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Home My WebLink About188-130 Ima ect Well History File' ~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(3c~-/~.,~) Well History File Identifier RESCAN DIGITAL DATA o Color items: [] Diskettes. No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: .~, o Other: , NOTES: BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other ~ DATE: /S/ BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE; /SI Scanning Preparation ~ 30 : ,/-.~'"~ + % : TOTAL PAGES /~.~"-_~ BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Production Scanning Stage '1 PAGE COUNT FROM SCANNED FILE: ~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~'/YES ' NO BEVERLY BRE~HERYL MARIA LOWELL DATE;~"',~,"'"/,~,,~ '~ ~ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: Stage 2 BY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) /si ReScanned (individual page [special attention] scanning completed) RESCANNEDBY~REN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked {done) 10/25/02Rev3NOTScanned.wpd C~ C~coPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri117, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ~ ~: <H ; ~, Anchorage, AK 99501 `~ ~ ~''~ `' ~'~ 4'~ `' ` ~ ~ ~ ~' Dear Mr. Dan Seamount: ~ ~E~~w~°EL~ ..~p~~~zo~o ~ ~ ~S (cxts. Gamm-ss~ar ~'aqe ~~~~~~ ~`~ a2. Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). 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 January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped Apri115,16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 2B 2E 2G 2H 2K 2M 2V 2W 2X, u >ii 3S PAD's ell Name PI # TD # Initial top of cement Vol. of cement um ed > Final top of cement ~ ~ Cement top off date > Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/16!2010 26-08 50029210790000 1840260 21" 3.30 7" 1/16!2010 2.5 4/16/2010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF Na Na Na 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF Na 22" n/a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" n/a 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" Na 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" n/a 2.5 4/15/2010 2K-19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" n/a 3.4 4/15/2010 2M-08 50103201840000 1921010 SF Na 17" Na 2.1 4/15/2010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF Na 17" Na 2.5 4/15/2010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4!15/2010 2V-06 50029210540000 1831790 SF n/a 19" Na 7.6 4/16/2010 2V 10 50029213100000 1850480 SF Na 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-o3 50029212740000 1850110 SF Na 37" Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" Na 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" Na 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF n/a 19" n/a 2.5 4/15/2010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF n/a 16" Na 2.1 4/15/2010 3S-O9 50103204320000 2022050 SF Na 45" Na 23 4/17/2010 2Z-19 (PTD 1881300) Failed TIFL 8/23/05, ,,'Lljd to SCP ) S~~j~.~t:'...','22J-.l·..~.·.·..ê~~.~'..·.·.1..$'.&'l·?·?ø)..·~.·~il~~·.·T~B..··.'·~.·/t~<9,?;·.·..~~.~~'d'....tQ...··.·SGp·. "... ~~.~.~:..,~$.~....}>rol>J~~..·)\T~}l..,.,Sµ~~.·..<]..l.?..l,7~b()µ()ç()ph~1~.ip.S.9()ro? ,.. . .. lQAt~: ,yv:~d;24A-\,lg·4Ø05 ..1 O:77:?p ~Q~()O·<' Tom & Jim, 2Z-19 (PTD 1881300) producer failed a TIFL on 8/23/05 and was added to the weekly SCP report. The TIIIO on 8/23/05 was 600/1420/940. The well has been SI since 8/6/05 due to high we. Slickline will either replace the GL V design with new or install DVs. The current GL Vs are 1989 vintage and are suspected to be the leak point. Schematic attached. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 «2Z-19.pdf» Content-Description: 2Z-19.pdf Content-Type: application/octet-stream Content-Encoding: base64 se'p µ:P-f p Ï'"o ,It;Çl( P 'U l4~p"5i 4QVJfS( 'l13 ç'2c ¿)/L. ftr Co ~14 - .. . qtt!)ps; 35àJrS: Z'{¡; ,( ~ r~ß 0/\ J"Re.¡1 ~~/o~ ~.-' ..'.... ., ~C:!\N~~EL SEP 2. 1 2005 1 of 1 9/2/2005 9:32 AM ) '~~~~~'~~n~~:!'~'~~',:~J,~~"~i~:'g~+ 2Z-19 SSSV I ~ (1805-1806, 00:4,000) I ]E:: ~ " 1-" 1 .': ~ Lø :IE j ]1[' ~. Jlr 4- I ~; I .~. .,.. :lIN I .~ ~ PBR (6228-6229, 00:3.500) PKR (6245-6246, 00:6.151) :. ... TUBING (4007-6471, 00:3.500, 10:2.992) PATCH (6424-6438, 00:2,765) w .~ PKR (6444-6445, 00:6.151) ~~ ~ SOS (6471-6472, 00:3.500) Perf (6548-6555) _..... . Perf (6564-6586) Perf (6612-6622) @D AVA Sideguard w/ 5.7 pup AVA w/4.22 pup AVA'RHS-XL' 14' MERLA PERMANENT TBG PATCH set 4/15/1994 OTIS PORTED NIPPLE MILLED OUT TO 2.80" 27/8" ECLIPSE WEATHERFORD PATCH LOWER PACKER WITH MID ELEMENT set 3/4/2005 JET PUMP ASS'Y SIN: PH1114, 12X RATIO, #12 NOZ, #11 THT, K-3 PACKOFF, SPACER (TOL 23'5") - set 3/5/2005 TIW 'SS-BB' Otis 'XN' w/2.75" X 2.635" AVA 2.25" PROFILE API: 500292188200 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 6617 Last Tag Date: 1/31/2005 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubing String - TUBING Size Top 4.000 0 3.500 4007 Perforations Summary Interval TVD 6340 - 6364 5907 - 5928 6370 - 6412 5933 - 5970 6548 - 6555 6089 - 6095 Bottom 4007 6471 Zone C-4 C-3,C-2,C-1 A-5 6555 - 6556 6095 - 6096 A-5 6564 - 6586 6103 - 6122 6612 - 6622 6145 - 6154 Gas Lift MandrelsIValves St MD TVD Man Mfr Man Type A-4 A-3 2 2583 2583 Merla 4 X 1 3 4081 3972 Cameo KBUG 4 4871 4640 Cameo KBUG 5 5242 4956 Cameo KBUG 6 5612 5274 Cameo KBUG 7 5980 5593 Cameo KBUG 8 6187 5773 Cameo MMG-2 Production Mandrels/Valves St MD TVD Man Mfr Man Type 9 6290 5863 Cameo KBUG Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 1805 1805 SSSV 6228 5809 PBR 6245 5824 PKR 6424 5980 PATCH 6430 5986 NIP 6434 5989 PACKER 6434 5989 PUMP 6444 6461 6461 5998 6013 6013 PKR NIP NIPPLE REDUCER TTL SOS AVA 6471 6021 6471 6021 Fish - FISH Depth I 6638 1" DMY Description ::Jo.= ) KRU 2Z-19 Well Type: PROD Orig Completion: 11/30/1988 Last W/O: Ref Log Date: TD: 6868 ftKB Max Hole Angle: 32 deg @ 4200 Angle @ TS: 29 deg @ 6340 Angle @ TO: 27 deg @ 6868 Rev Reason: Pull Slipstop Last Update: 7/28/2005 Top Bottom TVD Wt Grade Thread 0 115 115 62.50 H-40 0 3531 3481 36.00 J-55 0 6854 6361 26.00 J-55 TVD Wt Grade Thread 3909 11.00 J-55 DSS-HTC 6021 9.30 J-55 8RD EUE ABM Status Ft SPF 24 12 42 12 7 12 Type Comment 5" Atlas Omni Kone 5" Atlas Omni Kone 180 deg. phase; 2 1/8" Bi Wire Gun 180 deg. phase; 21/8" Bi Wire Gun 5" Atlas Omni Kone 5" Atlas Om ni Kone Date 2/14/1989 2/14/1989 10/25/1992 22 10 4 10/25/1992 8 2/14/1989 8 2/14/1989 VOD Latch 1.0 BK 1.0 BK 1.0 BK 1.0 BK 1.0 BK 1.0 BK 1.5 RK 1420 1380 1510 o 1455 o o Date Run 2/14/1989 2/14/1989 11/22/1992 10/18/1992 2/14/1989 4/3/1993 2/14/1989 V Mfr V Type Vlv Cmnt Port TRO 0.188 0.188 0.250 0.000 0.250 0.000 0.313 GLV GLV GLV DMY GLV DMY OV V Mfr V Type VOD Latch Port TRO 1.0 BK 0.000 0 Description DMY Date Run 2/28/2001 Vlv Cmnt ID 3.250 3.900 3.000 2.310 2.800 1 .468 0.000 3.250 2.635 2.250 2.992 2.992 I Lost in rathole Comment Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ¡81.-"J..//1F-02 /95 ---01.'L 2T -23 :;¡- 2W-12 I~'f 2.2.f 2Z-19 IfS-/?;tJ 1C-111 )st...,'/,. ~ 1C-117 )..et- /2. r 3F-14 115. :2. 72 2K-07 Q 2Z-12A I 0 7.., 07 ( ( '15- /cf<l 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Description Date NO. 3292 Company: 12/23/04 i(i~., t3.D.._ ..