oil and Gas Conservation Commission Safety Valve SyStem Test Report Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupauk / KRU / 2Z Pad Separator psi: LPS 100 HPS 12/1/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed aAS or CYCLE 2Z-01 1830730 100 70 70 P P OIL 2Z-02 1830800 2Z-03 18308501 · 2Z-04 1830860 2Z-05 1830760 100 70 70 P P OIL 2Z-06 1830770 3700 2000 2000 P P WAG . 2Z-07 18306401 100 70 65 P 4 OIL 2Z-08 1830380 2Z-09 ·1851360 2Z-10 · 1851370 100 70 70 P 4 OIL 2Z-11 1851380 2Z-12A 1951480 100 70 50 P P 0IL 2Z-13 1851060 2Z- 14 1851070 2Z-15 1851080 3700 2000 1700 P P WAG 2Z-16 1851090 2Z-18 1881330 100 70 65 P P OIL 2Z-19 1881300 100 70 65 P P OIL 2Z-20 ' 1881240 100 70 100 P P OIL 2Z-21 1881250 1001 70 70 P P OIL 2Z-22 1941470 2Z-23 1950100 2Z-29 1881290 100 70 70 P P OIL 2Z-WS1 1851580 · Wells: 12 Components: 24 Failures: 2 Failure Rate: 8.3% E390 Day Remarks: Surface Safety Valves On wells 7 & 10 had slow leaks when pressure tested. They ar serviced and retested by the operator. 1 ?/a/oo Paee 1 of 1 SVS KRU 2Z Pad 12-1-00 CS.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 P M C:LORI~IFILM. DOC E E L E W A T E R IA L U N D ER TH IS M A R K ER STATE OF ALASKA AL, ...,.~, OIL AND GAS CONSERVATION COMMIo,.,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address 5. Type of Well: P. O. Box 100360, Anchorage, AK 99510 Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2070' FSL, 328' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 0' FNL, 2360' FEL, Sec. 11, T11N, R9E, UM At effective depth 48' FSL, 2372' FEL, Sec. 2, T11N, R9E, UM At total depth 69' FSL, 2388' FEL, Sec. 2, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7797 6423 feet feet 6. Datum elevation (DF or KB) RKB 109 Effective depth: measured 7 6 9 6 true vertical 6326 feet feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-21 feet 9. Permit number/approval number 88-125 10. APl number 5o-029-21877-00 1 1. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) None ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4418' 9-5/8" 7760' 7" Cemented Measured depth True vertical depth 199 Sx AS III I 15' 1000 Sx AS III & 4453' 450 Sx Class G w/30 Sx AS I top job 200 Sx Class G 77 7 8' measured 7261 '-7331 ',7454'-7460',7466'-7488',7501 '-7520' true vertical 5891 '-5959',6077'-6083',6089'-6110',6122'-6140' Tubing (size, grade, and measured depth) 4.0", 11#/ft., J-55 @ 4004', 3.5", 9.3#/ft., J-55 @ 4004'-7384' Packers and SSSV (type and measured depth) 115' 3504' Alaska Oil ,~,. r,~ u,:~s 00115. C0mraJss ~1 /mchorage Pkrs: AVA RHS-XL @ 7165' & TIW SS-BB @ 7366'; SSSV: AVA Sideguard w/brain @ 1797' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 10/8/97. Intervals treated (measured) 7454'-7460',7466'-7488',7501 '-7520' Treatment description including volumes used and final pressure Pum 268.5 Mlbs of 16/20 and 12/18 ceramic proppant into formation, fp was 4900 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 140 86 195 1250 190 Subsequent to operation 240 2 0 8 1168 1262 207 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations X Oil X Gas 17. I he~,c~rtify that the foregoing is true and correct to the best of my knowledge. Signed(/V/.~.~ ~--~r- Title Wells Superintendent Suspended Service Date IN ARCO Alaska, Inc. KUPARUK RIVER UNIT '~' WELL SERVICE REPORT ~ ~ K1 (2Z-21 (W4-6)) WELL JOB SCOPE JOB NUMBER 2Z-21 FRAC, FRAC SUPPORT 1003971846.4 DATE DAILY WORK UNIT NUMBER 10/08/97 "A" SAND REFRAC DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 2 , (~) Yes O NoI (~) Yes O No DS-GALLEGOS CHANEY FIELD AFC4f CC~ DAILY COST ACCUM COST Signed ESTIMATE KD1687 230DS28ZL $160,833 $180,438 Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann ~ Initial Outer Ann ] Final Outer ArVn 396 PSI 1000 PSI 300 PSI 500 PSII 146° PSI ~"450 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 268509 LBS OF PROP IN THE FORM W/#14 PPA OF #12/18 @ THE PERF'S. I L FREEZE PROTECTED TBG DOWN TO 2500' W/29 BBLS OF DIESEL. MAXIMUM PRESSURE 6100 PSI AND F.G. (.87) TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, AND APC VAC TRUCK. HELD SAFETY MEETING (18 ON LOCATION). 09:30 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET THE TREESAVER AND PT'D HIGH PRESSURE LINES TO 7400 PSI. ~ 2.; 1 :::. PUMP BREAKDOWN W/50# DELAYED XL ~..~ ~, ~' 3~ii ~ ~ '~ 5 :':~PM. VOLUME PUMPED 422 BBLS. USED 5577 LBS~...':~.' 11:05 12:00 14:20 15:30 16:30 #16/20 PROP. MAXIMUM PRESSURE 6100 P~I AND ENDING PRESSURE 3700 PSI. STEPPED DOWN THE RATE A'i END OF STAGE. S/D AND OBTAINED ISIP OF 2428 PSI W/F.G. @ (.84). PULSED FOR CLOSURE TIME AND MONITORED WHTP. DETERMINED CLOSURE TIME +-10 MINS @ 2027 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 196 BBLS. MAXIMUM PRESSURE 4500 PSI AND ENDING PRESSURE 3500 PSI. S/D AND OBTAINED ISIP OF 2607 PSI W/F.G. @ (.87). MONITORED WHTP FOR CLOSURE. DETERMINED CLOSURE TIME OF 12 MINS @ 2250 PSI. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 1966 BBLS. PUMPED 269237 LBS OF PROP (19461 LBS OF #16/20 & 249776 LBS OF #12/18). INJECTED 268509 LBS OF PROP IN THE FORMATION W/#14 PPA OF #12/18 @ THE PERF'S. LEFT 727 LBS OF PROP IN THE WELLBORE. EST TOP OF FILL @ 7400'. FREEZE PROTECTED TBG W/29 BBLS OF DIESEL DOWN TO 2500'. COMPLETED THRU FLUSH. MAXIMUM PRESSURE 4900 PSI AND ENDING PRESSURE WAS 4200 PSI. S/D AND MONITORED WHTP FOR 5 MINS. STARTED R/D. DEPRESSURED THE 7" CSG PRESSURE TO 500 PSI AND R/D LRS HOT OIL UNIT. REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $91o.oo APc '$6,300.00 $6,300.00 DIESEL $400.00 $400.00 DOWELL $152,033.00 $152,033.00 HALLIBURTON $0.00 $10,905.00 LITTLE RED $2,100.00 $9,890.00 PETREDAT $0.00 $0.00 TOTAL FIELD ESTIMATE $1 60,833.00 $1 80,438.00 ALASKA OIL AND GAS CONSERVATION COMMI~,51ON REPORT OF SUNDRY WELL OPERATIONS/l/.. ., v/.//. i. Operations Performed: Operation Shutdown Pull tubing ,,, Alter casing Stimulate X Plugging Perforate _ Repair well Other __ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2070' FSL, 328' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 0' FNL, 2360' FEL, Sec. 11, T11N, R9E, UM At effective depth 48' FSL, 2372' FEL, Sec. 2, T11N, R9E, UM At total depth 69' FSL, 2388' FEL, Sec. 2, T11N, R9E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 12. Present well condition summary Total Depth: measured 7797' true vertical 6423' Effective depth: (approx.) (approx.) (approx.) feet feet RKB 109' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-21 9. Permit number/approval number 88-125 10. APl number 50-029-21877 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) measured 7696' feet Junk (measured) true vertical 6326' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 1 9 9 SX AS II 1 1 5 1 1 5 Surface 441 8' 9 5/8" 1 000 sx AS III & 4453' 3504' Intermediate 4 5 0 SX CLASS G-T©P JOB w/30 sx ASI Production 7 7 6 0' 7" 2 0 0 sx Class G 7 7 7 8' 6 4 0 5' Liner RE( EIVE Perforation depth' measured 7261'-7332', 7501'-7520' true vertical 5891'-5959', 6122'-6140' Tubing (size, grade, and measured depth) 4"/3 1/2", J-55, tbg w/tail @ 73~S~(aOjj & Gas Cons. Packers and SSSV (type and measured depth) ;Anchorage AVA 'RHS-XL' PKR @ 7165', TIW 'SS-BB' PKR @ 7366', AVA 'Sideguard' SSSV @ 1828' 13. Stimulation or cement squeeze summary 'A' SAND FRACTURE STIMULATION Intervals treated (measured) 7501' - 7520' Treatment description including volumes used and final pressure 14. Pressure Prior to well operation Subsequent to operation '" EE ATTACHED SUMMARY Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 610 26-8 1543 722 406 1831 Tubing 183 197 i5. Attachments 1G. Status of Well classification as' Copies of Logs and Surveys run__ Water Injector __ Daily Report of Well Operations X Oil X,.. Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Si.~)ned Title f~ 3 ' Date ]) Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL: ~-'Z.I TIJO ~ PERFS: c,, :~.' ~z..Kz~ MO ~ PERFS: '7,5'oi ' ~..~,~ HOLE ANGLE~.PERFS: /~"4 RC~IJFIL UOLUME RATE PRESSURE PROP. PROP. I EFF. PRO: zo; 4- 'T~G vo~. EFF. SLURRY: EFF. PROP: UOLUME ../_,~//32 i /___ /___ IslP: ~,,(t;)e) / PE.Ir F"IC: .~'7~. / LEAK OFF: S MIN. LOS INTERURL: FLUIO TEMP: IrLUIO UlSC' ~-~ STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~,-~iON REPORT OF SUNDRY WELL OPERATIONS 1 Operation Performed: Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator 5. Type of Well: Development X ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 2069' FSL, 327' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 27' FNL, 2317' FEL, Sec. 11, T11N, R9E, UM At effective depth 63' FSL, 2384' FEL, Sec. 2, T11N, R9E, UM At total depth 83' FSL, 1147' FEL, Sec. 2, T11N, R9E~ UM 12. Present well condition summary Total Depth: measured 7797' true vertical 640 9' feet Plugs (measured) feet Plugging Perforate _ Other 6. Datum elevation (DF or KB) I O9' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number. 2Z-21 9. Permit number/approval number 88-125 lO. APl number 50-029-21877 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 6 9 6' true vertical 631 1' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4418' 9-5/8" 7760' 7" measured 7261 '-7332', true vertical 5891 '-5959', Cemented Measured depth 199 Sx AS II 1 15' 1000 Sx AS III & 4453' 450 Sx Class G-Top Job w/30 sx AS I True vertical depth 115' 3490' 200 Sx Class G 7778' 63 91' 7466'-7488', 6088'-6110', 7501 '-752O' 6122'-6140' 7454'-7460', 6077'-6083', Tubing (size, grade, and measured depth) 4" & 3.5", 9.3#, J55 tbg w/ tail @ 7392' Packers and SSSV (type and measured depth) AVA 'RHS-XL' pkr @ 7165'~ TIW 'SS-BB' pkr @ 7366' & AVA Sideguard SSSV @ 1803' 13. Stimulation or cement squeeze summary Fracture Stimulation Intervals treated (measured) Kuparuk 'A' Sands Treatment description including volumes used and final pressure 1256 bbls GW/18 bbls Diesel/798 Gal Additives/139~178# of proppanl/FTP=6800 psi 14. Re~)resentative Daily Average Prqgluction or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 65 29 0 1325 168 Subsequent to operation 532 356 0 500 211 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector __ Daily Report of Well Operations X Oil X... Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Service Date SUBMIT IN DUPLICATE ARCO Alaska, In¢ · Subsidiary of Atlantic Richfield Company ;ONTRACTOR HnLI4Bul~'OtJ- CA~.~. WELL SERVICE REPORT F,ELO- D,STR,C~- ST^TE /DA~S ~*~E OPERATION AT REPORT TIME REMARKS o~S 68u.. 1022. Pu~4P ~¢ .~Z 5t.K. Wl'E. 2,6 ~ 5088.5 ~DFSi 1SiP 22430 A,/G ~ Z5 enu,. 151P 2'~0 I-'J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report °F OFI miles knots ISlgn°d ~ ~ ? STATE OF ALASKA AL, .~KA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL r~ GAS r'--] SUSPENDED [~ ABANDONED r=-] SERVICE ~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-125 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21877 4 Location of welt at surface 9 Unit or Lease Name 2069' FSL, 327' FEL, SEC 11, T11 N, R9E UM ~ - -~'~ATE i~' ~ LC~.L ;i ;..~ .. KUPARUK RIVER UNIT At Top Producing ,ntewal ~L~.12.?