-< _ ~,\) < ÿ:'fq- Alaska Oil & Gas Cons Comm ~ Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL -" Color CD INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG 12/14/04 12/08104 12/15/04 12/04/04 12/06/04 12106/04 12/03/04 12/05/04 12104104 1 1 1 1 1 1 1 1 1 '-" S'GNd ek- t JAbMJ.v-- SCANNEL fJ.PR 1 8 2005 DATE: f3~; Please sign and return on(opy ofthis transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 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 Alaska Oil and Gas ConserVation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Emie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Fieldfclnit/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, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE_ 2Z-01 1830730 100 70; .70 p p OIL 2Z-02 1830800 · 2Z-03 1830850 2Z-04 1830860 2Z-05 1830760 ' 100 - ..70 701 P p OIL 2Z-06 1830770 3700 2000 2000 P P WAG 2Z-07 1830640 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 OIL 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 .1881.300! 100 .'. ~70 65 P p OIL 2Z-20 1881240 100 . 70 100 p p. . OIL 2Z-21 1881250 100 70 70 p p OIL 2Z-22 1941470 - 2Z-23 1950100 2Z-29 1881290 100 70 ' 70 p p OIL · 2Z,WS 1 1851580' · . Wells: 12 Components: 24 Failures: 2 Failure Rate: 8.3% O90 var Remarks: Surface Safety Valves On wells 7 & 10 had slow leaks when pressure tested. They ar serviced and retested by the operator. , ~,.,,,,,,, paoe 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 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 ALASKA OIL AND GAS CONSERVATION COMMI;~.SION REPORT OF sUNDRY WELL OPERATIONS 1. Operations Performed: OPeration ShutdOwn stimulate X Plugging Perforate _ ' l~'//! Pull tubing Alter casing Repair well Other /~/'~,~' 1 5. Type of Well: elevation (DF or KB) /~, 2. 'Name of Operator I 6. Datum Development X I Exploratory __ RKB 10~)' 7. Unit or Property name ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Service 41 Location of well at surface 1850' FSL, 619' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 2530' FSL, 2080' FEL, Sec. 11, T11N, R9E, UM At effective depth 2617' FSL, 2310' FEL, Sec. 11, T11N, R9E, UM At total depth 2635' FSL, 2351' FEL, Sec. 11, T11N, R9E, UM Stratigraphic 1'21 PreSent well condition summary Total Depth: measured true vertical 6 8 6 8' feet Plugs (measured) 6373' feet feet Kuparuk River Unit 8. Well number 2Z-19 9. Permit number/approval number 8-130 10. APl number 50-029-21882 11. Field/Pool Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 6 7 73' true vertical 6289' Length Size 80' 16" 3496' 9 5/8" 6821 ' 7" feet Junk (measured) feet Cemented Measured depth True vertical depth 1 9 8 sx AS II 1 1 5 1 1 5 750 sxAS III & 3531' 3483' 350 SX CLASS G-TOP JOB w/132 T¢~ 2 2 5 sx Class G 6 8 5 4' ' measured 6340'-6364', 6370'-641 2', true vertical 5911'-5932', 5937'-5973', Tubing (size, grade, and measured depth) 4"3 1/2", J-55, tbg EIVE[ 6612'-6622' d UL 6149'-6158' Alas/(a 0il & Gas Cons, w/tail @ 6471' Anchorage Packers and SSSV (type and measured depth) AVA 'RHS-XL' PKR @ 6245', TIW 'SS-BB' PKR @ 6444', AVA 'Sideguard' SSSV @ 1805' 13. Stimulation or cement squeeze summary 'A' SAND FRACTURE STIMULATION Intervals treated (measured) 6 61 2- 6 622 Treatment description including volumes used and final pressure SEE ATTACHED SUMMARY 14. Pressure Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Prior to well operation 0 0 0 Subsequent to operation 0 0 0 15. Attachmehts 16. status of well cla'ssification as: Copies of Logs and Surveys run__ Water Injector __ Daily Report of Well Operations X Oil X Gas Suspended 171 I hereby certify that the fOregoir~g is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 28O 280 Service SUBMIT IN DUPLICATE issi0n KUPARUK STIMULATION SUMMARY CONTRACTOR: ARCO REP: SANO pI~RF I NTERUAL COMPANY TYPE DENSITY PHASING ACTUAL G~'-~ UOLUME TIME FLLIlO ST6/CLIM KUPARUK OPERATIONS ENGINEERING WELL FiLE OESIGN RATE PRESSURE PROP. PROP. ANN. UOLUME Mia ,L,]~L.T,~J~ MESH ~ WT. ~ STG,'CUM EFF. PRO: POST WHTPR: _~Z / ~z~o ISIP: Z.~'~'/ /.Z~ LEAK OFF: 5 MIN. NOTES: EFF. SLURRY: ~'-~,~-~-~ EFF. PROP: ~ '~ ~-~ ,,,c,.,,: .~,..~~EIV~ ,,,,,u,,: t~~ TB6.FRIC: t i~ FLUIDTEMP: PERF FRIC:/ 4at / ~JUL ~ ~ ~9~ FLUID UlSC; ~nchorago ' , STATE OF ~ ~ ~ OIL AND GAS CONSERVATION ~ON FIEPOFIT OF SUNDFIY WELL OPEFIATION$ 1. Operation Performed: Pull tubing . 2. Name of Operator Operation Shutdown._. Stimulate X , Alter casing Repair well 5. Type of Well: Development X Exploratory ._ Stratigraphic ._ Senace ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Locetion of well at surface measured 6868' fe et Plugs (measured) true vertical 6373' feet Plugging .__. Perforate _. Other 6. Datum elevation (DF or KB) feet 1850' FSL, 619' FEL, Sec. 11, T11N, R9E, UM At top of productive Interval 2530' FSL, 2080' FEL, Sec. 11, T11N, RgE, UM At effective depth 2617' FSL, 2310' FEL, Sec. 11, T11N, R9E, UM At total depth 2635' FSL~ 2351' FELr Sec. 11~ T11Nr R9E~ UM 12. Present well condition summary Total Depth: 109' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number' 2Z-19 9. Permit number/approval number 88-130 10. APl number S0-029-21882 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 6773' feet Junk (measured) true vertical 6289' feet Caang Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3496' 9-5/8" 6821 ' 7" measured 6340'-6364', 6370'-6412', true vertical 5911'-5932', 5937'-5973', Tubing (size, grade, and measured depth) 4" & 3.5", 9.3#, J55 tbg w/ tail @ 6471' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 198 Sx AS II 1 1 5' 1 1 5' 750 Sx AS III & 3531' 3483' 350 Sx Class G-Top Job w/132 sx AS I 225 SxClass G 6854' 6360' . 6093'-6100', 6149'-615S' AVA 'RHS-XL' pkr @ 6245'r TIW 'SS-BB' pkr (~ 6444' & AVA Sideguard SSSV ~ 1805' 13. Stimulation or cement squeeze summary Fracture Stimulation Intervals treated (measured) Kuparuk 'A' Sands Treatment description including volumes used and final pressure 1923 bbls water/57 bbls Diesel/105 bbls Additives/254r581# of proppant/FTP=5600 psi Reoresentative Daily Average Production or Ip!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 500 200 Subsequent to operation 2 7 2 1 9 0 0 1 3 0 7 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run-.. Water Injector m Daily Report of Well Operations X Oil X Gas Suspended i7. I hereby certify that the foregoing is true and correct to the best of my knowledge. 172 Signed Form 10-404 Rev 00/12/00 Title ~' ~ 3 I' A e e r SUBMIT IN DUPLICATE ARCO Alaska, Subsidta~ of Atlantic Richfield Compan-y- +WELL JNTRACTOR Do.It REMARKS FIELD-DISTRICT- STATE OPERATION AY REPORT TIME oqoo WELL SERVICE REPORT I DATE 1~o7 t5o5 .... 15o~1 1650 ibsb, i7oL 2'3~g ?~, ~l,c'k~,,~,,.. 2.5' 5,P"1 2H I0 f M,,,, XL. oW 5t7 8PR ~/7oo ?~', f. I 2610 ?% zoo S7 ]-'] CHECK'THIS BLOCK IF SUMMARY CONTINUED ON BACK miles Wind Vel. knots ]Signed ,~~__~, ~ o, 0 RIG IN i, /~. ,SKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS [~ SUSPENDED r~ ABANDONED r'~ SERVICE r'~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 88-130 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21882 4 Location of well at surface !i!~~~i ---- 9 Unit or Lease Name 1850' FSL, 619' FEL, SEC 11, T11N, R9E UM ~~-~' KUPARUK RIVER UNIT At Top Producing Interval I' VE~]'FIE'D 10 Well Number 2502' FSL, 2136' FEL, SEC 11,T11N, RgE UM !SuH,_.~j~_, 2Z-lg At Total Depth, J!. i~....~ ,t 11 Field and Pool 2587' FSL, 2369' FEL, SEC 11, T11N, RgE UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF. etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 109'I ADL: 25646 12 Date SpuddedNov 22 1989 13 Date T.D. ReachedNov 29 1989 14 Date Comp., Susp. or Aband.