_ ~ ~~ ~,~.~:~:~ ~ : 10 Well Num~r 28' FNL, 2316', FEL, SEC 11, T11N, ROE UM ~ ~;~t~.L: 1 AtTotaIDepth ~ .~~_~ ' ;~ J~ ~ ~ 11 Fielda~Pool 83' FSL, 2399 FEL, SEC 2, T11N, R9E UM ......... *'~ ..... ~ ~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 L~se Designatio~ and Sedal ~. KUPARUK RIVER OIL P~L RKB 109' ADL:~AKL: 2674 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Dep~, if offshore J16 No. of Completions NOV 4 1988 NOV 9 1988 ~ NA feet MSLI 1 17TotalDep~(MD+~D) 18 Plug Back Depth (MD+TVD) 19 DirectionalSu~ey 120 Depth where SSSV set 121 Thickness of ~r~frost 7797' MD & 6409' TVD 7696' MD & 6311' TVD YES ~ ~ ~J 1803' f~t MD~ 1400' (approximate) 22 Ty~ El~tric or Other Logs Run DIL,SFL, GR,CAL,SP,FDC,CNL, CBL,GYRO 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~ ~LE SIZE CEME~ING RECORD AMOUNT PULLED 16" 62.5~ H-40 SURF 115' ' 24" 199 SX AS III 9 5/8" 36~ J-55 SURF 4453' 12-1/4" 1000 SX AS III & 450 SX C~SS G 7" 26~ J-55 SURF 7778' 8-1/2" 200 SX C~SS G 24 Perorations open to Production (MD+~D of Top a~ BoEom and 25 TUBING RECORD inte~al, size and number) SIZE :DEPTH SET (MD) ~ACKER SET 7261'-7332' MD, 5" W/12 SPF 5891' - 5959' TVD 4"/3-1/2" 7392' 7366' 7501' - 7520' MD, 5" W/8 SPF 6122' - 6140' TVD 26 ACID, FRACTURE, CEME~ SQUEE~, ETC DEPTH I~ERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7214'-7216' 75 SX CLASS G 27 PRODUCTION TEST , Date First Production ]Method of Operation (Flowing, gas li~ etc.) I Date of Test Hours Test~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL ~TIO I TEST PERIOD ~ r FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAV~Y-API (corr) Press. 24-HOUR ~T[ ~ 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent di~ and presence of oil, gas or water. Submit core chips. ,. , ~m 10-407 Submit ~'~uplicate ~. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 7260' 5890' NA · · BOTTOM KUPARUK C 7331' 5958' TOP KUPARUK A 7446' 6069' BOTTOM KUPARUK A 7579' 6197' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~ Title ~'~-~'~}~I ~-z'~'.5/""'"'" Date ~/~'/,G ~.~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL; 2/11/90 2/12/90 2/26/90 2Z-21 Make 3 attempts at perf runs w/o success. Secure well. RU Otis S/L. Tst lubr to 3000 psi. RIH w/impression block, tag up @ 10,193' RKB, POOH. RIH w/1-3/8" JDC, tag up @ 10,193' & wrk dn to 10,210', POOH; no fsh. Secure well. TOF 44' below btm perf. RI E-line. Tst lubr to 3000 psi; OK. RIH w/2-1/8" JRC DynaStrip; unable to get past isolation siv @ 7351'. POOH, straighten strip. RIH, perf "A" sands fr/ 7466'-7488' & 7454' - 7460' in 4 runs @ 8 SPF, 60° phasing. Secure well. Signed: wELL s/z6/s9 ' e-1"$. C:l.x:c clu hot d ,, . ,- cLrc --~0' of 7 cs~ Rt~ C~' in top [~ C~. dlesel 9-5/B" ~ 7" ann. ~ - ~0 bbls A~ct~C A~ctLC ~ak ~/175 sx AS I a~ ~ ~L~aska ~i~ & ~as Cons. Commission ~nchom~ December 15, 1988 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 CONFIDENTIAL Re: Boss Gyroscopic Survey Job No AK--BO~80137 Well:~,~' ..... 2Z-21j ~3 Fiel .~r~-Kup&~'~ Survey Date: December 4, 1988 Operator: D. Harger Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. District Manager Enclosure NI. Sperry.$un/NL Industries, Inc. RO. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907)522-1737 RECEIVED ~UN ! 6 ]989 Alaska 0ii & Gas Cons. Commission Anchorage ARCO ALASKA, INC. i<-~I:]F-'I~t~I:.I'~(2Z-21 _ :-I~t:--~(:i- COMPUTATION DATE ................ '- ................. 6'; ALASKA A~ka Oil & ~as Cons. Commission VERT I CAL SECT I ONCALCULATED ....... Ai_~.~')NG CLOSURE ........................... -~ C'~V ~L~ ' ANCHORAGE ALASKA DATE OF SURVEY DECEMBER 4, 1988 .B. OL3:~. GYR_O~_C,-_g!P ! Q_~.L..LR. VEY..__ .._lOB NUMBER AK-BO-80137 KELLY BUSHINA ELEV. = 108.00 FT. OPE~.A_T~R-__H.ARGER ........... TRUE .......... 6_U.B:~E:__A_ _ MEASURED VERT I CAL VERT I CAL DEPTH DEPTH DEPTH COURSE INCLINATION DEG MIN COURSE ....... DOG-..L_EG .............................. T!:!TA.L. ................ D I RECT I ON SEVER I TV RECTANGULAR COORD I NATES DEGREES DEG/100 NORTH/SOUTH EAST/WEST VERT I C ~ ~ SECT ~ .) 0 1 1 48 4 21 ' ....... 6 ............ O:-q6 .... -:i'6~TOO o 0 N O. 0 E O. 00 0. O0 O. O0 O. O0 · . ~4 W 0 67 100 .q9 ~79 -8.01 0 48 N 49.50 W 0.81 0.46 N 0.~ . 200 ..... 199, '~9 91,_..99 0 38 N__ 7Q,_._5. C~..W ........ Q.,_31 ............. 1__, IO_N .......... _1.,(_-_,9_ W 1,79 300 299.98 191.98 0 43 N 73.89 W 0.10 1.47 N '2.74 W 2.70 400 3'P9.97 2'B1.97 5:~ N 69.10 W 0.26 1.'PS N 4.15 W 3.86 .~.o0 ........... 49?:95 ....... 3~.__9~__ 5 N 64...~:o w .c!,._l_.4 ........... '.2 :_6 6_ .. N ............... 5._'6_1__w . .5.,~__ 600 599..92 491.92 N 47.50 W 0.83 4.13 N 7.84 W 7.67 700 699.77 ,591.77 N 33.60 W 2.63 8.36 N 11.10 W 12.5'8 800_. . . ._779:21 ...........69_1.:..2_1 .............. 7 ..~6 ...... _1~._:3~,...1.0 .W. .......... 3:'_26 ........ 17,07 .N.__. _ 16,.82_.W .......... 'PO0 6:97.72 789.72 12 3 N 34.10 ,W 4.44 31.26 N 26.29 W 40.46 1000 9'P5.06 887.06 14 1 '-' - ,_-, N :-~2.19 W 2.30 50.36 N 38.73 W 63.25 ........... · - - - · ................................................ ~::__ 2._ 1100 1090 78 ~.:~.78 19 13 N 30 69 W 4.94 75.00 N _ ~.7o .W 92,09 1200 1184.09 1076.09 22 52 N 29.50 W 3.67 106.08 N 71.71 W 127.98 1300 1274.75 1166.75 27 0 N 28.19 W 4.18 143.02 N ,~2.02 W 170. A6 1 50 ......... .......... .......... .s_'9 .:=iii,; ......... N._.2_7,.L30 W_ .......... .7,P9 .......... 1.6_4,3.2. N ........... 10.'.3.,.2! .IN .......... l~4 ',~_ 1400 1361.23 1253.23 32 19 N 27.30 W ~.60 187.49 N 115.17 W 220. 1500 1444.69 1336.69 34 28 N 27.89 W °.--~'. 18 236.26 N 140.68 W 274.8.9 1600__ 1526.62 __1418.62 35 29 __~_.~.3~____~ .... l_,_Q5 2~..~ _N ..... d67~_7~LW___ ~Ot__. 1700 1606.95 1498.95 37 35 N 28.30 W 2.10 1800 1685.13 1577.13 39 32 N 28. 0 W 1.~6 190Q ....... !.76___1._.98 ..... 1_6_5.3.9.8. ........... _4...0..0 ....... N_ 2~,....1:~_W ....... 0,._4. ? _. 2000 1837.82 172~. 82 41 20 N 28.89 W 1.41 2100 1.911.47 1803.47 43 46 N 29.60 W 2.48 2200 1982.79 1874.79 45 13 N 29.89 W 1.48 2300 2051.56 2400 2119.21 25OO 2188.34 2600 225~.02 2700 2329.43 1943.56 47 51 N 31. 0 W 2.75 2011.21 46 59 N 30.19 W 1.05 2080.34 45 339.20 N 3.94.16 N _.45Q~_60 N .. 2151.02 44 2221.43 45 _. 27~0 ....... ~:63:Q6 ........ ~25~: 06 507.84 N 286.69 W 566.83 N W 627, .68_N W 690.24 N W 753.62 N 32 ...... N_ ~9..! O_ W ........ 1 , 65 ....... 8 ! 6.40. _N ...... 464.54 IN. :30 N 28. 0 W 1.29 878..~3 N 498.~:~'~ W 57 N 29.50- W 1.80 940.76 N 532.51 W .... 29 ...... N .. 32_. :3Q, IN ............... 8,_~ E: ..... ':772,_.48 _N ........5~.1,5~...l~ 196.00 W 391.48 225.40 W 453.66 582.52 319.73 650.04 354.51 72~,.~.~.__ 391.31 792.62 428.79 W 866.22 ..... ?~.~_ 1008.~9 107W.86 ARCO ALASKA, INC. 2Z-21 KUPARUK ALASKA ANCHORAGE ALASKA DECEMBER 6, 1988 VERTICAL SECTION CALCULATED ALONG CLOSURE. DATE OF SURVEY DECEMBER 4, 1988 B_O6$_~YR_.C!SCQ~. I C dOB NUMBER AK-BO-S0137 KELLY BUSHING ELEV. = 108.00 FT. _!:!F'..E_R_.A.._T. QR=HA.R. CLE_~ ................. T_RUE __SUB.:._-RE_.A_ .......... COURSE ......... !_'.;OURSE DO!.~:L_EG MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 2800 2394. 2900 2457. 3000 2519. 3100 3200 3300 .................. TOTAL.._ RECTANGULAR COORD I NATES NORTH/SOUTH EAST/WEST ~4-" 2286,.$4 51 34 N 32.89 W 4"26 lO04:'Q ............... i-'-::'-.-.-, · 9 N ._,7~.. a-:~. W 12 2349.12 51 23 N 32.60 W 0.30 lC)70.80 N 614.6,4 W 89 __ 241.1_. ~? ........... 5Q .... _,5._1 .... N.._32.1_~_ W ................. 0 :..~2 ..... I._I ~6_, ~2._N ........... ~..6_,.>~_W ..... '-'="~'" 29 2475 29 50 27 N 31 10 W 0 94 1':,o'-~ :_;:5 N 6~-.~/-.. ~.-.,F: W 2648.04 2540.04 48 49 N 30. SO W 1 . 66 126,7.6:-.? N 73/_-,. 1 '2 W 2.714,_ VERTIC~' SECT1 ) 1155.42 1233.66 1388.83 1465.00 95 2606.95 47 10 N 30 50 W 1.66 1.'_":31,61 N 77_4._, 00 W .......... J.=_,.~ '-'"' .................................................... : ................................................... ~j. ~.._. 3400 3500 3600 .... 3700 49 52 3800 49 38 3~00 ~_. 2~ 4000 3176.20 3068.20 48 18 4100 3243.36 3135.36 47 18 2783.15 2675.15 46 49 N 30.60 W 2851.35 2743.35 47 10 N ~1.19 W 2~-17,.92 ...... 2809,p2 ..... ~Q .... ~2 ....: .... N._33,.~Q..H 2980.~0 2872.90 3045.49 2~37.49 311~.__40 3002~0 0.35 O. 56 .......... 3! ~'~ '---' N 32.80 W 0.99 N 32.60 W 0.28 N 32.50 W 1.09 N 32.39 W 1.01 ...... N._~2,._~Q_ W .......... l ,Q 1 ..... 4300 3381.43 3273.43 4400 3452.05 3344.05 ..... ~QQ__ 3524~20 34Li_~.L~fO 4600 3597.49 3489.49 4700 3671.08 3563.08 . ~800 ..... 37~4, 91 36~6, 91 4900 3819.17 ~711.17 5000 3894.06 3786.06 510£) 396,9.17 3861.17 5200 4044.27 3936.27 5300 4120.81 4012.81 5400 . 4199.._77 ......... 4091 ,.77___ 5500 4280.77 4172.77 5600 4362.82 4254.82 45 28 N 32.50 44 39 N 32.19 .... ~ 2 ~ .... N 3.Z._~_O 42 46. N 32.60 42 28 N 33. 0 4'.2. _.21 ....... N__~3..30_ 41 44 N 33. 0 W O. 81 W O. 85 W ___L._Z1. W O. 20 W 0.40 W ......... Q W O. 64 41 15 N 33.6.'.) W 0.67 41 15 N 34.69 W 0.18 38 49 N 34.3~ W 2.45 3~: ... 51 ..... N_34._ 69~_ W ...........1.97 34 == '3 30 . ~,~, N 3-~. W 2 10 34 48 N 33.60 W 0.21 57(!0 ........... .4. ~.4~_. 1394.59 N 811.i7 W 1612.38 1457.35 N 848.73 W 1685.50 ..... 1521,02_ N ........ :~St-?.,. 1.1__ W 1535.42 N 931.18 W 1337.81 1649.66 N 972.42 W 1914.15 1_7.1 ~ 7__~._ ~ _~1~.i~_ W__ ~ 990.21__. 1777.29 N 105:3.81 W 2065.51 1839.81 N 1093.56 W 2139. A0 ! ?O 1 . 22 ..N ...... 11L!--~ 67_ N ..... 1961.87 N 1171.24 W 2284.' . 2021.67 N 1209. 12 W .... 2QSQ.._l '2_' .N___ _12_4 6.~2 l_ N ._ 2137.44 N 2194.36 N .......... 22~0..82__N .... 2306.89 N 2362.24 N 24~1_N___. 2471.26 N 2524.23 N 257~4, 'Z~__N _ 2623.34 N 2671.04 N 1282.87 W 1319.55 W 13~..43_W ..... 1393.05 W 142~.47 W 1.~6~.4~_N 1503.98 W 1540.46 W .1575,.25_W_ 1608.04 W 1639.55 W ............ · -"- . ,_4 2717, 05_N ....... 1670, 2355.07 242~_2~__ 2492.33 2560.03 26e4.43 2760.67 2826.66 2892.63 2956.8~ ....... 3Q18.17~ 3076.76 3133.92 ARCO ALASKA, INC. 2Z.-.~! ..... I<UPARLII<: ALASKA ........... _,S. PE6~RY=~I, JN _~tF.J.L~.UR~[Y.I~G_ C_QMP. A~Y ............ 'ANOHORAOE ALASKA vERT'I'~AL ~i~I~TION CALCULATED ALONG CLOSURE DECEMBER 6, 1988 DATE OF SURVEY DECEMBER 4, 1988 dOB NUMBER AK-BO-80137 KELLY BUSHING ELEV. = 108.00 FT. Q.P._ER_A.TOR-HARGE~ .................... TRUE ..... SUI~_.-_$[. 8 ..... C..O.U.E.'SE. MEASURED VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEPTH DEG M I N .... 5~6~ ......453'1-]'-~ ........ 4423,17 5900 4617.65 4509.65 6000 6100 COURSE DIRECTION DEGREES EJPG.'rL_.EG ......................... TqTAg.._.. SEVER I TY RECTANGULAR COORD I NATES DEG/100 NORTH/SOLITH ERST/WEST 4705.13 4793.16 31 15 N 34.69 W ........... ~'"~'~; ........ ~2760.61 N '~-g-.~9.66 W 28 59 N 34.50 W 2.26 ,._,.~o~A1 .91 N 1-~°A,~__.. 15 W VERTICr', SEC:TI~ 3241.74 3291.86 4.5~7..!3 ............ 28 ..... 58 ...... N_ .~ .4_... 80 W ............ 0,15 .......... 284.1_. 77._N ...... 17~5.,.7o_~ ......... ~3__49_, 27_.. 4685 16 27 40 N 34.':" - ~.0 W 1. :::2 2880.83 N I ~ ~-' · 7~.-.60 W 3387.66 6200 4881.78 4773.78 27 31 6300 4971.47 4863.47 24 56 6400 5062.80 4954.80 23 4 6450 5109.29 5001.29 20 8 6500 ...... 