~ J15 water Depth' if °ffsh°reNA feet MSL116 N°' °f c°mpleti°ns, 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost ;6868' MD & 6377' TVD 6767' MD & 6287' TVD YES [~ NO r~ 1805, feet MD 1400' (approximate) 22 Type Electric or Other Logs Run DIL,SFL, GR,CAL,SP,FDC,CNL, PET,GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO ri'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 198 SX AS III 9 5/8" 36# J-55 SURF 3531' 12-1/4" 1750 SX AS III & 350 SX CLASS G 7" 26# J-55 SURF 6854' 8-1/2" 225 SX CLASS G & 200 SX AS 1 , 24 Perforations open to Production (MD+TVD of Top and Bottom and i25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6340'-6364' MD, 5" W/12 SPF 5911'- 5932' TVD 4"/3-1/2", J-55 6471' 6444' 6370' - 6412' MD. 5" W/12 SPF 5937' - 5973' TVD 6612'- 6622' MD, 5" W/8 SPF 6141'- 6158' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, .ETC 6564' - 6586' MD, 2-1/8" W/8 SPF 6107' _ 6129' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ... 6548' - 6555' MD, 2-1/8" W/8 SPF 6093' - 6099' TVD 6612' - 6622' 34~348 lbs 16/20 CARBOLITE 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc,) .~ I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,,~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,,~ 28 . CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ,'VIAR 1 6 t9.90 .4la,,ka Oil & {]as Cons.. Commiss[c Anchora~a ,,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ ''~ '"' ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 6340' 5911' NA BOTTOM KUPARUK C 6422' 5982' TOP KUPARUK A 6539' 6085' BOTTOM KUPARUK A 6686' 6217' ., · : · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion 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 pedinent 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 7/15/89 2Z-19 Frac Kuparuk "A" sand perfs 6612'-6622' in nine stages per procedure dated 5/12/89 as follows: Pmp 35 bbls Bora Gel Pre-Pad @ 10-15-20 BPM, 3400-4290 psi Stage 1: Pap 150 bbls Bora Gel pre-pad @ 9-16-22 BPM, 3600-4280-3615 psi Stage 2: 150 bbls Bora Gel pad @ 15-20 BPM, 4100-3750 psi .Stage 3: 18.5 bbls Bora Gel v/2 ppg, 16/20 Carbolite, 20 BPM, 3750-3620 psi Stage 4: 17 bbls Bora Gel w/4 ppg, 16/20 Carbolite @ 20 BPM, 3620-3510 psi Stage 5: 20 bbls Bora Gel v/6 ppg, 16/20 Carbolite @ 20 BPM, 3510-3300 psi Stage 6: 22 bbls Bora Gel w/8 ppg, 16/20 Carbolite @ 20 BPM, 3300-3050 psi Stage 7: 24 bbls Bora Gel v/10 ppg, 16/20 Carbolite @ 20 BPM, 3050-2767 psi Stage 8: 15 bbls Bora Gel w/12 ppg, 16/20 Carbolite @ 20 BPM, 2767-2854 psi Stage 9: 72 bbls slick diesel flush @ 20 BPM, 2854-3784 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 542 bbls wtr 34,348# 16/20 Carbolite 652# 16/20 Carbolite 3500 psi RECEIVED APR ] o ]99 Alas~.Oil,& Gas Cons. Commission ', Anchoraga Dr~perviso~ ORIGINAL December 15, 1988 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re- Boss Gyroscopic Survey Job No. AK-BO-80135 Well: 2Z-19 Field: Kuparuk Survey Date: December 2, 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. Enclosure Sincerely, NL SPERRY-SUN, INC. Ken Broussard RECEIVED DiStrict Manager NL Sperry-SunlNL Industries, Inc. P.O. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907) 522-1737 SPERRY=SUN~~6U~iV~.Y~~MP-ANY ARCO ALASKA, -2:~-'" 1.9 ~ .... KUPARUK ALASKA INC. ANCHORAGE ALASKA ~OMPUTATiPJ~TE DECEMBER 6, 1988 'VERTICAL SECTION CALCULATED ALONG CLOSURE TR..WE SUB-_~A~ COUR~ ~QL~R~ .ASURED VERTICAL VERTICAL INCLINATION DIRECTION TH DEPTH DEPTH DEG M I N DEGREES .... SEVERITY DEG/100 0 O. O0 - 109.00' 0 0 N O. OE .SAGE I DATE OF SURVEY DECEMBER 2, 1988 B..~Q~__C~_YI~ 0 ~.OP.! C~8VEY= JOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = 109.00 FT. OPERAT_OR-HARG~ __TP_Tf_L_ RECTANGULAR COORD I NATES NORTH/SOUTH EAST/WEST O. O0 0. O0 0. O0 VERTICAL SECTION O. O0 300 400 5C)0 600 700 8O0 900 1000 1100 1200 1300 15£)0 1/,00 1700 , .. 1800 1900 ......... 2~ 2100 2200 2300 2400 2500 2550 2600 2650 2700 100 100.00 -9.00 200 ........... 300.00 191.00 400.00 291.00 50C).00 391.00 600.00 491.00 699.99 590.99 0 899.96 790.96 1 999.94 890.94 1 1£)99.92 990.92 __0 --1199.91 1090.91 1299.90 1190.90 1399.89 1499.89 1390.89 1599.88 1490.88 1699.._6_'7 1590.87 1799.85 1690.85 1899.83 1790.83 19~.~._ 1~~0 .... 2099.76 1990.76 2199.72 2090.72 C) 13 S 32.30 E 0.22 0.16 S 0.10 E 0 15 S 51.50 E 0.09 0.!,6 S 0.38 E .......... 0 .... i~; ..... S- :~8~m9- E ........ 0:-12 ............ O:/~"S ............ O':-'7g-E 0 9 S 82.69 E 0.09 0.70 S 1.11 E 0 11 S 32.10 E ~).__1 ~__ C)? .8.~_.. !~! 1. ?.4__E 0 24 S 18.19 E 0.22 1.33 ~ 1.54 E -0.16 -0.53 -0.95 -1.3(3 -1.57 -1.93 34 S 13.69 E ....... 5'_2 ........... ~ .___9 _._37._E 16 s 8. OE 26 S 10.19 E 48 S 7.30 E 0 43 S 12.30 E 0.18 2.15 S O. 31 ..................... 3...40 .S ............... 0.40 5.26 S O. 17 7.61 S o. 63 9.,.~_4_6 O, 11 10.86 $ 2399.62 2290.62 2499.57 2390.57 254~..~6__ 244_0.,.~ 2599.52 2490.52 2649.28 2540.28 2698~7 o=oo ~ ...... .... ~ ~I ~1 ~ / :..... 0 40 . S 15.39 E 0.07 12.04 S 0 39 S 1__4,_!2....E ................ O, 03 ............. 1'.3..,..1.~ _6 0 41 S 18.69 E 0.C)7 14.27 S 0 44 S 26.19 E 0.11 15.42 S · ~/.. z..? 0 __4.9 . $j:.1,60_1~ .......... Q,_12: .,-~.,-~- ·------- 1 7 S 44.30 E 0.37 17.94 S I 17 S 47.60 E 0.18 19.40 S _! __36 ~ . $__551~_80 K ........... 0.._'~. ...... 21..3).3.__~_ 1 :33 S 54.69 E O. 1C) 22.67 S I 42 S 50.19 E 0.21 24.41 S 1 _4_7 .... S 50,.. 0 _ E Q~.~:!~ ............ ___~6,i. 37'____~_____________ '1 55 S 49.60 E 0.14 28.46 S I 34 S 52.50 E 0.37 30.3';' $ 3 54 N 35.80 W 7.33 29.10 S 7 8 N 46. 0 W 6.73 25.56 S 1.77 E -2.46 2.01.. E ............... 7_~.- 17 .. 2.29 E -4.16 2.67 E -5.42 2,_.__9~_ E... -6.46 __ 3.21 E -7.17 3.50 E -7.90 .3,_7'~.1g. -.8.,.6o _ · 4.12 E -9.34 4.60 E -10.23 5,JZ6._ H_ , . - li..~1 6.3:3 E -12.81 7.85 E -14.78 _?-.7.. ;~ _ E --_ 1 ~ 11.9:3 E -19.85 14.2:3 E -22.60 _16...SZ_E_. -...,5.52 , 19.05 E -28.62 21.42 E -31.55 22~.QO_ E_ - ~__32..A~ 21.03 E -30.68 17.79 E -26.33 ll_~=___E - 18.97 ,S ARCO ALASKA 2Z-19 KUPARUK ALASKA ANCHORAGE ALASKA INC. .......... COMPUT~T_I ON_ D~TE DECEMBER 6, 1988 PAGI= ~ VERTICAL SECTION CALCULATED ALONG CLOSURE COURSE DIRECTION DEGREES DATE OF SURVEY DECEMBER 2, 1988 ...... BO~S_ O]~RO~JZ:OP~ I C SURVEY .... dOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = 109.00 FT. TRUE__ SUB-SEA COUR__S_E MEASURED VERT I CAL VERT I CAL I NCL I NAT I ON "TH DEPTH DEPTH DEG MIN N 51.50 W N 53, 80 W N 55.10 W 2750 2747.55 2638.55 13 25 2800 2796.03 2687.03 14 50 2900 2892.59 2783.59 15 19 DQG_-LE.G'.' ....... SEVERITY DEG/1 O0 __T_QT~IL._. RECTANGULAR cooRD INAT~'~-----~ERT I CAL NORTH/SOUTH EAST/WEST SECTION 5.37 13.76 S 3.88 E -8.92 3.03 6.36 S 5.84 W 2.91 0.60 8.77 N 27.01W 28,30 3000 2988.76 2879.76 16 26 ~100 3084.29 2975.29 17 55 3200 3178.69 3069.69 2£) 36 N 57.89 W N 59.50 W N61. OW 3300 3271,97 3162.97 21 37 3400 3364.24 3255.24 23 42 3500 3455.93 3346.93 23 19 3600 3547.99 3438.99 22 38 3700 3639.84 3530.84 23 54 3800 3730.31 3621.31 26 31 N 60.80 W N60. OW N 60.60 W N 62.89 W N 63.60 W N 65.69 W 3900 3819,70 3710.70 4000 3907.~Z~ 3798.23 4100 ~~ ...... 3~3.~1.. 4200 4076.99 3967.99 4300' 4161.45 4052.45 26 42 N 66.80 W 31 5 N 65.39 W 32 ...... ..5.._ ~' _N_6.5_,.I?_H ................... 32 23 N 65.39 W 32 21 N 65.50 W 1.35 23.85 N 1.55 39.18 N 2.72 55.52 N 1.02 73.03 N 2.11 92.07 N 0.,__45 ............. .~_.I., .1..,~_N ...... 49.84 W 55.19 75.08 W 84.41 103.73 W 117,15 ._ 135.20 W 152,95 168.69 W 191,21 1.13 130.34 N 237.74 W 269.70 1.30 148.11N 273.02 W 309.12 2,7_7 _ 166.32 N ~11.5~_~ 351,68 0.52 184.36 N 352.55 W 396.48 4.43 203.97 N 396.70 W 444.79 L~I .... ~Z~6.,~ ...... '_444.._2.~_W. 497.14 0.32 248.16 N 492.76 W 550.46 0.06 270.40 N 541.46 W 603.~ 4400 4245.92 4136.92 32 21 4500 4330.38 4221.38 32 22 4600 4414.89 4305.89 32 l& .......... ~700 4499.46 4390, 46 32 1 ~.__ 4800 4584.11 4475.11 32 6 4900 4668.84 4559.84 32 2 ._Ouo 4753 68 4644.68 31 52 ~ 6~,.60 W_ . 0.06 . 2~2.56 N ~O.!~_.W 657.49 -. N 65.80 W 0.11 314.58 N 638.98 W 711.00 N 6~.39 W 0.34 336.25 N 687.85 W 764.46 N 67. 0 W 0.21 378.42 N 785.77 W 871.07 N 67.10 W 0.08 39~.12 N 834.66 W 924.16 .... N.66,_8'LW ............ 0,!55 .............. 4!?,_SCL.N .................... ~8~.~__H ......... 977,_09., 5100 4838,64 4729.64 31 47 N 66.89 W 0.09 440.50 N 931.91 W 1029.84 5200 4923.71 4814.71 31 38 N 66.89 W 0.15 461.12 N 980.26 W 1082.41 ........ ~CJ~ ....... ~07,..31 ............. 4~0- 31 30 36 N 6~.,.~_.~ ............k~ ......... ~O~62_N.~lQ28._12.._W 1134.08 _ 5400 5095.45 4986.45 30 27 N 69.10 W 0.21 498.86 N 1075.53 W 1184.85 5500 5181.68 5072.68 30 23 N 69.69 W 0.31 516.68 N 11~'~.94 W 1235.46 5600 526Z~5 51~..~ . ~P__ ~ ' N 7~,._._(:LH O. 2~. ~;i4.~.Z~.._N 1 tZo2~Z_.w ~ 2@6.14 ARCO ALASKA, 2Z-19 KUPARUK ALASKA INC. S~'ERRY._..~Lm_.m.m~ NELL SUR_._VEY ING COMPANY ANCHORAGE ALASKA COM.P. UTATION_D~TE DECEMBER 6, 1988 VERTICAL SECTION CALCULATED ALONG CLOSURE PAGE 3 DATE OF SURVEY DECEMBER 2, 1988 BOSS dOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = 109.00 FT. OPERATOR-HARGER __ TRUE ..... .S_,U.B_-_~E_A ..... COURSE__ F ~SLIRED VERTICAL VERTICAL INCLINATION TH. DEPTH DEPTH DEG MIN COURSE DOG-LEG TOTals_ DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEGREES DEG/IO0 NORTH/SOLITH EAST/WEST SECTION 5700 5354.14 5245.14 30 7 5800 5440.70 5331.70 29 58 5900 5527.42 5418.42 29 45 6000 5614.29 5505.29 29 37 6100 5701.29 5592.29 29 28 6200 5788.33 5<579.33 29 29 6300 5875,59 57<56,59 28 59 N 70.1.g W 0.47 551.3<5 N 1218.08 W 1336.60 N 70. <59 W O. 29 5<58.12 N 12<55.27 W 138<5.59 N...7.1 ._.___CL._W ......... ~ ._.~? ........ _5.:.3 4__.._.4. 5__ N ..... 1. L31'.2..__'~ !__~ .......... 1_ Z~3~ N 71.50 W 0.28 &00.37 N 1359.20 W N 71.80 W 0.20 615.90 N 1406.01 W N 71.<50 W 0.10 631.35 N 1452.74 W N 71.39 W 0.51 64<5.85 N 1499.0<5 W &400 5962.98 5853.98 29 10 N 71.17 W 0.21 &62,44 N 1545,11 W 0.84 <594.26 N 1635.88 W 1.36 710.32 N 1679.07 W 0.48 718.46 N 1700.13 W 0.00 72~.71N 1721.18 W 0.00 737.~3 N 1749.80 W <5600 <5138.32 602~.32 28 4 N 70.10 W 6700 6227.07 6118.07 2<5 48 N 69.10 W 6750 6271.68 6162.68 26 52 N 68.60 W 6800 6316.28 6207.28 2<5 52 N <58.60 W 6868 ~376.93 6267.93 . 2<5 52 N 68.60 W' -- 8 ~IN. WEST Al-" MD = ~:3<58 HORIZONTAL DISPLACEMENT = 1899.04 FEET AT NORTH <57 DEG. 1485.68 1534.85 1583.91 163~.61 1<581.09 17~9_.._51 1777.10 1823.14 1845.70 1868.30 1899.04 ....... _TH_E. CALC:ULATION_...pROCEDURES ARE BASED ARCO ALASKA, INC. 2Z-19 KUPARUK ALASKA ANCHORAGE ALASKA DATE OF SURVEY DECEMBER 2~ 1988 COMPUTAT~.~N ~ATE .... DECEMBER 6, 1988 dOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = 109.00 FT. OPESATOR-HAS~8 ..... INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE ~SURED VERTICAL =PTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPT_H. .... N_O~..T._H._/_.S_O_Ld~H EAST_/.W.E_.S__T .....[!_I.F.._F'.E.R_E.N.~.E_ ...... c_.'.C.!~E._C_.'.T__I L--iN____ 0 0.00 -109,00 0.00 0,00 0.00 1000 999.94 890.94 7.61 S 2.67 E 0.06 0.06 2000 1999.80 1890.80 21.03 S 9.78 E 0.20 0.14 3000 2988.76 2879.76 23.85 N 49.84 W 11.24 11.0.3 4000 3907 23 3798 23 203 97 N 396.70 W 92.77 '~' =~ 5000 4753,68 464468. 419. 80 N 883.39 W 246,32 153.==~,~, 6000 5614.29 5505.29 600.37 N 1359,20 W 385,71 139.39 ..... ~8~ 637~.~?~ ...... _6~7.93 __737.93 N 1749.80 W 47!~.~7 ....... ~~ ...... THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADILIS OF CURVATURE METHOD. ARCO ALASKA, .2Z-19 KUPARUK ALASKA INC. SPEF~RY-SUN WELL SURV~Y_!NO_~E'fi[iY ANCHORAGE ALASKA C 0 ~P U__Tfi_l'_I ~1~ _DATE DECEMBER 6, 1988 PAGE 5 . DATE OF SURVEY DECEMBER 2, 1988 dOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = OP_E_~R.ATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 109.00 FT. TRUE " ~SURED VERTICAL PTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH__EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 0.00 109 109,00 209 209.00 309 309.00 409 409.00 509 509.00 609 609,00 709 709,00 809 809,00. 909 909,00 1009 1009.00 1109 1209 1309 1409 1509 -109. O0 O. O0 O. O0 O. O0 OI O0 O119 .S O. 12 E 0.00 100.00 0.48 S 0.41 E 0.00 200.00 0.65 S 0.80 E 0.00 300.00 0.70 S 1.14 E 0.00 400.00 0.88 S 1.36. E 0.00 500.00 1.39 S 1.56. E 0.01 6~0:~!0 2.24 S__ 1 -_7? E ..... Q...Q_I ................ 700.00 3.54 S 2.03 E 0.02 800.00 5.46. S 2.32 E 0.04 900.00 7.83 S 2,71 E 0,07. : 9.~7 S 3.00 E 0.09 10.97 S' 3.'23 E 0.09 !.~. 1.4S ~_~ ~3~__.. E ........0....l.P. .................. 1:3.25 S :3,81 E 0.11 0.01 14.38 S 4.16. E 0.11 0.01 1109,00 1000,00 1209.00 :1100.00 13~?.,.00 ..... ~2~0,.00 1409.00 1300.00 1509.00 1400.00 1609 1 O, O0 O. O0 O. O0 O, O0 .. O. O0 O, O0 O, O0 0.01 O. 02 o. o:~. O. 02 0.01 1709 1 1809 1 609.00 1500.00 709,00 ~-1600,00 809,00 ~1700,00 ! 5.53,,, 1~,.7:~ s 5.33 E o. 13 18. o7 s 6.46 e 0.15 0,01 O. 02 ARCO ALASKA, 2Z-19 KLIPARUK INC. ALASKA ANCHORAGE ALASKA COMPUTAT I DECEMBER 6, 1988 DATE OF SURVEY DECEMBER 2, 1988 dOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 109.00 FT. TRUE ~SURED VERTICAL D~PTH. ................ [:_!.E_PT_H. ........ SUB-SEA VERTICAL DEPTH 1909 1909.00 1800.00 2009 2009.00 1900.00 -- ....... ~109 2109.00 2000.00 2209 2209.00 2100.00 2309 2309.00 2200.00 TOTAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL ...-_'.. __E'_~T rlIFFERENCE CORRECTION NORTH/SOUTH EAsT/W ~. ................... · ........· ......,--.. 19.54 S 8.01 E 0.17 0.02 21.19 $ 9.98_E o. 20 22.82 S 12.19 E 0.24 0.04 24.59 S 14.44 E 0.28 0.04 26.55 S 16.80 E 0.33 0.05 2409 2409.00 2509 2509.00 2609 2710 2709.00 2813 2809.00 2917 2909.00 3021 3009,00 3126 3109.00 2300.00 '2400,00 2500.00 2600.00 2700.00 2800.00 28.&7 S 19.29 E 30.55 $ 21.63 E :28.52 S 20.55 E 19 06 S 10.4(.') E 4.33 S 8.61 W 11.34 N 30.70 W 2900. O0 3000. O0 27.02 N 54.90 W · 43.30 N .... 82.15 W 3232 3209.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3339 3309.00 3448 3409.00 3557 3509.00 3666 3609,00 3776 3709.00 61 , 04__N 113.69. W 80.19 N 148.01 W 101.87 N 185.70 W 122, 91, N . 2~-_'~3..26W 142.03 N 260.78 W 161.97 N 302.01 W 0.38 0.05 0.43 0.05 1.54 1.03 4.41 2.88 8~02 12.10 4.08 17.02 4,93 23...~8.... . ..... 6.36 30.83 7.45 39.88 9.05 48,75 8.87 57.26 8.51 67.26 10.00 ARCO ALASKA, 2Z-19 KUPARUK ALASKA INC. ~P~..BRY-SUN _WELL SURVEY I EICLI~.:QLIP. t~ti~ ........ ANCHORAGE ALASKA PAGE 7 DATE OF SURVEY DECEMBER 2, 1988 COMPUT~_T_~N D~.'llF~ DECEMBER 6, 1988 ,.lOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = 109.00 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~ SURED DEPTH TRUE VERTICAL DEPTH SUB-SEA TOTAL VERT I CAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST D I VERTICAL COR~E_C_T ~I ON__ 3888 4002 3809.00 3700.00 182.24 N 3909.00 3800.00 204.42 N 4119 4237 4356 4009.00 3900.00 230.23 N 4109.00 4000.00 256.61 N 4209.00 4100.00 282.89 N 347, 60 W 79.02 11.76 397.67 W 93.07 ._1_ ,4_ _._(_)5 .......... 453.74 W 110. 