5156,.~2_, ...... 5048,.~2 .......... 17 .... 6600 5252.78 5144.78 14 6700 5349.71 5241.71 14 1 6800 54~6.55 ~ooo ~= ......................... ~~.~:~ 14 51 6~00 5543.13 5435.13 15 12 N 34.80 W O. 27 2918.99 N 1808.'~'-oU W 34:33.95 N 35. 0 W 2 59 .~o~ 25 N 1834.16 W 3478 10 -- ~. . __ ~ .t..1~1 · ............................. . 2.06 2988.99 N 1856.88 W 6.01 3004.62 N 1866.62 W 5, ~6 ...... ~P~¢,~7. N ..... 1~74...9~ _W .......... 3.~.°9 3041. 13 N 1890.25 W 0 49 '-'C . . oJ60 73 N 1905.04 W 1.86__ 3081~0 .~ 1919~_W 0,48 3103,39 N 1932,64 W N 32.80 W N 31. 0 W N 31.69 W N 36.39 W N 37.69 W hJ__~ 1. . ,_. _.(!__. N_ __ N 32.19 W 7000 5639. 70~0 ....... 5~87, 7100 5735.53 7200 5831.81 7300 5928.15 7400 6024.57 7500 6121.08 7600 ....... 6217.70 .. 7650 6266,10 7700 ~314.54 7797 6408.52 39 5531.39 16 13 N 34.60 W 1.20 3125.98 N 1947.56 W 5627.53 15 46 N 35.89 W 0.36 3148.38 N 1963.58 W 5723.81 15 34 N 36.19 W 0.22 3170.2'2 N 197¢.48 W 5820.15 15 30 _~ ~.,~._J~_ ...... ~5 ~l~t.~TZ._N ...... t~,_~;~_W ..... 5916.57 15 15 N 37.10 W 0.27 3212.99 N 2011.32 W 6013.08 15 7 N 37.10 W 0.14 3233.88 N 2027.13 W .325~0 N ...... ~0~2,70_W 3264.46 N 2050.20 W 3274.48 N 2057.50 W __61 pg... 7.0 ...... .14 _ .4.3_ ...... N .3._7,.30 _W ..........0._ 39 . 6158.10 14 21 N 36.10 W 0.97 6206.54 14 21 N 36.10 W 0.00 6300.52 _t 4 21 _.N__~:_6_. ! ~%__W ........ .o._._PC.! ....... ._3.2_93..~gP_.N ...... --..;_'07.L_. 6Z_. W. 3518.76 3537.18 35~,~2~._. 3580.66 3605.13 36~~__ 3655.93 3683.01 ......... 3710.~ 3737.44 ~Z,.6._._~.~.1~_ 3790.60 3816.70 3854.87 3867.23 HORIZONTAL DISPLACEMENT = 3e91.22 FEET AT NORTH 32 DEG. 10 MIN. WEST AT MD = 7797 THE. F:ALcuLATIoN pRcicEDUREs ARE BA~;EO"ON"T'HE-US~ OF THREE ~II'MENSIONAL ~'A-Di-US OF CURVATURE METHOD. ARCO ALASKA, 2.Z_-~! KUPARUK ALASKA INC. ~8 E~ E~Y_-.~LINo_WEL, L_tUE~ VE ¥~J~_~..P M 8 ANY_. ANCHORAGE ALASKA .C~MP I_~T~I ON....Di~.TE ............ DECEMBER 6, 1788 DATE OF SURVEY DECEMBER 4, 1988 dOB NUMBER AK-BO-80137 KELLY BUSHING ELEV. = ....... ...O_PE[fJ~T£!B_-.HAROER .... 108.00 FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH ............ TRUE-. --SUB-SEA ................... ~0-~- ................................................................. MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH. .............. DEPT.H .............. ..... ..... .E.AS_'T./.W_E'_~T ....... _D .I'FFERE,N_.E;E_ ..... ¢_.'OE:_,RE!:LT I,ON .......... 0 0,00 -108,00 0,00 0,00 c),O0 1000 995,06 887,06 50,36 N 38,73 W 4,94 4,94 2000 1837,82 1729,82 507,84 N 286,69 W 1-'~ d~,18 157,24 3000 2519,89 2411,89 1136,52 N 656,35 W 480.11 .317.93 4o(! . . ~._,~.81 W__ 823.80 343.~? 5000 38~4.06 3786.06 2362.24 N 142~.47 W 1105.~4 282.13 6000 4705,13 45~7,13 2841,77 N 1755,70 W 12~4,87 188,~4 7000 ....... 77?7 6408,52 6300,52 3273,?0 N 2071,67 W 1388.48 27,87 THE CALCULATION PROCEDURES ARE' BASED ON THE USE OF THR_EE D!M_EN_8_I_O~AL_BA~IU~LI2E_£~VATLIBE_~IF. JHOD. __ R. ECE £D-- JuN i ,~aska Oii& Gas Cons. Commission Anchorage ARCO ALAoKA, 2.Z.-Z.';__ KUPARUK ALASKA INC. ............ ~,. PEBB Y._~IU~I_BEIJ,_~.,.B_VE Y N .......... O.H..PANY ANCHORAGE ALASKA ___C~MUP.LmT ,A T il ..ON_-DA T_E/ .................. DECEMBER 6,.~'~oo. ~,,_~ DATE OF SURVEY DECEMBER 4, 1988 dOB NUMBER AK-BO-80137 KELLY BUSHING ELEV. = 108.00 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERT I CAL VERT I CAL DEp. T.H.. ................. DEF~TH ............ DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH E.AS_T__/_W.E_~T_ .... P_I_ ._F F E_.R_'E N {2: E_ ...... ]-'_~ o.R' P E.C._: T _I .C!.N. ........... ' 0 108 308 308.00 200. 408 408. O0 300. 508 508. O0 400. 608 608. O0 500. 708 ....... 708,...00 .......... .6.09: 808 808. O0 700. 910 908.00 800. o. oo - lO8. oo o. oo o. oo o. oo 108:00 ............ _O...OQ ................... _0. :.~3. N.. ............. 9._ (:,2... w ................. 0,0! ............. 0,01. ...................... · ~08.00 100,00 1,13 N 1,69 W 0.01 0,01 00 1.50 N 2.84 W 0.02 0.01 O0 2.00 N 4.28 W 0.03 0.01. 00 2.72 N 5.95 W 0.05 0.02 O0 4.34 N 8.04 W 0,09 0.04 O0 ............ 8 92 N 11 47 W ...... 0 ':' . .......... ~. ..... . ......... ...6 O. 17 O0 18.11 N 17.50 W 0.8:3 0.62 O0 33.08 N 27.52 W 2. ~,~ 1 . 64 1013 1008.00 1118 1108.00 1226 1208.00 1455 1408.00 1577 1508.00 1701 1608.00 1829 1708.00 1960 1808.00 900.00 =~' '- ~,~.26 N 40.54 W ..5::~ .............. ~:~7 ........ lOO0.0o 00.28 N 56.84 w lO.28 4.90 1100.00 115.14 N 76.79 W 18.07 7.79 · !.~00,.~9 .............. ; 58,~!__~ ........ 1.pO.,.40...W ............. 29, 8o .............. ; 1773 .......... 1300.00 214.08 N 128.95 W 47.54 17.75 1400.00 275.14 N 161.42 W 69.13 21.59 15OP.O0 339.91N 196.38 W ............. ~.~ ................. ~_!P ......... 1600.00 410.83 N 234.26 W 121.66 28.33 1700.00 484.87 N 274.01W 152.28 30.62 ARCO ALASKA, 2Z-21 KUPARUK ALASKA INC. ~EEBBYz,~U~._]~EI, L.~L!R~EY INO_ COMPANY ANCHORAOE ALASKA DECEMBER 6, 1988 DATE OF SURVEY DECEMBER 1988 dOB NUMBER AK-BO-80137 KELLY BUSHING ELEV, = ........ _QF:ERATP~z~E~ 108.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 2095 1908 2236 2008 2383 2108 2528 '2208 266~ 2308 2821 2408 2981 2508 3138 2608 3289 2708 3436 2808 3585 2908 3742 3008 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH~ ~:OUTH. ......... E~./_N_EST ..... p__I .F...FEr-!,.'_EN..C.E. ..... CiQ.R.'F,:_'.E..C~T !: ON..... ....... .00 1800.00 .00 1900.00 .00 2000,00 .00 2100.00 .00 2200,00 .00 2300.00 .00 2400.00 .00 2500.00 .00 2600.00 .00 2700.00 ,00 2800.00 .00 2900.00 563.94 N 318.09 W 187.20 34.92 650.05 N 367.49 W 228,_~2 743.23 N 422.75 W 275.56 47.44 833.91N 474.28 W 320.07 44.51 921.47 N 521.59 W 361.17 41.10 1018.92 N 581.32 W 413.17 52.00 1124.16 N 648,57 W 473,17 60,00 1227.98 N __712.40 W 530,82 ................ 1325.15 N 770.19 W 581.77 50.95 1417.39 N 824.66 W 628.32 46.55 1511.92 N 883.13 ~ 677,.~ ....... 1612.45 N 948.59 W 734.05 56.19 3896 31o8. oo 3ooo. oo _4_947 .......~98,.oq .........~!0o. oo 4,194 3308.00 3200,00 4337 3408.00 3300.00 4477 3508.00 3400,00 4614 3608.00 3500.00 4750 3708.00 3600.00 1711.42 N 1011,84 W 788.31 54.26 1897.95 N 1130.52 W 886.47 46.73 1~84.66 N 1185.76 W ~2~.~0 43.43 2145.63 N 1288.11 W 1006.32 36.46 2222.68 N 1337.96 W 1042,05 35.73 ARCO ALASKA, 2z=~; .... KLIPARLIK ALASKA INC. ANCHORAOE ALASKA DATE OF SURVEY DECEMBER 4, C 0_1:1. P _U..T.~__T_I_O_ .N__ .D_ ATE DECEMBER 6, 1988 1988 ,_lOB NUMBER AK-BO-_, )137 KELLY BUSHING ELEV. = 108.00 FT. .._ _OELE~ETOR-HAROER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEpTM ...................... .K.!_EPTH ............ [!.E.P_TH.... _~.R__T.H__/~OLITH __EAS. T./._WE._ST____[! I.F..F.E.R_ENC.E_ ..... .C.i~!~_E. PT !.ON 4885 5018 5151 5283 5410 5533 5654 5772 - . 5888 6003 6116 622~ 6340 3808. O0 3700. O0 2298.53 N 1387.62 W 1077.03 34.98 ..... 3.908. O0 ......3800. :_pO 2372.41 N 1436.26 W 1110. ~ 4 3~.. 51 4008.00 3~00. 4108.00 4000. 4208.00 4100. 4308.00 4200. 4408.00 4300. 4508,_00 ...... 440Q, 4608.00 4500. 4708.00 4600. O0 =44~.Ago = N 1~'= -- 20 .. ~.,.87 W 1143.74 ~3. O0 2515.73 N 1~,~4.64 W 1175.55 ql ~:1 O0 2579.82 N 1.5__7.~_~6__W ............. ~2Q2, 2~ ................. 2~, 73 12~.,.21 ~2.93 O0 2639.24 N 1618.48 W -o= ~ O0 2696.88 N 1656.71W 1246.81 21.59 O0 ............... 2749, ~5_.~ .... 1~?1, ~4._~ .......... !~64.90 ....... 18.09 O0 2797.50 N 1725.12 W 1280.97 16.07 O0 2843.07 N 1756.61W 1275.28 14.31 4808.00 4700.00 2887.26 N 1786.99 W 4908.00 4800.00 2930.01 N 1816.54 W 5008.00 4~00.00 2969.16 N 1843.90 W 1321 . 46 12.70 1332.2.~ 10. 83 6553 5208. 6657 5308. 6760 5408. 6863 5508. 6967 5608. oo .......5_900:.00 ........... 3.o_94: ~_ Z__N ....... ! 8.6.._6_. 35. W ............. !._3..40. _61 ................ 8, 33 O0 5100. O0 3031.23 N 1883.29 W 1:345.61 5.00 O0 5200. O0 3052.47 N 1898.67 W 1349. O0 '-~ 3.~ O0 5300.00 3072.54 N 1913.79 W 1.3.~2~ 11 3.11 O0 5400. O0 3095.30 N 1927.55 W ~o~.' "5= 5'9 ~2.48 O0 5500.00 3118.47 N 1942.38 W 1359.31 3.72 ARCO ALASKA, 2Z-21 KUPARUK ALASKA INC. SPE RR Y- SUN WK.I.~ I~.~]dI I~,i_~BAN.Y ANCHORAO£ ALASKA COMPU~T_Z_O_N_~. TE.. DECEMBER 6· 1988 PAGi~ _ L DATE OF SURVEY DECEMBER 4· 1988 dOB NUMBER AK-BO-80137 KELLY BUSHING ELEV. = 108.00 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD __ DEPTH NORTH/SOL_I_T.H_. .... _E_A.~.T_/_W_E_~_;T D I .F_F_E~.E.N.C.:.E_. VERTICAL C,_.-!~..R.'E...!_'_.'T_.I.QN_ 7071 5708.00 5600.00 7175 5808.00 5700.00 .... s o .OO-- 5 oo. oo 7382 6008.00 5~00.00 7486 6108.00 6000.00 7589 6208.00 6100.00 7693 6308.00 6200.00 3142.06 N 1959.00 W 1363.39 4.08 3164.87 N 1975.56 W 1367.29 3.89 3187.2~ N 1992.05 W 1371.08 3.8(i) .~ - ~, -- 3209.38 N ~00~.59 W 1374.~2 3.74 ...... -,Z~.~__ 3.6~ .... 3231 07 N 2024.99 W 1'~" = 3252.37 N 2041.15 W 1381.97 3.52 . 3273.12 N 2056.52 W 1~ .... 25 3 28 52 .......6.300,.5~ ....... ~'.2.~3._~._0__N ....... ~071.~..67.W ....... ! 388:.48, ..................... .3, '..2-'.4 .................. THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN ............ TH_E_.N_.E_A.~E_~T_2.0_F.O. OT_DP (EROU_RA~.US OF CURVAT. UB_E_)_E_'P_~IxJTS ARCO ALASKA, INC. 2Z-21 KUPARUK ALASKA S.P.E~R¥,_SUN__~WF~LI, $_L~_V.E_Y_!.NP_'=_CC_~M..P_A..I~Y_ ANCHORAOE ALASKA ¢oH_PUT~T_~ O_N DEC. EMBER 6, 1988 .... PAGE DATE OF SURVEY DECEMBER 4, 1988 dOB NUMBER AK-BO-80137 KELLY BUSHING ELEV. = 108.00 FT, OPERATOR-HARGER INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MARKER 7260 5889.61 5781.61 3183.19 N 7446 6068.95 5960.95 3222.64 N 7579 6197.39 6089.39 3250.15 N 7650 6266.10 6158.10 3264.46 N ....................................... 7696 6310.67 6202.67 3273.67 N 7797 6408.52 6300.52 3293.90 N 1989.00 W 2000.35 W 2018.62 W 2039.46 W 2050.20 W 2056.92 W 2071.67 W TOP KUPARUK C BASE__.KL!_P.ARUK _C TOP KUPARLIK A BASE KUPARUK A sU..R.V.E...Y._.D_ E. P T H ............. PBTD TD ARCO ALASKA. INC. 2Z-21 DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA 'i ...... MARKER ....... MEASURED DEPTH THICKNESS CO~ZiSQ.INA T'~.JL WITH REF. TO WELLHEAD TOP KUPARUK C 7260 BASE KUPARLIK C 7331 TOP KUPARUK A 7446 BASE KUPARUK A 7579 PBTD 7696 BKB BKB SUB-SEA VERTICAL TD 7797 5889.61 5~58.02 6068.95 6197.39 (OR I G I N- 327FEL 2069FSL ) ~£C_ 11 _TJtlN__~OgE 5781.61 5960.95 6089.39 6310.67 _ 62Q~,~7 ...... 6408.52 6300.52 3183.19N 1.989. O~ ....... '- ] -'~= ~~ 31.98, 42N ~_~00~ ...... 3222.64N 2018.62W 3250.15N 2039.46W 327~,___67~ 2Q56. 32~3. ~ON 2071.67W --. _ 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE. DATA_ CALCULAT I ON ._A. ND_ I_.N. TERP.OLA. T! ~N_~Y._RAD._I.US__OF_..C_:~I~?A. TL!R.E DATE OF SLLR.V._EY_PE_C.;_EM_B. ER._.4:_1~.:~S8 COMPUTATION DATE DECEMBER 6, 1988 dOB NUMBER AK-BO-80137 ........................................ KE~.L_Y_B._U~..H__I.N!~._EL. EV_, _=_108.00... ET- SPERRY -$U.N -30~0.00 5CRLE :- 1 INCH TO tO00. O0 / 1000.0 KUPRRUK RRCO RLRSKR. OECEHBER 4. 2Z -21 AK-BO-B0137 7797 TRUE NORTH -2oho. oo -~obo. oo ~000.00 ~000.00 -1000.00 O. O0 l_1000. O0 H(~R I ZE]NTRL PROJECT I ON INC. 1988 SPERRY -SUN 0.00 5CRLE KUPRRUK 2Z-21 RK-80-80137 :- [ INCH TO 1500.00 / 1500.0 RRCO RLRSKR. ]NC. OECEMSER 4. 