58 17.52 511.22 W 128.91 18.32 568.88 W 147.29 18.39 4474 4~ 4711 4309,00 4200.00 309,03 N 4409,00 4300,00 334.76 N 4509,00 4400,00 359.86 N 4609.00 4500.00 384.52 N 4709.00 4600.00 408.90 N 4809,00 4700.00 433.29 N 4829 4947 5065 626.61 W 165.68 18.39 · 684,45 W 184.03 18.35 742.34 W 202.28__ 18.~5 800.15 W 220.'~ ~ 18.11 857.80 W 238.37 17.98 915.01W 256.13 17.76 5182 4909.00 4800,00 457.57 N 971,93 W 273.73 17.60 5299 5009.00 5415 5109.00 5531 5209.00 5647 5309.00 5763 5409.00 5878 5509.00 5993 5609.00 4~00.00: ':".:~i. '480.55~N 1027.94:W __5P00,'00 ~ . ::501., 7 !:1N :i.~i i~ ~:.:1082,97.~_ W_ 5100.00 522.24 N 1137.97 W 5200.00 542.46 N 1193.39 W 5300. O0. ~.:_5.62.07. N ..... ..... 1248.01: W 5400. O0 ~ 581 . 03 N · 1302.35 W 5500. O0 : 599.42~ N 1356.35 W 290.64 16.91 .. 322.68 15.96 338.78 16.10 354~1. 1.15.62 .... 36~.79 15'38 384.91 15.12 ARCO ALASKA, INC. 2Z-19 KUPARUK ALASKA ANCHORAGE ALASKA CO_M.~U~T I ON_PfiTE DECEMBER 6, 1988 . PAGE. 8~ ~ DATE OF SURVEY DECEMBER 2, 1988 dOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = 109.00 FT. ._~JP~RATOR-_H~OER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH . TRUE SUB-SEA ,SURED. VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL REC. TANOULAR COORDINATES MD-TVD NQ_R_TH/SOUTH EAST/WEST DIFF~_R_~CE VERTICAL C.'Ofi~LTiTION ~108 5709.00 5600.00 6223 580~.00 5700.00 6338 5909.00 5800.00 6452 6009.00 5900.00 6566 6109.00 6000.00 617.26 N 635.04 N 1410.15 W 399.86 1463.83 W 414.74 · ~ 1516.61 W 429.20 1569.39 W 443.69 1621.17 W 457.77 652.76 N 670.73 N 688.94 N 14.95 14.88 14.45 14.50 14.07 6679 6209,00 6100,00 6791 6309.00 6200.00 ' 6868 6376.93 6267.93 707.06 N 1670.55 W 725.36 N 1717.74 W 737.93 N. 1749~80 W THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS; OF CURVATURE) POINTS 470.76 12.99 482.84 12.08 ARCO ALASKA, INC. ._L2.Z- 19 SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE PAGE 9 DATE OF SURVEY DECEMBER 2, 1988 KUPARUK ALASKA DECEMBER 6, 1988 dOB NUMBER AK-BO-80135 KELLY BUSHING ELEV. = 109.00 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS ",SURED DEPTH 6340 6422 6539 6689 6750 TRUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5910.58 5982.19 5801.58 5873.19 653'03 N 665.89 N 1517.44 W 1555.26 W 6084.57 6217.25 6271.68 5975.57 6108.25 6162.68 684.50 N 708.55 N 718.46 N 1608.74 W 1674.44 W 1700.13 W MARKER TOP KUPARUK C BASE KUR~RUK C TOP KUPARUK A BASE KUPARUK A SURVEY DEPTH 6767 6868 6286.84 6376.93 6177.84 6267.93 721,26 N 737.93 N 1707.28 W 1749.80 W PBTD TD ARCo' ALASKA. INC. · 2Z-19 STRAT. GI~_P_I~[C SU~J~IAR¥ DERIVED USING D IL DEPTHS AND SPERRY SUN SURVEY DATA CO~nJ~D I NATES .... MARKER MEASURED DEPTH ....... TVD THICKNESS · BKB BKB SUB-SEA VERT I CAL WITH REF. TO WELLHEAD ( OR I G I N- 619FEL 1849FSL ) T OP KUPARUK C · BASE KUPARUK C 6340 5910.58 6422 5982.19 TOP KUPARUK A 6539 BASE KUPARUK A 6689 PBTD 6767 6084.57 6217.25 6286.84 5801.58 653.03N 1517.44W 5975.57 684.50N 1608.74W 6108.25 708.55N 1674.44W · · 6177.84 721.26N 1707.28W TD 6868 6376.93 ~. 6267.~3 737.93N .~._~1749.80W 1) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. 2) COMPUTER PROGRAM - SPERRY SUN THREE DIMENSIONAL RADIUS OF CURVATURE, DATA CALCULATION AND INTERPOLATION BY RADIUS OF CURVATURE DATE OF SURVEY DECEMBER 2, 1'='c'°~,,~ COMPUTATION DATE DECEMBER 6, 1988 JOB NUMBER AK-BO-80135 .............................................................................. KE_.LLy,B_USH!NG...E,.LEV__. = IO'..~:._~_~!)....FT,. ......... SPERRT -SUN SCALE :- 1 INCH TO 500.00 / 500. KUPRRUK ARCO ALASKA. INC. 2Z-19 DECEMBER 2. 1988 RK-80-80135 -20~0.00 TRUE NORTH 6868 -~sbo. oo -~.obo. oo -sob. oo HOR I ZONTRL PROJECT I ON ~00.00 l_500.00 ~ SPERRY -...SUN 0.00 5CRLE :- ! INCH T8 1500.00 / 1500.0 KUPRRUK RRC8 RLRSKR. 2Z-19 DECEHBER 2. AK-80-80135 INC. 1988 1500.00 3000.00 4500.00 BO00. O0 7500.00 6376.93 VERTICRL -6868 ~sbo. oo soho. oo -PROJECT I r~N 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator N. ASKA OIL AND GAS CONSERVA ' ' APPLICATION FOR SUNDRY APPROVALS 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ Operation Shutdown _ Re-enter suspended well _ Time extension _ Stimulate .~. Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1850' FSL, 619' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 2530' FSL, 2080' FEL, Sec. 11, T11N, R9E, UM (approx.) At effective depth 2617' FSL, 2310' FEL, Sec.11, T11N, R9E, UM (approx.) At total depth 2635' FSL, 2351' FEL, Sec. 11, T11N~ R9E, UM (approx.) 12. Present well condition summary Total Depth: measured 6868' feet Plugs (measured) true vertical 6373' feet None RKB 109' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-19 ~&~, ~ · 9, Permit number 88-130 10. APl number 50-029- 21882 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 6773' feet Junk (measured) true vertical 628 9' feet None Tubing (size, grade, and measured depth 4"3-1/2", J-55, tbg w/tail @ 6471' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 198 Sx AS II 115' MD 115' TVD Surface 3496' 9 5/8" 750 Sx AS III & 3531'MD 3483'TVD Intermediate 350 Sx Class G - Top job w/132 sx ASI Production 68 21 7" 225 Sx Class G 6854'M D 6360' TVD Liner Perforation depth: measured R ,~-t,~ ~, i, 6340'-6364' MD, 6370'-6412' MD, 6612'-6622' MD ;;'~ true vertical 5911'-5932' TVD, 5937'-5973' TVD, 6149'-6158' TVD ;JUL!2 Na ,- 0il & Con . Packers and SSSV (type and measured depth) AVA 'RHS-XL' pkr @ 6245', TIW 'SS-DB' pkr @ 6444'~ AVA 'Sideguard' SSSV @ 1805' Attachments Description summary of proposal .~. Detailed operation program _ BOP sketch 13. 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 ./~)~ CU,~. ~ ~c'~-~''~'~'~'~ Title Sr. Operations Engineer ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form require ORIGINAL SIGNED BY LONNIE (;, ,SMITH Approved by the order of the Commission Commissioner IApproval No. Approved Copy Returned SUBMIT IN TRIPLICATE Form 10-403 Rev 5/03/89 KUPARUK RIVER WELL 2Z-19 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-19 Sand Fracture Stimulation AFE #AK3439 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 6430' RKB and replace with isolation sleeve. . RIH with standing valve and set in Otis ported landing nipple at 6430' 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 all 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 79. 12. Pump the fracture stimulation as per the attached pump schedule. Ramp between stages. Obtain representative fluid samples of the pad, slurry, and flbsh 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 3,400 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 SI well, bleed down annulus, and rig down frac equipment. 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 fiowback at 5 to 10 BPH° decrease the wellhead pressure in 50 psi increments 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-19 A SAND FRACTURE PUMPING SCHEDULE 5/12/89 ST/IGE FLUID CLEAN VOLUME PUMP RATE PROP. ~. PI:::K~PANT PI:::JOPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM @ BBLS I GW PRE-PAD 150.0 2 0 0 · 0 .................................................. SHUT DOWN FOR ISIP AND LEAKOFF CALCULAT'IONS 2 GWPAD 150.0 20 0 0 3 GW wi2 PPG 18.4 20 2 16/20 M CARBO-LITE 1 544 4 GW wi4 PPG 17.0 20 4 16/20 M CARBO-LITE 2856 5 GW w/6 PPG 19.8 20 6 16/20 M CARBO-LITE 4982 6 GW w/8 PPG 22.2 20 8 16/20 M CARBO-LITE 7452 7 GW wi10 PPG 24.3 20 1 0 16/20 M CARBO-LITE 10203 8 GW w/12 PPG 13.1 20 1 2 16/20 M CARBO-LITE 6593 9 SLICK DIESEL FLUSH 70.0 +SV 2 0 0 - - 0 1 5O/ 1 5O 74 1 50/ 300 224 201 320 374 20/ 340 394 251 365 414 30/ 395 439 35/ 430 469 20/ 450 504 ~ 70/ 520 .