1988 1500.00 3000.00 4500.00 6000.00 7500.00 $408.52 VERT~CRL 7797 PROJECTION ~bo. oo soho. oo ~%o. oo ARCO Alaska, Inc. Date: December 8, 1988 Transmittal #: 7367 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 Y- 2 6 OH LIS Tape and Listing I 1 - 2 9 - 8 8 # 7 2 9 5 7 2 Z - 2 0 OH Edit Tape and Listing 1 2 - 0 5 - 8 8 # 7 3 0 2 8 2 Z- 21 OH Edit Tape and Listing 1 2 - 0 2 - 8 8 # 7 3 0 0 7 Receipt Acknowledged: DISTRIBUTION: State of Alaska Lynn ~Goetlinger STATE Of ALASKA A~ OIL AND GAS CONSERVATION OOMMI~..,,~ 0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate m Plugging Perforate _ Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc 3. Address P. O. Box 100360 Anchorage AK, 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2069' FSL, 327' FEL, Sec. 11, T11N, RgE, UM At top of productive interval 28' FNL, 2316' FEL, Sec. 11, T11N, RgE, UM At effective depth 63' FSL, 2384' FEL, Sec. 2, T11 N, RgE, UM At total depth 83' FSL, 2399' FEL, Sec. 2, T11N, RgE, UM 12. Present well condition summary Total Depth: measured true vertical 7797' 6409' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 109' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z-21 9. Permit number/approval number 88-125/9-567 10. APl number 5~-Q29-21 877 11. Field/Pool Kuparuk River Field Effective depth: measured 7 696' true vertical 6311 ' feet Junk (measured) feet Casing Length Size Structural 8 0' 1 6" Conductor Surface 4418' 9-5/8" Intermediate Production 7 7 60' 7" Liner Perforation depth: measured 7261 '-7332'md, true vertical 5891'-5959'tvd, Cemented Measured depth 199 sx AS II 115'md 1000 sx AS III & 4453'md 450 sx Class G Top -Job w/30 sx AS I 200 sx Class G 7778'md 7501 '-7520'md 6122'-6140'tvd True vertical depth 1 1 5°tvd Tubing (size, grade, and measured depth) 4" & 3-1/2" J-55 tbg w/tail @ 7392' Packers and SSSV (type and measured depth) 3490'tvd 6391 'tvd feet AVA 'RHS-XL' pkr @ 7165', TIW 'SS-BB' pkr @ 7366' & AVA 'Side~uard' SSSV ~ 1803' !13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service Tubing Pressure Prior to well operation (producing) Subsequent to operation (producing) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Area Drilling Engineer Date SUBMIT IN DUPLICATE Form 10-404 Rev 05/17/89 ARCO Oil and Gas Company,~," ,. Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial RepolT' on the first Wednesday after a well is spudded or workover operations are started. Daily worl( prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. KUPARUK RIVER County. parish or borough NORTH SLOPE Lease or Unit ADL: 25588 AKL: 2674 ITItle WORKOVER IStst;t~K IWell no. Field 2Z-21 Auth. or W.O. no. AK3412 Operator IARCO W.I. 56.0000 Prior status if a W.O. ARCO Spudded or W.O. begun ACCEPT' Date and depth as of 8:00 a.m. I Date 08/01/89 IH°ur 11=30 08/02/89 ( 1 TD: 7797 PB: 7696 SUPV:LP 08/03/89 ( 2 TD: 7797 PB: 7696 SUPV:LK 08/04/89 ( 2 TD: 7797 PB: 7696 SUPV:LK 08/05/89 ( 2 TD: 7797 PB: 7696 SUPV:LK Complete record for each day reported NORDIC 1 TRYING TO KILL WELL 7"~ 7778' MW:10.7 NA CL/BR MOVE RIG FROM lQ PAD TO 2Z-21. ACCEPT RIG FOR WORKOVER AT 1130 HR 8/1/89. RIG UP TANKS, ETC. TO KILL WELL.ATTEPMT TO KILL WELL WITH 10.7 PPG BRINE. DAILY:S11?,744 CUM:$1,754,455 ETD:S117,714 EFC:$3,387,741 KILLING WELL 7"@ 7778' MW:12.0 NA CL/BR PUMP AND KILL WELL DOWN TUBING. PERFORATE TUBING AT 5415-17. CIRC AND KLL WELL INCREASING BRINE WT BASED ON SITP/SICP FROM 10.7 TO 12.0 DAILY:$151,847 CUM:$1,906,302 ETD:S269,591 EFC:$3,387,711 TOH W/TBG 7"@ 7778' MW:12.0 NA CL/BR WEIGHT BRINE UP TO 12 PPG, DISPLACE WELL W/ 12 PPG BRINE, MONITOR WELL, NO FLOW, WELL DEAD, SET BPV, ND TREE, NU BOPE, TEST BOPE, BOLDS, PULL 580009, TBG CAME FREE, TOH W/ TBG, LD HGR, LD 4" TBG, STB BACK 3-1/2" TBG, MODERATE DRAG AT CONNECTIONS ON 7" DAILY:$48,825 CUM:$1,955,127 ETD:SO EFC:$3,387,711 SPACING OUT 7"@ 7778' MW:12.0 NA CL/BR POOH WITH 3-1/2" TUBING. L/D 5 COLLAPSED GLM'S. BOTTOM 3-1/2" x 1-1/2" GLMNOT COLLAPSED. CHANGE OUT 2 SEALS ON SEAL ASS'Y AND RIH WITH COMPLETION. SPACE OUT COMPLETION STRING. DAILY:S22,774 CUM:$1,977,901 ETD:S341,190 EFC:$3,387,711 The above i,~,e~rrect Signatu~.~ ~ see Procedures _k~.~.al, Section 10, Drilling, Pages 8§ and 87. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the' first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operatlonsare suspended for an indefinite or appreciable length of time. On workovers when an official test ie not required upon completion, report completion and represelltatlve test data in blocks provided. The "Final R®Fert" form may be used for reporting the entire operation if space is available. I Accounting cost center code District Sta~K ARCO ALASKA INC. ICounty or Parish NORTH SLOPE Field ILease or Unit KUPARUK RIVER ITltleADL: 25588 AKL: 2674 2Z-21 Auth. or W,O. no. I ' AK3412 I WORKOVER IWell no, Operator A.R.Co. W.I. ~z~CO Date56. 0000 Spudded or W.O. begun ACCEPT 08/01/89 Complete record for each day reported Date and depth as of 8:00 a.m. NORDIC 1 Iotalnumber of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our 1 Prior status If a W.O. I 11:30 08/06/89 TD: 7797 PB: 7696 SUPV:LK RIG RELEASED 7"@ 7778' MW: 6.8 DIESEL SPACE OUT AND LAND COMPLETION. SET BPV. N/D BOP AND N/U AND TEST TREE. DISPLACE WELL WITH DIESEL. PULL CHECK VALVE AND REPLACE WITH DUMMY VALVE AT GLM @ 7094'. TEST ANNULUS TO 2500PSI FOR 30 MIN. RELEASE RIG TO 2Z-20 AT 1800 HR 8/6/89. FINAL COST $399,889 DAILY:S38,699 CUM:$2,016,600 ETD:S2,016,600 EFC:$3,556,940 Old TD Released rig Classifications (oil, gas, etc.) INew TD Date PB Depth Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(e) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. :C.P. Water % iGOR Gravity Allowable Effective date corrected S igna/~~The ab.~is correct sF~; ~3°r~r~ e~r~rPe~n u aaln, dS ed ic~ti r(~ ~b u~ i0°, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. I Division of AtlsntlcRichfteldCompany o. 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 X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2070' FSL, 328' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 0' FNL, 2360' FEL, Sec. 11, T11N, R9E, UM (approx.) At effective depth 48' FSL, 2372' FEL, Sec. 2, T11N, R9E, UM (approx.) At total depth 69' FSL, 2388' FEL, Sec. 2, T11N, R9E, UM (approx.) 12. Present well condition summary Total Depth: measured true vertical 7797' feet Plugs (measured) 6423' feet None 6. Datum elevation (DF or KB) RKB 109' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-21 /~ ~ '~ '-' ~- ,~-,~-~ 9. Permit number 88-12~ 10. APl number 50-029-21 877 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7696' feet Junk (measured) 6 3 2 6' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4418' 9 5/8" 7760' 7" Cemented Measured depth 199 Sx AS II 115' MD 1000 Sx AS III & 4453'M D 450 sx Class G - Top job w/30 sx ASI 200 Sx Class G 7778'M D measured 7261'-7332' MD, 7501'-7520' MD true vertical 5891'-5959'TVD, 6122'-6140' TVD Tubing (size, grade, and measured depth 4"/3-1/2", J-55, tbg w/tail @ 7392' Packers and SSSV (type and measured depth) True vertical depth 115' TVD 3504'TVD 6405' TVD AVA 'RHS-XL' pkr @ 7165', TIW 'SS-BB' pkr @ 7366' & AVA 'Sideguard' SSSV @ 1828 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch X ~ Fracture A Sand 14. Estimated date for commencing operation July, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X. Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ (.~,~ ~ ~ ..~L~~/~-4~ TitleFoR COMMISSIoNSr' OperatiOnSuSE ONLyEngineer Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No~. Approved Copy Returned Approved by the order of the Commission Form 10-403 Rev 5/03/89 Commissioner Date "~/~-~'~ ~ SUBMIT IN TRIPLICATE KUPARUK RIVER WELL 2Z-21 FRACTURE STIMULATE THE A SAND . , . . No workover fluids will be used during the fracture treatment. No BOP's will be used during the fracture treatment. The estimated maximum surface treating pressure is 6,500 psi. The estimated A Sand bottom hole pressure is 2,600 psi. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A A Kuparuk Well 2Z-21 Sand Fracture Stimulation AFE #AK3412 May 12, 1989 Pre-Frac Slickline Work 1. MIRU Slickline Unit. 2. Tag bottom. 3. (If applicable) Replace GLV's with dummy valves. . Pull Otis commingling sleeve with blanking plug from Otis ported landing nipple at 7351' RKB and replace with isolation sleeve. . RIH with standing vane and set in Otis ported landing nipple at 7351' RKB. Pressure test tubing to ensure DV's are set. Pull standing valve. 6. RDMO Slickline unit. Fracture Stimulation 7. MIRU fracturing equipment and related flowback equipment. 8. Record the total weight of the proppant. 9. Perform ali standard quality control procedures (On-site Operations Engineering). 10. Install largest diameter 'tree saver' available for 4", 11.0# tubing. Pressure test lines. Pressure up the annulus to prevent tubing buckling and maintain throughout job. 11. Pump the 150 BBL pre-pad at 20 BPM. Shut down and record ISIP and 10 minute pressure decline. If treating pressure is excessive (greater than approximately 5,500 psi), ball out the perfs. (Halliburton should come prepared for a ball out). Perf size is approximately 0.4" and the total number is 152. 12. Pump the fracture stimulation as per the attached pump schedule. Ramp between stages. Obtain representative fluid samples of the pad, slurry, and flu'sh stages during the treatment. Place frac fluid samples in 140° water bath.. The estimated treating conditions are as follows: WHTPE: Fracture Gradient: Tubing Friction: Tubing Friction: Recommended maximum treating pressure 3,600 psi 0.72 psi/ft 140 psi / 1000' (4") 220 psi / 1000' (3.5") 6,500 psi 13. 14. 15. Record ISIP and 5 minute, 10 minute and 15 minute shut-in pressures. SI well, bleed down annulus, and rig down Record the weight of proppant not pumped. Flowback Schedule 16. Begin flowback at the designed break time after verifying that gelled water samples in the water bath have broken. Contact Operations Engineering in Anchorage and do not begin flowback if gelled water samples have not broken. 17. Flowback the well at 5 to 10 BPH. At bottoms up verify that the gel has broken. Record tanks straps, choke settings and WHP's during flowback period. Inspect samples for proppant. If excessive proppant is produced, reduce rate and contact Operations Engineering. 18. After 24 hours of flowback at 5 to 10 BPH, decrease the wellhead pressure in 50 psi increaments every two hours until the well is producing at header pressure. Continue to monitor for unbroken gel or excessive proppant throughout flowback. 1 9. Once well has completed flowback, obtain a 24 hour well test. KUPARUK WELL 2Z-21 A SAND FRACTURE PUMPING SCHEDULE 5/12/89 ST/tGE FLUID CLEAN VOLUME PUMP RATE PROP, ~. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM (~ BBLS 1 GW PRE-PAD 150.0 20 0 .................................................. SHUT DOWN FOR ISIP 2 GWPAD 150.0 20 0 3 GW w/2 PPG 18,4 2 0 2 4 GW w/4 PPG ,17.0 20 4 5 GW wi6 PPG 19.8 20 6 6 GW wi8 PPG 22.2 20 8 7 GW wi10 PPG 24.3 20 1 0 8 GW w/12 PPG 13.1 20 1 2 9 SLICK DIESEL FLUSH 77.0 +SV 2 0 0 · 0 AND LEAKOFF CALGULA¥1ONS 0 16/20 M CARBO-LITE 1 544 16/20 M CARBO-LITE 2856 16/20 M CARBO-LITE 4982 16/20 M CARBO-LITE 7452 16/20 M CARBO-LITE 10203 16/20 M CARBO-LITE 6593 - ' 0 1 50/ 1 50 81 1 50/ 300 231 20/ 320 381 20/ 340 401 25/ 365 421 30/ 395 446 35/ 430 476 20/ 450 511 77/ 527 511 TOTAL GELLED WATER = TOTAL DIESEL = TOTAL FRAC FLUID = TOTAL DIESEL FOR FLUSH -- 397.9 BBLS 16.8 BBLS 414.7 BBLS 77.0 BBLS + SV 1. All fluids should be maintained between 85 F and 90 F on the surface. 16/20 M CARBO-LITE -- 33632 LBS 2. Stages I and 4 are crossllnked 40~1,000 gal gelled water with 2% KCL by weight and 5% diesel by volume and enough breaker for an 8 hour br~[a~. :~= 3. Stages 5 through 8 are the same as above but without diesel. C',d ~,;, ~ 4. Reduce pump rate to 15 BPM if treating pressure rises to 6,000 psi. Shut down at 6,500 psi. ,,~ _.'i~ ~ c,, .~.;~. 5. Stage 9 (flush) should include a volume adjustment for surface equipment between the wellhead and densimeter. '~'~ ~ ~,,'~ 6. This job is intentionally underflushed by 4.0 bbls. The blender tub should be bypassed at flush. ,;,.~,~ · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Comp'l ere Change approved program __ Pull tubing ~ Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2069' FSL, 327' FEL, Sec.ll, T11N, RgE, UM At top_o_f p. roductive interval 28' FNL, 2316' FEL, Sec.11, T11N, RgE, UM At ef~qtivl~SdLe?~84' FEL, Sec. 2, T11N, RgE, UM At total depth 83' FSL, 2399' FEL, Sec. 2, T11N, RgE, 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 2Z-21 9. Permit number 88-125/8-983 10. APl nu0r~bBe_~ 50-- 1877 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total depth: measured 7797 'ND true vertical 6409'TVD 7696'MD Effective depth: measured 6311 'TVD true vertical feet Plugs (measured) feet feet Junk (measured) feet None None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth ~ueverticaldepth 80' 16" 199 sx AS II ll5'MD ll5'TVD 4418' 9-5/8" 1000 sx AS Ill & 4453'MD 3490'TVD 450 sx Class G - Top job w/30 sx AS I 7760' 7" 200 sx Class G 7778'MD 6391'TVD measured 7261 '-7332'MD, 7501 '-7520'MD RECEIVED true vertical Alaska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) Anchorage 4"/3-1/2", J-55, tbg w/tail ~ 7392' Packers and SSSV (type and measured depth) AVA ~RHS-XL~ per ~ 7165~ TI~ ~SS-BB~ pkr ~ 7366~ & AVA ~Sideguard~ SSSV ~ 1828~ 13. A~achments Description summary of proposal ~ Detailed operations program __ BOP sketch ~ 14. Estimated date for commencing operation July 5, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: / Oil Z Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED LONNIE C. ,qMtTU GA1/9 Commissioner J Approval No. 2'",,~::~ '~ .Approved Copy Returned / SUBMIT IN TRIPLICATE/'Y' KUPARUK RIVER UNIT WELL 2Z-21 WORKOVER SUMMARY The purpose of this workover is to replace a collapsed GLM located at 5,479'. This will require pulling the existing tubing string from above the top production packer. The well will be killed with brine prior to removing the tree and installing the BOP stack. KRU 2Z-21 was completed as a single selective in March, 1989. The current completion was run without incident. During slickline operations in the first part of June trouble developed in passing tools through a 3-1/2" x 1" Camco KBUG GLM located at 5,479'. The GLM appears to be collapsed. To repair the existing problem a workover is planned to replace the collapse mandrel and to inspect the other GLM's in the completion. RECEIVED JUN 2 9 t989 Alaska 0ii & Gas Cons. Commission Anchorage KUPARUK RIVER UNIT WELL 2Z-21 WORKOVER 4"x 3-1/2" SELECTIVE SINGLE COMPLETION 1. Set BPV. MIRU Nordic #1. Fill pit with unviscosfied brine. 2. Pull BPV. Kill well by bullheading brine down tubing. Do not exceed frac gradient of the "A" sand. 3. Set BPV and ND tree. NU BOP. Pull BPV and set test plug. Test rams, annular, and choke manifold to 3000 psi. (Notify AOGCC prior to NU BOPE.) 4. Screw into tubing hanger with 4" tubing with x/o to 4-1/2" NU lift thread. Back out lock down screws. . Pressure up on tubing to 200 psi if possible. Close annular and strip out tubing until the seals are out of the PBR. Circ out deisel packer fluid on choke the long way. Ensure well is dead and stable. 6. POOH with existing completion assembly. Stand back tubing in derrick. Inspect jewelry. SSSV and 'good' GLM's will be re-run. Lay out collapsed GLM(s) and make note of same. 7. Change out AVA seal assembly and re-run completion with new jewelry items as required. Verify all completion equipment has been operationally and/or pressure tested. * Drift all tubing and completion equipment. * Record OD's and I D's of all auxiliary equipment. * Install and test dummy valves in all GLMs. Flush out 1/4" SSSV control line with Chevron aviation hydraulic fluid. * Use APl modified pipe dope. * Change out all seal rings. * Torque 3-1/2", 9.3#/ft, J-55, EUE 8RD MOD torque, 2400 ft-lbs, maximum torque. JUN 2 9 t989 Alaska 0il & Gas Cons. C0mmissJ0n Anchorage to 1600 ft-lbs, minimum Make up to last scratch. * Torque 3-1/2", 9.2#/ft, J-55, BTC AB MOD to 1000 ft-lbs, minimum torque, 1600 ft-lbs, maximum torque. Make up to base of triangle. Torque 4", 11.0#/ft, J-55, DSS-HTC to 2400 ft-lbs, optimum torque, 1800 ft-lbs minimum and 3000 ft-lbs, maximum torque. Shoulder connection. * Pressure test SSSV control line to 5,000 psi. Maintain 3,000 psi while running in hole. Clamp control line every other joint. 2Z-21 WORKOVER (continued) 8. Sting into PBR and test backside to 1,000 psi. Space out tubing hanger. Bleed off pressure off of SSSV control line and attach to tubing hanger. Re-pressure control line and test to 5,000 psi for 10 minutes. Drain stack and land tubing. Run in lock down screws. Test back side to 1,000 psi. 9. R/U slickline and pull dummy valve from 1-1/2" GLM above packer. Displace annulus and tubing with deisel. Record SITP and SICP. Re-set dummy valve in GLM and test annulus to 1,000 psi. Set BPV. N/D stack. N/U and test tree to 5,000 psi. Release rig. 10. 11. 12. 13. REC[IVED Alaska 0il & (;as Cons. Commission Anchorage COMPLETION SCHEMATIC 2Z-21 AS-RUN COMPLETION SELECTIVE SINGLE COMPLETION "C" SAND PRE- FRAC PERFS: 7261 '-7332" PERM PKR AT 7366' WLM "A" SAND PRE- FRAC PERFS: 7501 '-7520' . 1 - 4" X 1" TELEDYNE MERLA GLM WITH DUMMY VALVE AT SPECIFIED . 6 - 3-1/2" X 1" CAMCO "KBUG" GLMS WITH DUMMY VALVES AT SPECIFIED . 10. 1 JT 3-1/2", 9.3#, J-55, EUE 8RD, AB-MOD IPC TUBING 1 1 . 3-1/2" X 1" CAMCO 'KBUG' GLM WITH DUMMY VALVE (EUE 8RD) 12. 1 JT 3-1/2", 9.3#, J-55, EUE 8RD, AB-MOD IPC TUBING 13. CARBIDE BLAST RINGS (WITH 5' OVERLAP ACROSS 'C' SAND PERFS) 14. 3-1/2" X 10' PUP JOINT 1. 4", 11.0#, J-55, DSS-HTC, IPC TUBING 2. 4", AVA "Sideguard' SSSV, 5.900"OD, 3.250"1D (DSS-HTC) 4", 11.0#, J-55, DSS-HTC, IPC TUBING DEPTH, USE BK-2 LATCH (DSS-HTC), 5.850"OD, 3.125"1D 4. CROSSOVER, 4" DSS-HTC BOX X 3-1/2" EUE 8RD PIN @ 4004' MD 3-1/2", 9.3#, J-55, EUE 8RD AB Mod IPC TUBING DEPTHS, USE BK-2 LATCHES, (BTC AB MOD), 5.359"OD, 2.867" ID 6. 3-1/2" X 1-1/2" CAMCO "MMG-2' GLM WITH AVA 1-1/2" CK VALVE, USE RK LATCH (EUE 8RD AB-MOD) 5.793"OD, 2.920"1D 7. 1 JT 3-1/2", 9.3#, J-55, EUE 8RD, AB-MOD IPC TUBING 8. 3-1/2" AVA PBR BBL ID = 3.90" 3-1/2" X 7" AVA RHS-XL PACKER 5.955"OD, 3.00"ID 60,000# REL 15. 3-1/2" OTIS PORTED LANDING NIPPLE 4.50"OD, 2.813" XN PROFILE WITH ISOLATION SLEEVE 2.35"1D (EUE 8RD) 16. 3-1/2" X 10' PUP JOINT 17. TIW LOCATOR SEAL ASSEMBLY 1 8. 3-1/2" X 7" TIW 'SS-BB' WL SET PACKER WITH 5' SEAL BORE EXTENSION XO TO 3-1/2" EUE 8RD 19. 3-1/2" X 8' PUP JOINT 20. 3-1/2" OTIS "XN" NIPPLE 2.750" X 2.635" 21. 3-1/2" X 8' PUP JOINT 22. 3-1/2" AVA SHEAR OUT SUB (PINNED FOR 3500#) TUBING TAIL @ 7392' TUBING MEAS. FO @ 7698' IGC 1/6/89 7-1/16" 5000 PSI BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 4 BLIND RAMS 5 TUBIN6 HEAD 2 1. 16" CONDUCTOR SWAGED TO 10-:3/4" 2. 11"-:3000 PSI STARTING HEAD :3.11 "-3000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1 / 16"- 5000 PSI PIPE RAMS S. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1, CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS :3000 PSI WITH 1500 PS! DOWNSTREAM OF THE REGULATOR, 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO :3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. 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. 11. TEST STANDPIPE VALVES TO 3000 PSt. 12.TEST KELLY COCKS AND INSIDE BOP TO :3000 PSI WITH KOOMEY PUMP. 1:3.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14 PERFORM COMPLETE BORE TEST ONC OPERATE BORE DAILY. jUN 2 9 t9 9 Oii& Gas Cons, Commission Ar~cho_rage dO JULY 28, 1986 (NORDIC RIG 10-3/4") STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging Pull tubing ~ Alter casing m Repair well m Perforate ~' Other ~__ Compl ere 2. NameofOperator ARCO Alaska¢ Inc. 3. Address P.0, Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2069' FSL, 327' FEL, Sec.11, T11N, R9E, UM At top of productive interval 28' FNL, 2316' FEL, Sec.11, TllN, R9E, UM At effective depth 63' FSL, 2384' FEL, Sec. 2, T11N, R9E, UM At total depth 83' FSL, 2399' FEL, Sec. 2, T11N, R9E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation(DForKB) RKB 109' Z UnitorPropertyname Kuparuk River Unit 8. Well number 2Z-21 9. Permit number/approval number 88-125/8-983 10. APl number 50-- 029-21877 11. Field/Pool Kuparuk River 0il Pool 12. Present well condition sUmmary Total depth: measured true vertical Effec!ive depth: measured true vertical 7797'MD 6409'TVD 7696'MD 6311'TVD Casing Length Size 80 ' 16" Conductor 4418 ' 9-5/8" Surface 7760' 7" Production feet feet feet feet Plugs (measured) No ne Junk (measured) None Cemented Measured depth 199 sx AS II 115'MD 1000 sx AS III & 4453'MD 450 sx Class G - Top job w/30 sx AS I 200 sx Class G 7778'MD ~ueverticaldepth 115'TVD 3490'TVD 6391'TVD Perforation depth: measured 7261 '-7332'MD, 7501 '-7520'MD true vertical 5891 '-5959'TVD, 6122 '-6140 'TVD Tubing (size. grade, and measured depth) 4"/3-1/2", J-55, tbg w/tail ~ 7392' Packers and SSSV (type and measured depth) AVA 'RHS-XL' pkr ~ 7165'~ TIW 'SS-BB' pkr ~ 7366' & AVA 'Sideguard' SSSV ~ 1828' 13. Stimulation or cement squeeze summary Intervals treated (measured) 7214'-7216, Treatment description including volumes used and final pressure .-,,;:,.~.s!;~ .Oil & Gas Cons. Comr~issio~,'" ..... ,,,~, ~,nch0rage 14. Representative Daily Average Production or Injection Data N/A Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run ," Daily Report of Well Operations .Jr_.. Gyro Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 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. Area Drilling Engr. Service Form 10-404 Rev06/15/88 b * Completion Well History (Dani) SW04/021 feet SUBMIT IN DUPLICATE · ARCO Oil and Gas Company · Well History - Initial Report - Daily 'instructions: 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. ARCO ALASKA INC. District KUPARUK RIVER Field AK3412 Auth. or W.O. no, ICountyl parish ~r'5'O%Od~h Lease or Unit .... -----. ~--v~m--&lO / / IState A~ 2Z-21 Well no. ARCO Operator ACCEPT Spudded or W.O. begun Date and depth as of 8:00 a.m.02/22/89 ( TD: 7797 PB: 7696 SUPV:DL 02/23/89 ( TD: 7797 PB: 7696 SUPV:CD 02/24/89 ( 1 TD: 7797 PB: 7696 SUPV:CD 02/25/89 TD= 7797 PB: 7696 SUPV:CD 02/26/89 ( 14 TD: 7797 PB: 7696 SUPV:CD NORDIC i IDate Complete record for each day reported lO) 02/21/89 ARCO W¢6' 0000 JHour 1130 HRS Prior status f a W.O. SURGING SOUR~m PERF$ 7~ 777~' MW: 0.0 RIG ON LOCATION @ 1130 HR 2/21/89. N/D MASTER VALVE AND N/U BOP. TEST BOP TO 250 AND 3000 PSI. INSTALL WEAR BUSHING. R/U ATLAS W/L. TEST LUB . PERF W/ 4" GUNS @ 4SPF F/7214-16. POOH. RUN 6" GAUGE RING & JUNK BASKET TO 7682'. RUN AND SET BRIDGE PLUG @ 7241'. R/D ATLAS. M/U CHAMP SQUEEZE PKR & BY-PASS. RIH TO 2000'. CIRC OUT 66 BBL OF DIESEL. FIN TIH TO 6972'. EST INJECTION RATES OF 1/4 BPM @ 3000PSI. AFTER 4 BBL 1/3 BPM @ 3000PSI. AFTER 7 BBL 1/2BPM @ 3000PSI. PRESSURE BLEED TO 1350PSI AFTER 20 MIN. RELEASE PRESS & CIRC THRU BY-PASS-OK. CLOSE BY-PASS AND ATTEMPT TO SURGE PERFS. DAILY:S44,600 CUM:$1,044,240 ETD:S1,044,240 EFC:$1,751,000 SLIP CUT DRILL LINE 7"@ 7778' MW:10.7 NA CL/BR SURGE PERFORATIONS. UNABLE TO GET OVER 1/2 BPM INJECTION RATE. RIG DOWN B.J. UNSET PKR AND POH. RIH W/ 115 STANDS + SINGLE. TAG @ 7235' SLM.(Bp @ 7241'} WLM). MIX, PUMP AND DISPLACE 75SX CLASS G + ADDITIVES. SET AS BALANCE PLUG. POH 10 STANDS. REV CIRC 1-1/2 CAPACITY OF D.P. PERFORM BRADEN HEAD SQUEEZE HOLDING 2500 PSI FOR 4 HOURS. POH. M/U BHA & TIH. SLIP & CUT DRILL LINE. DAILY:S54,662 CUM:$1,098,902 ETD:S1,098,902 EFC:$1,751,000 POOH 7"@ 7778' MW:10.7 NA CL/BR GIH. TAG CEMENT AT 6895. TEST TO 3000PSI. DRILL HARD CEMENT 6895 TO 7240. TAG EZSV @ 7241. CBU. TEST SQUEEZE PERFS TO 1500 PSI. DRILL EZSV 7241-43. RIH TO 7684. CBU. POOH TO P/U CASING SCRAPERS. DAILY:S28,710 CUM:$1,127,612 ETD:S1,127,612 EFC:$1,.751,000 PULL WEAR BUSHING 7"@ 7778' MW:10.7 NA CL/BR POOH WITH BOTT BASKETS. P/U 7" CASING SCRAPER. TIH. TAG @ 7680. CIRC & FILTER COMPL FLUID. POOH L/D DP. ATTEMPT TO PULL WEAR BUSHING. DAILY:S35,539 CUM:$1,160,151 ETD:S1,160,151 EFC:$1,754,000 MONITOR WELL-W.O.W. 7"@ 7778' MW:10.7 NA CL/BR N/D STACK. PULL WEAR BUSHING. N/U STACK. R/U DRESSER. TEST LUBRICATOR TO 1500PSI. PERF WITH 5" CASING GUNS. AFTER 5TH RUN WELL BEGAN TO FLOW. SHUT-IN NO PRESSURE. PUT 100 PSI ON WELL AND SHUT IN WHILE WAITING ON WEATHER. HIGH WINDS. MAX WIND SPEED-109 MPH. MONITOR WELL. DAILY:S27,797 CUM:$1,187,948 ETD:S1,187,948 EFC:$1,754,000 The above is correct For f0rm'p"~aration a~ distribution--, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, Drilling ,Supt. AR3B-459-1-D (~;:!~;~'[~ii$;::,.~4Number all daily well history f ........... tively las they are prepared for each well, Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or {2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin.e until comp et un. County or Parish State District I NORTH SLOPE ARCO ALASKA INC. AK I Field ILease or Unit KUPARUK RIVER / 2Z-21 :Complete record for each day while drilling or workover in progress NORDIC 1 Date and depth as of 8:00 a.m. 02/27/89 ( TD: 7797 PB: 7696 SUPV:CD 02/28/89 ( TD: 7797 PB: 7696 SUPV:CD 03/01/89 ( TD: 7797 PB: 7696 SUPV:CD 15) TIH 7"@ 7778' MW:10.9 NA CL/BR WAIT ON WEATHER. WT UP BRINE IN THE PITS TO 10.9PPG. REPAIR PIPE ELAVATOR. LOAD PIPE SHED WITH DRILL PIPE WHILE MONITORING WELL. TIH W/ DP OPEN ENDED. DAILY:S30,621 CUM:$1,218,569 ETD:S1,218,569 EFC:$1,754,000 RIH W/PACKER ON W/L 7"@ 7778' MW:10.9 NA CL/BR TIH WITH D.P. CIRC WELL ON CHOKE INCREASING BRINE WT TO 10.9 PPG. CIRC AND MONITOR WELL. POOH L/D DP. R/U DRESSER REPERF F/7272-92, 7295.5-7302, AND 7261-71. RIH W/ 6.00" GAUGE RING/JUNK BASKET TO 7679' WLM. M/U TIW PERM PKR. RIH w/ PKa ON W/L. DAILY:S40,768 CUM:$1,259,337 ETD:S1,259,337 EFC:$1,754,000 DISPLACE WITH DIESEL 7"@ 7778' MW:10.9 NA CL/BR RIH W/ TIW PERM PKR. SET @ 7360' WLM. RUN 3.5 X 4" COMPLETION. M/U AVA 4"SSSV. TEST CONTROL; LINE TO 5,000 PSI. CONT RUN COMPLETION. STING INTO LOWER PACKER AND VERIFY W/ 500 PSI. SPACE OUT. M/U FMC 4-1/16" 5M TBG HANGER. LAND TBG. TEST TBG TO 2500PSI. PACKER SET AT 2200PSI.TUBING WOULD NOT TEST. PRESS ANNULUS TO 1500 PSI AND SHEAR AVA PBR. P/U TBG AND VERIFY SHEAR-OUT. PRESS ANNULUS TO 2000PSI. ORIFICE VALVE SHEARED. INCREASE ANNULUS PRESSURE TO 2500 TEST ANNULUS-OK. CLOSE SSSV AND TEST SAME-OK. WASH THRU ORIFICE VALVE. RE-TEST TBG TO 2500PSI-OK. SHEAR OUT BALL@ 3200PSI. SET BPV. N/D STACK AND N/U FMC 4-1/16" 5M GEV IV TREE. PULL BPV SET TEST PLUG AND TEST TREE TO 5000PSI-OK. DISPLACE WITH DIESEL. (AVA 'SIDEGUARD' SSSV @ 1828', AVA 'RHS-XL' PKR @ 7165', TIW 'SS-BB' PKR @ 7366', AND TT @ 7392'.) DAILY:S365,474 CUM:$1,627,811 ETD:S1,627,811 EFC:$1,751,000 IWell no. The above is correct For form preparation and ~is~ibution see Procedures Manual Section 10, Drilling, Pages 86 and 87 · AR3B-459-2-B J Number all daily well history forms consecutively Jas Ihey are prepared for each well. lPage no ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepa~'e and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended lor an indefinite or appreciable length of time. On workovers when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code County or Parish NORTH SLOPE Lease or Unit KUPARUK RIVER Title ADL: 25646 2Z-21 I COMPLETE & PERFORATE District ARCO ALASKA INC. State AK Well no. Auth. or W.O. no. AK3412 ADL: 50-029-21877 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our ] Prior status if a W,O. I 1130 HRS Operator A.R.Co. W.I. ARCO 56. 0000 Spudded or W.O. begun Date ACCEPT 02/21/89 Date and depth i Complete record for each day reported as of 8:00 a,m NORDIC 1 03/02/89 ( 1 TD: 7797 PB: 7696 SUPV:CD RIG RELEASED 7"@ 7778' MW:10.9 NA CL/BR DISPLACE WITH 258 BBL DIESEL. PRESSURE TUBING TO 1000 PSI TO CHECK ORIFICE VALVE-OK. SET BPV AND SECURE WELL. PULL RIG OFF 2Z-21. RIG RELEASED TO 1B-5 AT 1200 HRS 3/1/89. DAILY:S8,900 CUM:$1,636,711 ETD:S1,636,711 EFC:$1,751,000 Old TD New TD PB Depth Released rig Date K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Off c a reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest lime Production Oil 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Division ot AflanflcRIchfleldCompany STATE OF ALASKA Ab-,,.,KA OIL AND GAS CONSERVATION COMMIb,.,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown _~_ Re-enter suspended well m Alter casing m Repair well ~ Plugging ~ Time extension ~ Stimulate __ Change approved program m Pull tubing ~ Variance m Perforate m Other ~ 2. Name of Operator ! 5. Type of Well: '~. 6. Datum elevation (DF or KB) ~ Development ~ april Alaska. Inr'. [ Exploratorym RKB 109' 3. A~cl-r~s -- - I Stratigraphic ~ 7. Unit or Property name P, O, Box 100360~ ..Anchora~e~ AK 99510~0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 2Z-21 A2070.' FSL~ 328' FEL, Sec.ll, T11N, R9E, UM ttop ct productive interval 9. Permit number 0' FNL, 2360' At effective depth 48' FSL, 2372' At total depth 69' FSL.~, 2388' 12. Present well condition summary Total depth: measured true vertical FEL, Sec.ll, TllN, R9E, UM (Approx) FEL, Sec 2, T11N, R9E, UM (Approx) FEL, Sec.2, TllN, RgE, UM (Approx) _, 88 - 1 25 10. APl number 50-- 029-21877 11. Field/Pool Kuparuk River Oil Pool 7797'MD feet Plugs(measured) None 6423'TVD feet Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Surface /4.41 8 ' Intermediate Production 7760 ' Liner Perforation depth: measured true vertical ~bing(size. grade, and measureddepth) None PackersandSSSV(typeandmeasureddepth) None 7696'MD ~et Junk(measured) None 6326'TVD ~et Size Cemented Measured depth 16" 199 sx AS II llS'MD 9-5/8" 1000 sx AS III & 4453'MD 450 sx Class G - Top Job w/30 sx AS I 7" 200 sx Class G 7778'MD None None True vertical depth 115'TVD 3504'TVD 6405'TVD 13. A~achments Descriptionsummaryofproposal~ Well History Detailed operations program BOP sketch 14. Estimated date for commencing operation ~ll ~- ~- ~ m b,e r~ lqRR 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil'"k¢~ Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed(¢~T(/~Z¢,,_ Title Area Drilling Eng neer '""' - - '~ --" FoR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance m Mechanical Integrity Test ~ Subsequent form required 10- r,p,.-~.,,^~ SIGNED BY Approved by order of the Commissioner LOS~,,I,:. C. SMITH (Dani) SA4/02 81Approval No. .~poroved Copy Returned Commi.ioner Date feet Form !0-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: 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 ARCO ALASKA INC. Ii NORTH SLOPE Field Lease or Unit KUPARUK RIVER ADL: 25646 Auth. or W,O, no. ~Title AK3412 J DRILL Operator ARCO Spudded or W.O. begun ~Date SPUD Date and depth as of 8:00 a.m. Complete record for each day reported DOYON 14 J St a~,,K 2Z-21 ]w.,, .o. API: 50-029-21877 1' 56,0000 IHour ~ .... IPrior StaiUS if a W.O. 11/05/88 ( ] TD: 2211'( 2~ SUPV: 11/06/88 ( TD: 4480'( SUPV: 11/07/88 ( TD: 4480'( SUPV: 11/08/88 ( TD= 6070'( 15 SUPV: ) 69) 0) ~0) 11/09/88 (5) TD: 7625'(1555) SUPV: 55) 11/10/88 ( TD: 7780'( SUPV: 11/11/88 ( TD= 7780'( SUPV: 11/12/88 ( 8 · TD: 7797'( SUPV: 7) DRLG 16"@ 115' MW: 9.2 VIS: 60 ACCEPT RIG @ 0530 HRS, 11/4/88. NIPPLE UP DIVERTER AND FUNCTION TEST, DRILL AND SURVEY TO 2211'. DAILY:S195,704 CUM:$195,704 ETD:S195,704 EFC:$1,751,000 TIH ON SHORT TRIP 16"@ 115' MW: 9.3 VIS: 45 DRILL FROM 2211' TO 4480',CBU, SHORT TRIP TO 400', HOLE TIGHT FROM 1030' TO 600', TIH. DAILY:S43,688 CUM:$239,392 ETD:S239,392 EFC:$1,751,000 TESTING BOPE 9-5/8"@ 4453' MW: 8.3 VIS: FINISH TIH, CBU, TOH, RU CASING TOOLS,RUN 115 JTS 9-5/8" CSG AND SET AT 4453', CEMENT CSG W/1000 SX AS III & 450 SX CLASS G. LOST RETURNS DURING JOB, DO TOP JOB W/30 SX AS I. DAILY:S196,107 CUM:$435,499 ETD:S435,499 EFC:$1,751,000 DRILLING 9-5/8"@ 4453' MW: 9.1 VIS: 33 PU BIT AND BHA, TEST CSG, DRILL OUT, DISPLACE WATER WITH POLYMER MUD, TESTED SHOE TO 12.8 .PPG EMW TO LEAKOFF, DRILL 4480' TO 4982', STANDPIPE PRESSURE TOO HIGH, TOH, FOUND 2 JETS BLANKED FOR WRONG TFA, CHANGE BITS, TIH TO SHOE, CUT DRILL LINE, TIH, DRILL 4982' TO 6070'. DAILY:$66,880 CUM:$502,379 ETD:S502,379 EFC:$1,751,000 DRILLING 9-5/8"@ 4453' MW:10.7 VIS: 42 DRILLING FROM 6070' TO 7625'. DAILY:S57,321 CUM:$559,700 ETD:S559,700 EFC:$1,751,000 LOGGING 9-5/8"@ 4453' MW:10.7 VIS: 44 DRILL TO 7780', SHORT TRIP TO SHOE, HOLE TIGHT, REAM 7570' TO 7780', COND HOLE FOR LOGS, DROP SURVEY, TOH, RU SCHLUMBERGER AND LOG. DAILY:S48,607 CUM:$608,307 ETD:S608,307 EFC:$1,751,000 TIH FOR WIPER TRIP 9-5/8"@ 4453' MW:10.7 VIS: 52 LOG AS FOLLOWS= DIL/SFL/GR/CAL/SP/FDC/CNL, MICROLOG/GR, FMS/GR, RFT AT SPECIFIED DEPTHS. MAKE UP BHAAND TIH FOR WIPER TRIP. DAILY:S43,366 CUM:$651,673 ETD:S651,673 EFC:$1,751,000 The above is,,~Ofrect r)~TT .