~'~'~ 504 ,,-: TOTAL GEH FO WATER = TOTAL DIESEL = TOTAL FRAC FLUID = TOTAL DIESEL FOR FLUSH = 397.9 BBLS 16.8 BBLS 414.7 BBLS 70.0 BBLS + SV 16/20 M CARBO-LITE = 33632 LBS 1. All fluids should be maintained between 85 F and 90 F on the surface. ~:?~,~?i 2. Stages I and 4 are crosslinked 40,Wl ,000 gal gelled water with 2% KCL by weight and 5% dlesei by volume and enough breaker for an 8 hour break. 3. Stages 5 through 8 are the same as above but without diesel. 4. Reduce pump rate to 15 BPM if treating pressure rises to 6,000 psi. Shut down at 6,500 psi. 5. Stage 9 (flush) should include a volume adjustment for sudace equipment between 'dm wellhead and densimeter. 6. This job is intentionally underflushed by 4.0 bbls. The Mender tub should be bypassed at flush. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown_ _ Plugging _ Pull tubing_ Type of Well: Development X Exploratory _ Stratigraphic _ Service _ Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Perforate _ Other X 6. Datum elevation (DF or KB) 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1850' FSL, 619' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 2530' FSL, 2080' FEL, Sec. 11, T11N, R9E, UM (approx.) At effective depth 2617' FSL, 2310' FEL, Sec.35, T11N, R9E, UM (approx.) At total depth 2635' FSL, 2351' FEL, Sec. 35, T11N, R9E~ UM (approx.) 12. Present well condition summary Total Depth: measured 6868' feet Plugs (measured) true vertical 6373' feet None RKB 109' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-19 J~/'~, '/~,'~ ~,,t.~ 9. Permit number 88-130 10. APl number 5o-029-21882 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 9970' feet Junk (measured) true vertical 6 21 7' feet None Casing Length Size Structural Conductor 8 0' I 6" Surface 3496' 9 5/8" Intermediate Production 6 8 21 7" Liner Perforation depth: measured true vertical Cemented Measured depth True vertical depth 198 Sx AS II 115' MD 115' TVD 750 Sx AS III & 3531'MD 3483'TVD 350 Sx Class G - Top job w/132 sx ASI 225 Sx Class G 6854'1V~. ~C~i t~.' [~VDi~.:! Tubing (size, grade, and measured depth ~L,~J .... Oil & Cas Con:;. 4", 11..0#, J-55 to 4007' RKB and 3 1/2, 9.3#, J-55 to 6,471'RKB Packers and SSSV (type and measured depth) AVA "Sideguard" SSSV C 1805', 1805', AVA RHS-XL PKRC 6,245'RKB, TIW "SS-BB" PERM PRRC 6,444' RKB 13. Attachments Description summary of proposal .~_ Detailed operation program _ BOP sketch _ Pump scale inhibition squeeze treatment. 14. Estimated date for commencing operation June. 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~[ Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~ c~,,'~--~ ,~ ,~ ~ ~.,~~ Title Sr. Operations Engineer ~' ' 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 require ORIGINAL SIGNED BY LONNIE C. SMITH IApproval N~;;~.. Approved Copy Returned Approved by the order of the Commission Form 10-403 Rev 5/03/89 Commissioner Date SUBMIT IN TRIPLICATE Scale Kuparuk Well 2Z-19 Inhibitor Squeeze Treatment 6/23/89 CC 230DS28ZL . . 1 . . . . . . 10. 11. MIRU Slickline. RIH with gauge ring to ensure tubing is free of scale. RIH with standing valve and set in XN nipple at 6461' RKB. MIRU pump equipment. Mix 10 drums Chemlink S-289 with 5,500 gallons (131 bbls) produced water. Pump pre-mixed inhibitor pill pumping at 2 BPM. Note: Maximum treating pressure is 1300 psi Overdisplace pill with at a rate of 2 BPM with 250 bbls of produced water to push pill out into formation. Follow produced water overflush with 68 bbls of diesel to displace tubing. Note: Maximum treating pressure is 1300 psi RIH and pull SV from D nipple. RDMO pump equipment. Shut-in well for 24 hrs to allow chemicals to soak. Bring well back on production at 500 BFPD for the first 24 hrs. Inform corrosion Engineering that well is flowing. Daily samples will be taken for analysis of residual returns for the first seven days, then samples will be taken weekly. Open well fully after the first day. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A STATE OF ALASKA ~. ALASKA OIL AND GAS CONSERVATION COMMISSION · REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pedorate Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. Box 100360 Anchoraqe~ AK 99510-0:~Q 4. Location of well at surface 1850' FSL, 619' FEL, 5ec.11, TllN, RgE, UN At top of productive interval 2502' FSL, 2136' FEL, $ec.11, TllN, RgE, UM At effective depth 2570' FSL, 2326' FEL, 5ec.11, T11N, EgE, UN At total depth 2587' FSL~ 2369' FEL~ Sec.11~ TllN~ RgE, UN 12. Present well condition summary Total depth: measured 6868 'MD true vertical 6377'TVD 6767 'MD Effective depth: measured true vertical 6287 'TVD feet feet feet feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) No ne Junk (measured) N o ne Other ~ , Compl el;e 6. Datum elevation (DF or KB) "~-Ur~r Property name I~lli~r~rl,l~ R~/~ IIn'l~- 8. Well number 2Z-19 9. Permit number/approval number 88-130/9-002 10. APl number 50-- 029-21882 11~ Field/Pool ~(u.naruk Rivmr Oil Pnnl Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80 ' 16" 3496 ' 9-5/8" 6821 ' 7" 198 sx AS II ll5'MD 750 sx AS III & 3531'MD 350 sx Class G - Top job w/132 sx AS I 225 sx Class G & 6854'MD 200 sx AS I measured 6340'-6364'MD, 6370'-6412'MD, 6612'-6622'MD 115'TVD 3485 ' TVD 6364'TVD true vertical 5911 ' -5932 ' TVD, 5937 ' -5973 ' TVD, 6149' -6158 ' TVD Tubing (size. grade, and measured depth) 4"/3-1/2", J-55, tbg w/tail ~ 6471' Packers and SSSV (type and measured depth) AVA 'RHS-XL' pkr (~ 6245', TIW 'SS-BB' pkr (~ 6444', AVA 'Sideguard' 555V ~ 1805' feet 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure FEB 2 Gas Cons. Commissk 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run ~ Gyro Daily Report of Well Operations _,~ , 16. Status of well classification as: Oil _.._/ Gas ~ Suspended Serw~ __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15188 Title Area Drilling Engr. * Completion Well History (Dani) SW04/016 Date Z//~¢/.O? SUBMIT IN DUPLICATE ~.~ ~ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and subm t he "Initial Report" on the first Wednesday after a well is spudded or workover operalions ara started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County. parish o~ borough ~ORT~ SZ, OPE ILease or Unit IT,tie ~: 25646 2~.CO ALASKA INC. KUPARUK Field Auth. or W.O. no. AK3439 Operator j~t~CO Spudded Or W.O. begun ACCEPT Date and depth as of 6:00 a.m, 50-029-21882 State ~'Z- 19 [wan no IOate 02/04/89 Complete record for each day reported NORDIC RIG I IARCO W I ,56,nnnn Prior status if a W.O. 02/04/69 ( )) TD: 6848 PB: 6771 SUPV:DLJB 02/05/89 ( TD: 6848 PB: 6771 SUPV:DLJB ND TREE 7"9 6848' MW:10.7 BRINE MOVE RIG FROM 2Z-18 TO 2Z-19. ACCEPT RIG AT 0530 HRS 2-4-89. NIPPLE DOWN TREE. DAILY:S38,880 CUM:$846,096 ETD:S846,096 EFC:$1,371,500 RIH WITH COMPLETION 7"9 6848' MW:10.7 BRINE NU BOPE AND TEST. RO E-LINE AND PERF A SAND 6 SPF 6612-6622, PERF C SAND 12 SPF 6340-6364, 6370-6412. TOTAL OF 6 RUNS WITH 2 MISFIRES. RUN 6.125" GR & JB TO 6580'. PU AND WITH TIW SS-BB PERM PKR AND SET AT 6441' WLM. RD E-LINE. RUN AND START RIH WITH COMPLETION. (AVA 'SIDEGUARD' SSSV % 1805', AVA 'RHS-XL' PKR ~ 6245', TIW 'SS-BB' PKR ~ 6444', & TT ~ 6471') DAILY=S83,840 CUM=$929,936 ETD:S929,936 EFC=$1,371,500 RECEIVED FEB 2 ~a~kC, pjl,,,& Gas Cons. Commission The above i,,_.