~.o ~ For form preparation and~ution, ~ ns e. ~,; P~ r~.nnu4a Is~S e c)t o n 10. ~ NIPPLE DOWN, LAND 7" CSG 7"@ 7778' MW=10.7 VIS: 48 WASH & REAM 50' TO BOTTOM, DRILL 17' RATHOLE, CIRC & COND MUD FOR CSG, TOH, RU & RUN 198 JOINTS 7", LOST RETURNS WHILE RUNNING, UNABLE TO REGAIN CIRC, PIPE STOPPED 19' OFF BOTTOM, CEMENT CSG (41 BBLS) CLASS G, DISPLACE W/ 295 BBLS 10.7 PPG BRINE, RECIPROCATE CSG WHILE CMTG, NO RETURNS DURING JOB, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Raporl" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. Field KUPARUK RIVER Auth. or W.O, AK3412 Operator ARCO ICounty orN°(~H SLOPE Lease o r ~iL~j~: 25646 Title DRILL API: 50-029-21877 Ac;:ountlng cost center code Stat~,K 2Z-21 IWel~ no. I A,R.Co. Spudded or V~l~]]gun IDate 11/04/88 I Complete re~l~%~ea~.l~day reported Date and depth as of 8:00 a.m. ~6.0000 11/13/88 ( TD: 7797'( SUPV: Iotal number of wells (active or inactive) on this oat center prior to plugging and I bandonment of this well I our 1300 HRS IPrlor status If a W.O, I RELEASE RIG 7"@ 7778' MW: 0.0 VIS: LAND 7" CSG, CUT OFF LANDING JT, INSTALL PACKOFF & TEST SAME TO 3000 PSI, CLEAN PITS, RELEASE RIG @ 1130 HRS, 11/12/88. DAILY.' $347,967 CUM: $999,640 ETD.' $999,640 EFC.' $1,751,000 Old TD J New TD J PB Depth Released rig II Date IKtnd of rig I Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method J Official reservoir name(s) I Potential test data Well no. Date i Reservoir Producing Interval Oil or gas Test time Production 011 on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The ab~~ correct I Date For form preparation Wf~istribution, ~ ' see Procedures Mann'al, ~fectlon 10, Drilling, Pages 86 an]~'-.~7. ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7355 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-21 2"&5" Raw FDC 11-10-88 4453-7716 2Z-21 2"&5" Porosity FDC 11-10-88 4453-7716 2Z-21 Microlog-GR 1 1 -1 0-88 7050-7746 2 Z- 21 Repeat Formation Tester 1 1 - 1 0 - 88 7264 - 751 7 2Z-21 5" Dual Induction 1 1 -1 0-88 I 000-7742 2Z-21 2" Dual Induction 1 1 -1 0-88 I 000-7742 2Z-21 Formation Microscanner (4-Pad) 11-10-88 7050-7600 2Z-21 Cyberlook 1 1 -1 0-88 7050-7650 2Z-20 2" Dual Induction 11-20-88 3690-7972 2Z-20 5" Dual Induction 11-20-88 3690-7972 2Z-20 Cyberlook 1 1-20-88 7000-7972 2Z-20 2"&5"Raw FDC 11-20-88 3900-7946 2Z-20 2" & 5" Porosity FDC 1 1-20-88 3900-7946 2Z-20 Microlog-GR 1 1-20-88 7000-7964 Receipt Acknowledged: DISTRIBUTION: State of Alaska(+sepia) D&M NSK Drilling L. Johnston(vendor package) Franzen October 31, 1988 Telecopy: (907) 276-7542 I{r Mike ~' = . Wlnzree Area Drilling Engineer ARCO Alaska, Inc. F. O. Box 100360 Anchorase, Alaska 99510-0360 Re~- Kuparuk River Unit 2Z-21 ARCO Alaska, Inc. Permit No. 88-125 Sur. Loc. 2070'FSL, 328'FEL, Sec. 11, TllN, RgE, U~4. Btmho!e Loc. 74'FSL, 2407'FEL, Sec. 2, TllN, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indem~lify you from the probable need to obtain additional permits required by law from other goverr~menta! agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that tile Co~ission may witness testing before drilling below the shoe of the conductor pipe. V~-ry truly.Fpurs, /" : / .?: /.., / / Chaiman of Alaska Oil and Gas Conservation BY ORDER OF THE CO~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental ConservatiOn w/o encl. STATE OF ALASKA ,, ALASK,. ,.)IL AND GAS CONSERVATION t.,,JMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]J Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 109', PAD 73'GLfeet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0i1 Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25646 ALK 2577 4. Location of well 'at surface 7. Unit or property Name 11. Type B~nd(see 20AAC25.025) 2070'FSL, 328'FEL,Sec.11,T11N,R9E,UM Kuparuk River Unit Statewide At top of productive interval(~ target) 8.'Well nu.mber Number 0' FNL, 2360' FEL,Sec. 11 ,T11 N, RgE,UM 2Z-21 #8088-26-27 At total depth 9. Approximate spud date Amount 74 ' FSL,2407 ' FEL,Sec. 2,TI 1N,RgE~UM 11/03/88 $500,000 ,. 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 2Z-5, 2Z-6 7810 'MD 2873' @ TD feet 30' ~ surface feet 2560 6356'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAG 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle 500 Maximum surface 2060 psig At total depth (TVD) 3437 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ~L~" 1~', ~.5# ~-~,n We!d 80 36 36' !!6 !!6' -*200 CF t2-1/4" 9-5/8',3~# .l-55 RT¢. Ab.?? ~,F, qG, /~b. KR ~./zTq, !n0n s,, AS I1.1 & IF-ERW 450 sx £1as.~ f';, 8-1/2" 7" 26# J-55 BTC 7775 35 35' 7810 6356' 200 sx Class G Tail IF-ERW Top of G 500' above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Kuparuk Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sCu°rr~;;TM RECEIVED Intermediate Production OCT/~' ]988 Liner . ~SK~ 0ii & Bas C0~s. Perforation depth: measured ': ", Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program J~ Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge %k) Comm~smon Use Only ~-II# .. . .,_ (TWM) PD:~/O;~7 . Permit Number J APl number J Approv~a~J,d)lte~' /_.,~ J See cover letter ?~, -/z.¢ I 50-- O.ii~ - .2. ! ¢;,¢ J .,'C'/'~//~ J for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required []'-- Yes ,1~i(No ' Hydrogen sulfide measures .~]Yes ~No Directional survey required ~ Yes g No Required working p~re f~J30.~E--'~)C]2M; )i~ 3k/J; [] 5M; [] 10M; [] 15M Other: -/ /_.,.-, //., //'~ ' /' J / / '" //'"/ //'~~ by order of j'~Z ,/-"~ Approved by ~k~,,~ ~ /- k //"~~'/~ Commissioner the commission Date /~.~//~'~ Form 10-401 Rev. 12-1-85 Submit ir triplicate HOR I Z~NTAL PROJECTION SC~ ' I IN. = 1000 FEET ARCO ALASKA, !ne, Pad 2Z, Ne I I No' 21 Rev I ced Propoea I Kuperuk Field. North SI ope. Aleeke 4000 3000 2000 1000 1000 4000 3000 I TD LOCAT I ON' r4' FSL. 24or' FEL SEC- 2. T IIN. RgE TAROET TVD'5859 TUD=?306 DEP'3799 NORTH 3210 WEST 2032 TARGET LOCATION' O' FNL. 2360' FEL SEC- 11. TIIN. RgE WEST-EAST 2000 1000 I I 1000 I )SURFACE SURFACE LOCATION' 2070' FSL, 328' FEL SEC. I1. TIIN. RgE N $2 DEC; 3799' (TO 20 MIN W TARGET) ARCO ALASKA. !no. Pad 2Z, Wel I No= 2t Kuparuk Field, North Rev I sed Proposal Slope, Alaska 0 ~ RKB ELEVATION, 109' '13 1000 _ 2000 _ ;~000 _ 4000 _ 5000 _ 6000 _ 7000 , KOP 3 9 15 21 2; TVD=600 TMD=600 DEP=O BUILD 3 DEe PER 100 FT B/ PERMAFROST TVD=1609 TMD=1663 DEP=288 39 45 EOC TVD=2057 TMD=2258 DEP=676 T/ UGNU SNDS TVD=2219 TMD=2508 DEP=866 T/ W SAK SNDS TVD=2819 TMD=3436 DEP=1575 MAX!HUH AN GLE 49 DEG 45 Hi N K-5 K-12 TVD=3279 TMD=4148 DEP=2118 9 5/8" CSG PT TVD=3479 TMD=4458 DEP=2354 BEGIN ANGLE DROP 48 TVD=3607 TMD=4656 DEP=2506 DROP 1.5 DEO 24 PER I00 FT 39 36 33 30 TVD=4889 TMD=6285 DEP=3490 21 18 15 12 TARGET (EOD) TVD=5859 TMD=7306 ; DEP=3T99 t T~ ZONE C TVD=5861 TMD=7308 DEE=3799 ¥/ ZONE A TVD=6034 TMD=7483 DEP=3830 9/ KUP SNDS TVD=6159 TMD=7610 DEP=3852 ID (LOG PT) TVD=6356 TMD=7810 DEP=3887 TARGET ANGLE 10 DEG i i i 1 000 2000 3000 VERTICAL SECTION i 4000 RECEIVED OCT ]9 8 ~,i~si<a Oil .& Gas Cons, ;Ar~chora9e 300 250 200 150 100 5O 5O lO0 200 150 100 50 0 50 100 700 I I I I I I \ \ 600 \ \ \ \ 500 I I I X1 400 \ X"~I 30C _ 300 _ 250 ~ ~00 ~o ",,800 '-~>X60o I REC OCT '~' ~. ~ I _ 200 _ 150 _ 100 _ 5O tO _ 5O _ 100 200 150 100 50 0 50 100 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. DEGASSER MUD CLEANER SHALE SHAKERS ST STIR STIR TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.7 PV 15-30 5-15 11-16 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.0-10.5 % Solids 10± 4-7 12-15 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After I~3' of departure, there are no well bores within 200' of this proposed well. TWM/ih 10/12/88 In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. KUPARUK RIVER UNIT 20'° DIVERTER SCHEMATIC 6 DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~3N WELD STARTING HEAD 3. FMC DNERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION I ! 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR C-.-.-~S IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 ii 7 ,,iTJ , L_) DI~ el 1::5-5/8= ~ .PSI ~ ~ STACK ACCLMJLATC~ CAPA~IT~ TEST I. O-ECl( ~ FILL ~TCR RESERVOIR TO PR(I3ER LEVEL WITH HYI3RN~IC R. UID. 2. ~ THAT ACO.M.tATCR PRE5~I~[ IS 3i300 P~I WITH 1500 PSI ~TREAM CF T~E RE(t. LATCR, 3. CI~ERVE TIbF., T~EN ~ ALL UNI'F~ SIMJLTAI~[CUSLY AN3 REO:I~ 'r~ TI&~ AN~ PRE.~URE RE14~ININ~ AFTER ALL LIqlTS ARE CL~ WITH O.tN~ING ~ CFF. 4. REC(]~ (IN NIIDC REPiIRTo TI~ ACCEPTABLE LOIM!R LIMIT IS 45 SE~ CLC~II~ TIKE: AM) 1200 PSI REMAINING 13-5/~" BOP STACK TEST I. FILL 8CP STAQ<: A,M) ~ MIINIFCI..D WITH ARCTIC DIESEL. 2- O-ECK THAT ALL LOCI( ~ SCRERS IN P~I.L~F. AD ARE FLLLY RE:TRACTED. SEAT TEST PLUG IN IM[LL~ WITH RULING JT AM) RLN IN L~ SCRE~ 3. CLC*3~__ ~ PREVE~ A~) ~ KILL AN) Q-EKE Lithe VALVES ADJACENT TO BCP STAiX. ALL Oll-ER VALVES AM:) ~ SHCM.D BE OPEN. 4. PRESSLI~ UP TO 250 PSI N43 HOLD F(IR IO MIN. IN.- ~ PRESSLRE TO 3(ID PSI AM) ~I.D F(IR IO B.EED PRE~_~ TO 0 PSl. 5. CPEN ~ P~f%'ENTER AhD ~ KILL AN30-CKE LI~ VALVES. CLOSE TCP PIPE ~ AJ~ HCR VALVES CN KILL AJ~D O-O(E LI~ES. 6. TEST TO 250 PSI /~) 3(/30 PSl AS IN STEP 4. 7. O:NTINJi TEETIN~ ALL VALVE.~ LI~:.S, At~ O-O(ES WITH A 250 PSI LOW A~) 3000 PSl HIGH, TEST AS IN STEP 4. DO M3T PRF_~II~ TF~T /tNY ~ THaT M)T A FULL CLOSING P~BITIVE SEAL CH, E. CN.Y FUI~TIUN IESI O-i~E3 ~.~T CO M3T FI.g. LY 8. CPEN TCP PIPE P. AM~ AN:) CLOSE BOTTOM PIPE RA~. TEST BOTTCM PIPE RAMS TO 250 PSI A~ 3000 PSI. 9. OPEN BOTTOM PIPE ~ BAO( OUT RUN~NG J'r i0. o.o~E BLIND ~ AI~ TEST TO 250 PSI A~D 3(X13 PSI. II, (~PEN RIII~ RAMS AM) R~TRIEVE 'rE~T ~ MN(E MN~IFCLD AI~ LIhES ARE FLI.L CF M3N-FREE'ZING FLUI~ SET ALL VALVES IN ERILLING P(~ITICN. 12- TEST STAJ~PlPE VALVES, K~I l y0 KELLY ~ CRILL PIPE SAFETY VALVE., AN3 I~IDE B~P TO 250 PSI 3000 PSI. 13,. RECCRD TEST IhFCRM~TI(3N CN BL~ PREVENTER 'TEST FORM, SIGN, ~ ~ TO CRILLING SU=ERVIS[3R. 14. PERFCI~ ~TE B(~E TEST AFTER NIPPLING UP AN) Y~EKLY TkI~EAFTER FL/dCTICNM. LY (3:F. RATE B(PE DALLY. ARCO Alaska, Inc. Post Office So. ~00350 Anchorage. Alaska 99510-0360 Teiepnone 907 276 1215 October 4, 1988 Mr. C. V. Chatterton Commissioner State of A1 aska Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' Conductor As-Built Location Plat - 2Z Pad (Wells 18 - 21, 29) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. If you hav~ any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG'hf Encl osu re GRU13/1.2 ARCO Alaska. Inc. is a Subsidiary of AHanticR~c~l(JeldCompan¥ I I I 12 4 VICINITY MAP I'- Imi. i! NOTES: I. COORDINATES ARE /~S.R ZONE 4. ' . . 2. ALL DISTANCES SHOWN ARE TRUE. IJMI~T MERIDIAN. 5. ELEVATIONS ARE B.~M.S.L ~ 4. REFERENCE FIELD BO0~: I 2 5. QG. ELEVATIONS ~OM NSK-~.23.6-Z, rev. I PROTRACTED SECTION CORNER 14j 15 6. HORIZONTAL POSITION B~ED ON ~-Z CONTROL I MONUMENTS PER LHD and ASSOCIATES. ,, "I I Na Y X LATITUDE LONGITUDE F.E.L. E S.L Elev. Elev. 18 '5,966,552.92 529,117.01 70° 19' 10.907" 149° 45'50.250'' 591' IT96' 65.0' 72.6' I 9 5~966~605.96 529,088.86 70° I 9~ I I .430" 149°45' 51.065" 619' 1849' 67.8' ~2.5' 20 5,966~658.89 529,060.86 70°19'! I. 952" 149°45'51.87~'' 647' 1902~ 68.0' 72.6' 21 5,966,827.08 529,579.54 70°19' I 3.594" 149° 45' 42.563" 327' 2069' 66.5' 71.6' . . , ' 258' I 158' 67.5' 7 I. I' 29 5,965,916 58 529 455.15 70019 04.655" 149°45'40.515'' I j "~ ~ .. , J " i I HEREBY CERTI~ THAT I AM PROPERLY ~ ~ REGISTERED AND LICENSED TO PRACTICE ~ ~--~e'e~-- ~x ~ LANO SURV~ING IN THE STATE OF ~."" A-'%~ ~ '~ ALASKA AND THAT THIS PLAT ~" ~ REPRESENTS A LOCATION SURVEY ~~49th~ ~ ~ ~ ~ ~CO MADE BY ME OR UNDER MY ~~~~~'"' ~ D.S. 2-Z DIMENSIONS AND OTHER D~AI~ ~CRAtG L. SAVAGE:'~ WELL CONDUCTOR AS-BUILT ARE CORR E CT AS OF 8/29/88. '~~ .5~8-5 .