~S correct sig..,u,/? For form pre~aratio~d see Procedures Ma~ Section 10, ~ Drilling, Pages 86 ana 87. AR3B-459-1-D INumber all daily well history forms consecutively iPage no, ae they are prepared for each well, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: PrePare and submd the "Final Report" on the first Wednesday after allowable has Oeen assigned or well ,s Plugged. Abandoned or Sold. "Final Report" ~hou[d be suOmitted also when operations are susoeneed for an indefinite or appreciable ~ength of :~nle On worl<overs when an offlc~al [est la not required ,Joon completion, report completion and representative test data ~n blocks PrOvided The "Final Report" form may be used ~or reporting the en~re District County or Parish ~ State ARCO ALASKA INC. I NORTH SLOPEI AK I Lease or Unit I Title APL: 25646 ~ COMPLETE & PERFORATE AccoLJntlrlg COSt center code Field KUPARUK Auth. Or W.O. no. ~K3439 Operator A.R.Co. W I. ARCO 56. 0000 Spudded or W.O. begun Date ACCEPT 02/04/89 02/06/89 (1L) TD: 6848 PB: 6771 SUPV:DLJB 23-19 Iwe. no. Date and depth as of 8:00 a.m. API: 50-029-21882 Com01ete record for each day reported NORDIC RIG 1 otal number of wells {active or reactive) on this pst center prior to plugging and bandonment of ttlis well our ' I Prior status if a W,O, IH 0530 HRS RIG REL 2100 HRS 2-5-89 7"@ 6848' MW= 7.0 DIESEL FINISH RUNNING COMP. RAN TOTAL OF 98 JTS 4" J-55 DSS-HTC IPC TBG, 68 JTS 3.5" J-55 EUE 8RD ABM IPC TBG AND 3 JTS 3.5" 9.2t J-55 BTC ABM IPC TBG. LAND TBG PRESS TBG TO 2500 PSi AND SET AVA RHS-XL PKR AT 6245'. TEST TBG TO 2500 PSI. PRESS. ANN TO 1500 PSI AND REL PBR. TEST ANNULUS TO 2500 PSI, TEST SSSV TO 1500 PSI. SHEAR OUT. ND BOPE NU TREE AND TEST TO 5000 PSI. DISPLACE TO DIESEL. SET BPV. RIG RELEASED 2100 HRS 2-5-89. DAILY:S267,161 CUM=$1,197,097 ETD:S1,197,097 EFC=$1,371,500 FEB Alaska 0il & ~as Cons. C0mmlss1011 Old TO New TD Released rig Pate PB Deplh Kind of rig Classifications (oil, gas. etc.) Type completion (single, dual. etc.) Producing method Official reeervoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production ~iF on' test Gas par day Puml~ size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct I°''' = l ' ITM 3 := Fo, for., pra~,io', and see Procedu~,'lanual, Section 10. Drilling, Pages 86 and 87. AR3B-459-3-C INumberall daily well history forms consecutively Page no I as they are prepared for each well. I I DIvlN~ of AtlantlcRIchlteldCompl~y ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 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. 3 F- 1 5 Kupaurk Fluid Level Report 1 2- 0 3 - 8 7 3 N - 1 8 Kupaurk Fluid Level Report 1 2-1 8 - 8 7 3 F- 01 Kupaurk Fluid Level Report 8-29-87 3 F- 0 2 Kupaurk Fluid Level Report 8-29-87 3 F- 0 9 Kupaurk Fluid Level Report 8-29-87 3 F- 0 6 Kupaurk Fluid Level Report 8-29-87 3 F-1 0 Kupaurk Fluid Level Report 8-29-87 3 F-1 I Kupaurk Fluid Level Report 8-29-87 3 F-1 5 Kupaurk Fluid Level Report 8-29-87 3 F-1 4 Kupaurk Fluid Level Report 8-29-87 3 N- 1 0 Kupaurk Fluid Level Report 5-18-87 3 N-06 Kupaurk Fluid Level Report 5-22-87 3 N-09 Kupaurk Fluid Level Report 5-21-87 31-0 1 Kupaurk Fluid Level Report 4-24-87 3 N- 1 I Kupaurk Fluid Level Report 4-15-87 3 N- 1 4 Kupaurk Fluid Level- Report 4-13-87 3 F- 0 8 Kupaurk Fluid Level Report 4-14-87 3 N-01 Kupaurk Fluid Level Report 4-20-87 3 N - 1 4 Kupaurk Fluid Level Report I 2 - 0 4 - 8 7 3 F-1 5 Kupaurk Fluid Level Report 2-02-89 3 F-- 1 5 Kuparuk Well Pressure Report 8-27-87 3 F- 1 3 Kuparuk Well Pressure Report 8-27-87 3 F- 1 5 Bottom-Hole Pressure Survey 8-25-87 1 B- 0 5 Kuapruk Well Pressure Report 2-20-89 1 E-25 Kuparuk Fluid Level Report 2-19-89 3 B- 1 1 Kupaurk Fluid Level Report 2-20-89 3 A- 0 3 Kupaurk Fluid Level Report 2-21-89 3 H-01 Kupaurk Fluid Level Report 2-21-89 2Z-1 9 Kupaurk Fluid Level Report 2-20-89 31-1 2 Kupaurk Fluid Level Report 2-20-89 1 E-0 8 Kupaurk Fluid Level Report 2-19-89 3M-1 8 Kupaurk Fluid Level Report 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casin g Casing Casing Casing Tubing Tubin~ Casinl Casin~ 3H-01 3B-13 1E-29 1C-05 3M- 1'7 2Z-20 30-10 31-12 3H-10 Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report BHP Report 2-15-89 2-17-89 2-15-89 2-1 8-89 2-16-89 2-18-89 2-16-89 2-20-89 2-13-89 Casing Casing Casing Casing/Tubing Casing Tubing Casing Tubing BHP Receipt Acknowledged: Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron STATE OF ALASKA Al::,. ~'KA OIL AND GAS CONSERVATION COMM k.._,iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951 0-0360 4. Location of well at surface 1,~t~00~3 · '. Sec I T11N RgE UM oFf,cd uCctl~(~ i r~9~al . 1, , , Operation shutdown ~ Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate __ Pull tubing __ Variance ~ Perforate ~ Other __ 5. Type of Well: 6. Datum elevation (DF or KB) Development .~ RKB 109 ' Exploratory __ Stratigraphic __ 7. Unit or Property name Service__ Kuparuk River Unit 2,~t30_' F.SL, 2080' FEL Sec. 11 T11N, RgE, UM (approx.) effective Uepth ' ' 2617' FSL, 2310' FEL, Sec. 11, TllN, RgE, UM (approx.) At total depth 26.~5' FSt., 2351' FEL; Sec. 11: TllN: RgE: UM fapprox. I 12. Present well condition summary Total depth: measured 6868 ' MD feet true vertical 6373 'TVD feet 8, Well number 2z-19 9. Permit number 88-130 10. APl number 50-029-21882 11. Field/Pool K,Inarmmk R~vmr ~!~1 Pnnl Plugs (meaSured) None Effective depth: measured feet true vertical 6773 'FID feet 6289 ' TVD Casing Length Size Structural Conductor 80 ' 16" Surface 3496 ' 9-5/8" Intermediate Production 6821 ' 7" Liner Perforation depth: measured None true vertical None Tubing (size. grade, and measured depth) None Packers and SSSV (type and measured depth) Nope 13. Attachments Description summary of proposal Well History 14. Estimated dateforcommencingoPermion December, 1988 16. If proposal was verbally approved Junk (measured) None Cemented Measured depth True vertical depth 198 sx AS II ll5'MD 750 sx AS III & 3531 'MD 350 sx Class G - Top job w/132 sx ASI 225 sx Class G 6854' MD RECEIVED J~N O ~I l.g~ Alas~ 0ii & Gas Cons. Commission .. ,,~i ~ch0rage Detailed operations program BOP sketch __ 115. Name of approver Date approved Service ll5'TVD 3483'TVD 6360'TVD Date Status of well classification as: Oil x" Gas__ Suspended__ 17. I hereby certify that the foregoing is true and Correct to the best of my knowledge. Signed e '~ ~J~~ Title Area Drilling Engineer FOR COMMISSION USE ONLY I Approval No. ¢_ Dd),~z- Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commissione~-ONNIE C. SMITH Approved Copy Returned Commissioner feet Form 10-403 Rev 06/15/88 039 / SA4 Subsequent Work Reported on No. SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Dally Inatructiona: Prepare and submit the "Initial Report" on the first Wednesday efte~ a well ia spudded or workover operations are st&tied. Daily work prior to SPudding should be summarized on the form giving incluelve dates only. . ,] District I County, parish or borough State I Field ILea~ or Unit I Auth. or W,O. no. ; ITitle no. Operator IARCO W.I. Spudded or W.O. begun ]Date IHour ]Pdor statu, i, a W.O. Date and depth as of 8:~ 11/23/88 TD: 2619'( SUPV: 11/24/88 ( TD: 3561'( SUPV: 11/25/88 ( ~D: 4257'( SUPV: 11/26/88 ( TD: 6351'( 2 SUPV: 11/27/88 ( TD: 6831'( SUPV: 11/28/88 ( TD: 6858'( SUPV: 11/29/88 ( TD: 6868'( SUPV: Completerecordforeachdayrepo~ed ) DRILLING 16"e 115' MW: 9.1 VIS: 51 19) NIPPLE UP DIVERTER, PICK UP BHA & ORIENT MOTOR, TEST DIVERTER, SPUD WELL e 1000 HRS, 11/22/88. DRILL F/115'-2619'. DAILY:S98,977 CUM:$98,977 ETD:S98,977 EFC:$1,371,500 FIN RUNNING 9-5/8" CSG 