~~ j j ~ ,,.' M.O'O.J~.'~ j,a~ I -- , i Nc~ Y X LATITUDE LONGITUDE F.E.L. E S.L Elev. Elev. 18 '5,966,552.92. 529,117.01 70° 19' 10.907" 149° 45'50.250'' 591' 1796' 65.0' 72.6' I 9 5,966,605.96 529,088.86 70° I 9' I I .430" 149°45' 51.065" 619' 1849' 67.8' 77_.5' 20 5,966,658.89 52_.9,060.86 70°19'! 1.952" 149°45'51.877" 647' 1902' 68.0' 72.6' 21 5,966,827.08 52.9,379.34 70019' I 3.594" 149° 45_.'42.563'' 327' 2069' 66.5' 71.6' 29 5,965,916.38 529,453. 15 70°19' 04.6:53" 149° 45'40.515'' 258' 1158' 67.5' 71. I' CHEC LZST FOR NEW WE L PErnUTS ITEM APPROVE 'DATE (1) F?,e f?c /o/z /tv 1. (2 th~ 8) (3) Admin FP(. /~:,/~ ~/~z 9. thr 13) lO. (10 and 13) 12. 13. (14 thru 22) (5) BOPE (23 thru 28) Is the permit fee attached .... . ................................. · .... ~ , 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party .................... 2'. ........... ~/~ 8. Can permit be approved before fifteen-day-wait ...................... Lease & Well No. YES NO Does operator have a bond in force .................................. Is a conservation order needed ............... ....................... administratiVe approval needed _ Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ...................... .................. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... 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 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 wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... , Is the drilling fluid program schematic and list of equipment adequate~z~, Are necessary diagrams and descriptions of diverter and BOPE attached.~-~ Does BOPE have sufficient pressure rating - Test to 3~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .... ~'. ............ Is the presence of R2S gas probable ................................. REMARKS (6) OTHER (29 thru 31) (6) Add: Geology: En$~neering: LCS -.,C.~- BEW .... rev: 08/11/88 ~.01i For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. POOL Additional R~arks: INITIAL GEO. UNIT ON/OFF CLASS STATUS AREA NO. SHORE / De . I- o O ~ r Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. CO~PAH¥_~AH.E ; ARCO AbASKA, ZNC, kP! NUMBER I ~0~029~2t877~00 REFERENCE NO ~~007 PAGE: UA:T! OM : CO:M~ENT: ~: b,.~:8 TAPE, ARCO KUPARUK.:2:~ 73007 I bi8 IAPE, ARCO KUPRR.UK 2g~2t, API~5:0'029-2187.7 HEADER **** .O01 · ******************************************************************************** O~PANY NAME: F~ELDt B ROUGHI TATEI PI NU~ER: ~CO AbA&KA. INC, KUPARUK NORTH 8bOP£ AbASKA 50-029~2~877-00 LOCATZONI 20?0' rSb & 328' F~L $£CTIONI 11 TONNSHIPI 11N RANGEI gE PER~ANENT DATUM: ~$b EbEVA~ION; 0 LOG NEASURED FROM RKR 109, ABOVE PERMANENT DATUM 2'DgC'Iggg 14=:02 PAG~Z 2 TYPE FLUID ~N HObEI bSND POLYMER 4, ~3, 5/8" ~ DRILLER DEPTH OF 4452 AND: LOGGER DEPTH OF 44'53 I'30 TOOL NUMBERS: HOE BAY B. BERRY TCM AB 95 REHAR'KSI I ,/2" 8TANoorrs AND 2' HObEFINDER USED ON HATR~X DENSITY = 2,65 G/C3 .FbUiD DENSIty , i,00 G/C3 CNL MATRIX ~ SAND ; HOLE CORRECTION_= CALIPER D-N DATA RECORDED rro~ (775o . 7o~o') & ~5~oo ' 445~') TOOL STRING (BTN. TO TOP) ML-GR-TCCB-A~8' - ' ONE TEFbON-$?ANOOrr RUN ON AMS Flb~ $ USED AS REPEAT DUE TO bARGE PUbb AT OPERATORS - D, BOONE AND r, FOSTER D~TE JOB START'EDI {O-NOV-88 JOB REFERENCE NOI 73007 bDP/ANA{ R, SINE& THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVER~AY$ FIELD PRINTS ***** 14102 TZNKHA~ or province y 0 TABLE TYPE S CURV DEr! P ? CHANNEL, NAME ~,N$ l~-Deep ReslstLvlty - SpQn~aneouS GR ~amm9 RaY DPH~ Dens~YrPorostt~ DDHO De~ DEF! 2'D£C-1988 PAGE~ 4 T¥ T ,01~ sLon ,$ DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB TYPE ~PR Cor)£ VA~U~ t 66 0 1'5 66 68 o 66 DEGF 548t01t 15 000 OO :, , it 1 I DIL D~P?. OPH~;rOC a N~,CHb CNTCsCNL " *2S0 GReMLL 7700,000 I01 563 3 395 078 948 360 000 T~NSeDIL 6140,000 SFLU,DIL SP,DIb "17,328 GReDIb DRHO.FDC 0,044 ~Hoa,roc TENS,CNL 6140,000 NPHX.eCNL RCFT,CNL 542,117 RCNT,C~I, GR,CNL 10 ~R.~LL 91,563 TEN~CHL .250 CALI.MLL -999,250 I~RES IL NL 3 ~HL 6 9 MLL -999 4¸4 3.179 IL~ DIL I EN$ FDC 6140 RLI FDC 8 ~NRA CNb 3 CFTC CNL 633 GR,CHL '999 2 508 0 0 Vet :[ f~ D~PT~ MTE~eMLL D~PT DPHI,FDC G~. RTN~,CNL CNTC~CNL Llst.~na n~ Center ~53,500 750'0 O0 TEN~ DXL 7400 000 000 GR: TEN~ 50 ! 7200 000 1842 t47 750 7100,000 2.i79 19,~46 118,438 4,0~3 18~5,646 493~,000 ~45,6~5 GR~ TENS DXL TENS N~ RCFT ~N.L OR DRHO. FDC GRoC~L GRoMLL 2'DEC-1988 14:02 4548 PHXCNT TENS CALX ~DX~ 5188,000 SFLU.,D:X~ 0,0~! RHOB,FDC 5189~00~ NPHI~CN~ 4J1~320 R.CN~,CN~ 118.438 ?ENS*CHL 'i PAGE= ,880 ,6 ,289 5~ 629 50 Z.883 TNRAeCNL GR,CHL 9,9~4 ~RES,#LL 2.248 518~.000 ,742 '.108 " ,250 -t,866 D D'] D~HI.,~ Ir'DC Gt~ ~DC C~TC Ge FDC RTNR CNL CNTC blStln, 6900 ..90!' 6700 ~0 }0 ~0 ~999 250 6600,000 -999,,250 -999;250 ~99 ~* 0 6500 000 '999 "50 -99~ 250 -9~ 250 ~999 TEN~ DIL D TEN SP,b!L DR~Oe~DC TENS,DIL TEN$.CNb RCFT,CNb ~R,CNL GR,MLL 2'D~C'IgR8 14:02 4904,000 -':}! '999,250 :999,250 .ggg,250 SF~U.DIL ReN{.~NL ?EN&,CHL CALI;HLL PAGEt 7 CNL GR CHL MRES NLL C L; ;DC '999~ -999;~'~ TNR~ NL CFTC ~NL :~99,250 GR CHL ~99;250 ~RES MLL - iO · '9! ;0 '999 0 -ggg -9:99~ O0 D GR,CN~ GR,Mbb ?ENS,DIL OReO,rOe ~CFT,CNL GR,CNb ,,999'250 ;999,25o 999; 250 8r u 3 ~150 NPHI,CNb ~999,250 RC~?,CNb 999,250 ~EN~,CH~ :999,2,50 · CAbI,~b~ .999;250 cr?c GR ~0 ~0 R?NR.CNb CNT~CNb 5700, 560 0 0999 ,0 "999 $$00 0~0 "999 -999 250 -999 250 '999 2~0 ?EN$,DIb 4100,000 RCFT~CNb 8~:c"~ MLb ORNO, rD ,c[,.~ "., {,o TENS,OIL 3860 D 'FDC TENSeCNb -999 RCF?,CNb :999 GR'CNb 999 GR,MbL "999 000 ~o SF~U,OX RCNT, TENS.CHh CALI,~Lb ,mm! -999 250 T R-,CNL -999 250 CFTC;CNL -999 250 GReCHL -999 250 MRE$,MbL .i -99} '999 '999 -999 2 "999 "999 0999 "999 0999 -999 25O 250 25.0 2 0 ~o 14102 PAGE: I0 e~ D1 :L GR,FDC DEFT, GR,rDC MTE~eMLL 5100. 4900 GR GR 4800,000 TENS 2,97! o SP -999,250 GR '999,250 347 $6 4700,000 TEN$,DIL 3i~0,000 SFLU,DXL 3.407 22,842 DRHO*FDC '0;020 RHOB~.PDC ~ ~ 91,500 TENS, CNb 3~0,000 NPHX,CNL 18~9,t85 G.R,CNL 91,500 TENS,CHh .9990250 -999;250 GR,Mbb -999,250 CALI,MLL 999,250 0999,250 CFTC, GR, MRE$: 324~: NL 3,398 3tl. O,.O:O0 9,892 50 2 D'E;C-1986 :[4t~02 PAG~ I ! D D aLL DEP?. G~,FDC C~TC,Ceb 0~ ~999 ~,999 0999 ..999 ,,,999 ~00 ;0 R4 i00 ?EN$,DIb DR~:~:D~bFDc RCF?,CNb GR.CNb -999 ~999 0999 250 -TEN$..CHb 260 CALI'.MLL -999 -999 999 · Nb -99~ ,.250 250 IL#,DIb C LZ,FDC 250 TNRAeCNL 250 CFTC.CNL 000 GR,CHL 250 NRE&~Mbb -999 0999 e999 0999 250 D~PT G~ RTNR CNTC TENS HTE# IL FDC MLL MLL 39 e999 i°° ~999 3500~000 ~999~ 0 '999,~0 ~999,250 ~999,250 g999~250 ~999,250 ~999,250 TEN R~ SP,DI~ TEN$.~CND GR.CN~ RCFT,CNb GR.CN~ -9 -999 RCN~ TE:N~ CAb~ NPH: RCN~ CAbi -999 -999 -999 250 250 ~ILH,DIL TNRA,CNL CFTCoCNL ,MLL .! ~4 250 Yer'i~ica~ 2*D~C-! 988 D FDC FDC D~PT lbo -999 999 e, 999 3000 ~o *999 0 ~0 0 2900,000 0 -999 250 *999 250 -999 0 '999 250 DO TEN b ,, TENS Ri DRHOeFDC TENSeCNL RCFT'eCNL GR,,CNL GReNLL TENS DXL TENS CN RCFT CN~ OR CNL GR Nbb --9 50 Nbb CFTC, CNL 000 GR. CIiL 250 PlRE$.MLL w999 ~9~ *999 '999 ,4 r~er atas~a Co~ R1 ,h CNTC,~NL D~P?,bD b _GR.FDC RTNR,CNb CN?CeCNL - -999 0 0 0 2400 ~0 0999 "999 ~ $0 '9C)9 0999 '999 ~999 ~999 2200,000 ~9 9,~ 0 '999,250 -999,250 ~999,2 ~999~2 0 '"99902 0 D DRHO r C TENS RCFT CNL GR CNb GR TENS,OIL DRHO,FDC TEN&,Nb RCFT,~NL GR,CNL "99 -999 250 w999 250 "999 250 '999,250 -999,250 -999,250 o999,250 Mibb CAbI RHOB#PHI [NbOC Nb RCNT GR,OIb RHOBiFDC NPH!;CNb RCNT,CNL TENS,CHh CALI,~LL PAGE= 2SO -999 MR -999 -999 ~999 999 -.999 t8.35 '999 o SO O0 2$0 CFTC GR NRE& -999,~50 9 , CFTCeCNL ~80'0,000 GR,CHL 999.250 MRE$,MLL 2"'DEC"'i988 14:.02 D~P? DPH! C~?C :L rxL i700 -999 -999 -999 -999 -999 -999 -999 ~0 ?ENS. GR la TEN ~0 ;0 io0 RCFT,CNL GRiCNL GRe~LL TENS,DIL D t, G~,CNL GR;M£,L '9 "999 ,,999 '999 -999 8FbU OIL GR DiL RHOB rOC RCNT EN$ CHh AL! -999 -999 250 ILM,DXL C~TCeCNL 000 GRoCHL 250 NRE$,MLL -999 :9999 9 9 25O '/5 250 $0 $0 $0 Cent, ey I4=02 Dl ~0 GR D I~'LL D~PTe GR,FDC RTNR~CNL C~C,CNL ?~S~L~ *'999 -999,250 -~,~:~o 1100,000 '999, '9~v'1500 "~"~0 DRHOeFDC TEN$.CN~ RCPT,CNL GR~CN~ T£N$.DIL D 8P.DIL RHO'FDC TEN$,C~L RCFTmCNL GR.CNL GR.HLL :,~ RCN! TEN; CAb: GR IL RHOB ~DC NPHX RCNT T~NS HL CALX, MLL 9¸9 ~0 SF ION 2 NAME : EDI~ ,002 ~ICE : Fbi¢ IO~ : 001. A02 : 88/12/ 2 FILE : · THIS DATA HA~ NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS i( Center 2~EC~988 14102 P AGE i · 18 COI~P F~RST: I 7800"' TO VA~U D'EF! TABLE ?¥PE ~ CURV DEPT~ CHANNE~ NAME Tension Density ~oros/ty Delta rno Bulk DensLty _ Near rDC Count Rate Far rDC Count Sate ~aliper T~NS ?aris on NPN! NEUTRON POROSITY 2"DBC-lgg8 '~4~02 PAG~I Ig .. rro~fda cps 548408 CAL! FDH ZN 548408 GeFOH GAP! 548409 T~NS CNH LB 548409 NPH! CNH PU 548408 TNRA~CNH 548408 RTNRC-NH 548408 RCFT CNH CPS 548408 · , 15 0000000 ~ 15 000 15 000 O0 0 iS 000 O0 0 ~5 000 O0 0 15 000 O0 0 ~5 00o O0 0 15 00o OO o 15 o0o OO 0 I 1 1 ! 8 68 68 00:~0000:000 0000000000 .0~ 0 0 O0 o.ooooooo 0000000000 0000000000 000000o000 0000000000 00000000o~ ~AG~: 2O F'DH R IrDH FDH R! 'NH CNTC CNH RTNR, CNH CNT~,CNH RHOBeFDH G~.F'DH RTNR,CNH 213 0?8 s½o 234'~ 97 ';400000 2483 72 256~ 054 7'77 73'00 000 5~ 453 750 2 351 2688 361 GR RCFT, GRa NFDC NS T~rT GR TENS NrDC TENS RCFT GR CNH CtqH CNH tFDH FDH rH FDH FDH CNH CNH CNH FDH ItOH CNH CNH CNH RCNT,CNH 83.000 56920~0 _57800 5692000 946600 72313 5572 000 632 500 5572 000 1 O95 658 5O '/5O P#ieFDHFDC;rDH NPH , NH DPHX ,FDH FFDC, FDH NPHX,CNH ~CNT~CNH 5¸8 ~00 000 6'"/' oFDH T:'N: eFDHNH CFTC, 000i06 5 RHO ~i~TC F H F~H NH 0,024 6,906 DRH0 · FDH CALl ,FDH TNRAoCNH CFTC. CNH 00055 9,64i 1254,487 ,catLon iL, COmpu 2~D~C~198~ 14'~02 PAGE ~ 2 ! ?:20 10 FDH 704~ CNH ;** FILE ?RA ON t :R °002 **$* FILE HEADER NAME t ~DIT ,003 iON t O0)A02 ne, 12/ 2 ,IZE J 1096 : LO ! DATA HAS NOT B~EN DEPTH t~H:IFT~D SCHLUMBERGER LOGS ~NCLUDED W~TH THIS F~LE NAME = EDXT,O03 m <1,2" SAHPLE RATE> t~n~ Center 2'DEC'1.988'14=02 PAGE I 22 DEr! TABLE TYPE DEFI CU~V DATA fORMAT SFECZFZCATXON RECORD ** 8ET TYPE = 64ED ** TYPE REPR CODE vabgE 73 16 66 yeti: 2'DEC-.I. 988 14=02 DEPT. 7769,833 MIMV,MLb 1,604 MNOR,MLb t-SiSHTENoMbL DEPT, 7700.000 MXNV.Mbb 2,889 MNOR,NLb 2,266 HTEN,.WbL DEPT. 76000000 MlNV.Mbb 2.393 MNOReMLb 20089 H~:ENeMLL DEPT. 7500,000 HIN¥,ML5 4,345 MNOR,~bL 3.622 HTEN,Mb.b DEP?. 7400,000 MlNVoMbb 4,626 MNOR~#Lb 30660 HTEN,MbL D~PT. ?30OEO00 MINV,MLb 4.444 MNOR.MLb 60595 H?EN.Mbb D~P?. 7200.000 MINV.~bb 1.645 MNOR,MLL 1.200 HTKN.MbL D~PT, 71000000 MlNV,Mbb 2,113 MNOReMLL i,724 H?EN,MbL DEPT, 7047,333 MINVoMLL 2,675 MNOR.,MLL .2,174 HTEN,MLL END OF ~ATA ~ SSt,SO0 612,625 650,000 642,4~8 639,750 6 2,soo 637.750 630,?S0 '999,250 lcation~Ll. St.l~ Center 2"~EC"! 988 14 ~ 02 TAPE TRA: 2/2 ARCO KUPAR.UK ARCO AUPARUK