16"~ 115' MW: 9.4 VIS: 46 2) DRILL TO 3561' (CSG POINT), MAKE SHORT TRIP, CBU, TOH, RU & RUN 9-5/8" SURFACE CSG DAILY:$48,895 CUM:$147,872 ETD:S147,872 EFC:$1,371,500 ) DRILLING 8-1/2" HOLE 9-5/8"~ 3531' MW: 8.8 VIS: 31 ;96) CEMENT 9-5/8" SURFACE CASING W/750 SX AS III & 350 SX CLASS G. NU BOP, TIH, DRILL OUT, RUN LOT TO 12.5 PPG EMW DRILL AHEAD WITH POLYMER MUD. DAILY:S106,813 CUM:$254,685 ETD:S254,685 EFC:$1,371,500 ) TOH 9-5/8"~ 3531' MW:10.7 VIS: 40 94) DRILL 8-1/2' HOLE FROM 4257' TO 6351', CIRC & TOOH DUE TO TURBINE FAILURE. DAILY:S53,750 C0M:$308,435 ETD:S308,435 EFC:$1,371,500 ) DRILLING 8-1/2" HOLE 9-5/8"~ 3531' MW:10.6 VIS: 38 80) TOH WITH FAILED TURBINE, MAK~ UP NEW BIT & BHA, TIH, WASH TO BTM, DRILL 8-1/2" HOLE TO 6831' DAILY:S59,770 CUM:$368,205 ETD:S368,205 EFC:$1,371,500 [ LOGGING 9-5/8"e 3531' MW:10.6 VIS: 42 7) DRILL TO 6858', SHORT TRIP TO SHOE, REAM TO BOTTOM, CBU, SURVEY, TOH, RU & LOG DAILY:S48,496 CUM:$416,701 ETD:S416,701 EFC:$1,371,500 ) RU TO CEMENT 7" CSG 9-5/8"@ 3531' MW:10.6 VIS: 40 10) FINISH LOGGING 8-1/2" HOLE LOG W/ TRIPLE COMBO, RFT/GR, & SWC. DRILL TO 6868'. CONDITION HOLE TO RUN 7" CSG, RUN 7" AND RU DOWELL TO CEMENT. DAILY:S206,719 CUM:$623,420 ETD:S623,420 EFC:$1,371,500 RECEIVED JAN d z~ ]9~ 0il .& Gas Cons. Commission ' ~,, ~chorage The abo.~ is correct Signa~l.~l.,~ ~' " JDate" AR3B-459-1-D INumber all dally well hlsto~/ forms consecutively aa they are prepared for each well. jPage 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 operations are suspended for an indefinite or appreciable length of time. On workovers when an official test ia 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. ARCO ALASKA INC. Accounting cost center code District ICounty or Parish ISlate KUPARUK I ADL: 25646 / 2Z-19 Field ILease or Unit I Well no, AK3439 J DRILL Auth. or W.O. no. ~Title I API: 50-029-21882 ARCO NORTH SLOPE 56.0000 operator SPUD A.R.Co. W.I. 11/22/88 Spudded or W.O. begun Date DOYON 14 Date and depth Complete record for each day reported as of 8:00 a.m~11/30/88 ( 8) Iotal number of wells (active or inactive) on this dst center prior to plugging and bandorl~ o[.]~.ll~ well I our I Prior status if a W.O. I PB: SUPV: Z Old TO ] New TD Released rig I Date Classifications (oil, gas, etc.) Producing method Potential test data RIG RELEASED 7"~ 6848' MW:10.7 ~INE RUN 7" CASING TO 6848', CEMENT W/ 225 SX CLASS G, DISPLACE W/ BRINE, BUMP PLUG, PRESSURE CASING TO 3500 PSI, FLOATS HELD, ND BOP, SET SLIPS, CUTOFF CASING, INSTALL PACKOFF AND TUBING HEAD, PUMP DIESEL IN ANNULUS, RELEASE RIG AT 1500 HRS, 11/29/88. DAILY:S183,796 CUM:$807,216 ETD:S807,216 EFC:$1,371,500 RECEIVED AlaSka Oil & Gas Cons. Commission ",~:: ~chorage j P6 Ds,th I I Kind Of rig tType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production 011 ;3n test Gas per day' Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effecti~,e date corrected The above is correct Signature/'~ t~ IDate Title/ ,,, S~er~lliPnr°Cedures Mar["~'g. Pages 86 a~t~ 87S.ecti°n 10, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no, Division of AtlsntlcRIchfleldCompany ARCO Alaska, Inc. Date: December 15, 1988 Transmittal #: 7372 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. ,~ 1Y-26A OH LIS Tape and Listing 1 2-08-88 #72962 · 2 Z- 1 9 OH LIS Tape and Listing 1 2 - 0 6 - 8 8 # 7 3 0 3 6 · 2 Z- 1 9 RFT Tape and Listing I 1 - 2 8 - 8 8 # 7 3 0 3 6 Receipt Acknowledged: Alaska 011 & C~s Con- Anchota~;' Commissio~ ........................... Date: ............ DISTRIBUTION: State of Alaska L. Goettinger ARCO Alaska, Inc. Date: December 8, 1988 Transmittal #: 7369 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. ~2 Z- 1 9 Repeat Formation Tester 1 1 - 2 8 - 8 8 ~ Z- 1 9 Chronological Sample Taker I 1 - 2 8 - 8 8 ~'-2Z-19 2" Dual Induction 1 1-27-88 ~2Z-1 9 Microlog- GR 1 1 -27-88 ~2Z-1 9 Cyberlookk I I -27-88 ~2Z-1 9 2" & 5" Raw FDC 1 1 -27-88 a~, 2 Z- 1 9 2" & 5" Porosity FDC 1 1 - 2 7 - 8 8 ~ 2 Z- 1 9 5" Dual Induction 1 1 - 2 7 - 8 8 6342-6619 3629-4049 1000-6822 6100-6821 6200-6750 3534-6796 3534-6796 1000-6822 Receipt Acknowledged: Alaska, oil Gas Co & Co nrn lon ..................... ............ " DISTRIBUTION; NSK Drilling State of Alaska(+sepia) Franzen D&M L. Johnston(vendor package) NOV-25-'88 89:4! iD:DOYON ~,IG 14 TEL NO:659-?Gg3 ALASX~, O~L ~ CAS CONSERVATION , ~.O.B.E. Inspection ~epoct Date //.f.)t!..b'.,h ,~1.,..,.., ...., " ~ 7; z-:::. '---~-m,~.- .... ~ : .- -- ': --~ _~ ~.~~ Permit t~.,-, Ij ~J . (;t~" ~ .~._ ~<.Caslng Sat ~ ~ ~'' ~ Ger~eral Bbuseke,~pJng. L''/ Rig ~// Reserve Pit ~" Pressure After Closure .... . ........ pstg./TOO Trip Tank ' _ ~ ___ Full Charge Pxe~sure Attained:_ h min~_/O sec, r13w gonJ tot ~f~. Controls; Mast mr ~' ~ '" ~ an0 FloOr S~fe~y Valves BOPE Stack Test Pressure Upper Kelly / Test, ~re,~ure Mmular Preventer j~(~~ Lower Kelly t Test Pressure:_ Pipe Rams ~ _~ .... Z'-'<,~-' Ball typ~ j -: .... 'Test Pze~sure~~_O O, " ....... ~ ~est ~ressure~~~_ ~iino ~ms ~ ~~gC;C,C:, Z.,tde ~o~ Choke Line Valves~ . , '.~0~0 Choke Eenifold j Te~t Fressure B.C.R. Valve }'_. ~ No. Val~eo [ q Kill Line ~Jalves '.} ~OO, O: ~o flanges ~'~ '~ ~~ - ........... . Check 'Valve ~ N~4 : /dJus'table Choke~ / ' C').~' ,drauicolly: .Oper, t~. cbok~2 ' 0~_ · .... Test R~sults: Failures MOi~J( '_ Tes~ T~e ....... ~ _.hfs,. Repair or Replacement of failed equt. pm~ut to-be made wi. thin Commis~tou office notifle~. days and Inspector/ Remarks Dl~trlbution_ ortg, - AO~OC¢ , cc - Operator cc - Supervtso~ Inspector NOV 2 October 31, 1988 Telecopy~ (907)276-7542 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360' Kuparuk River Unit 2 Z- 19 ARCO. Alaska, Lnc. permit No. 88-130 ' L 619'FEL Sec. 11 TllN RPE UM. Sur. Loc. 1850 FS , , , , , Bcmhole Loc. 2652'FSL, 2342'FEL, Sec. 11, TllN, RPE, UM. Dear Mr. Kewin~ Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to o~tain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of' the equipment before' the surface casing shoe is drilled. Where a diverter system 'is required, please also notify this office 24 hours prior to commencing equipment ~nstallation so that the Commission may witness testing b~fore drilling b~low the shoe of the conductor pipe. Chairman of Alaska 0tl and Gas Conservation Commission BY O~ER OF ~E COMMISSION dlf ~ gncloaure c¢~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o ancl. ~ ---- ~ STATE OF ALASKA ALASKa-, glL AND GAS CONSERVATION U,J'MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill FII lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepenq Service [] Developement Gas [] Single Zone J~ 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 0il 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 Bond(see 20AAC25,025) 1850'FSL, 619'FEL,Sec.ll,T11N,R9E,UM Kuparuk River Unit Statewide At top of productiveinterval(@ target) 8. Well nurpber Number 2530'FSL,2080'FEL,Sec.ll,T11N,RgE,UM 2Z-19 #8088-26-27 At total depth 9. Approximate spud date Amount 2652'FSL,2342'FEL,Sec.11,T11N,RgE,UM 11/16/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD ~nd TVD) property line 2Z-2, 2Z-~ 6862 'MD 2652' ~ TD feet 30' ~ surface feet 2560 6383'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (sea 20 AAC 25.035 Kickoff depth 2531 feet Maximum hole angle 300 Maximum surface 2057 psig At total depth CVD) ~52 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) 24" 1~" G2.~ H-~O W~IH R~ ~ ~R' 11R 11G' +2nn . 12-1/4" 9-5/0"36~ J-55 BTC 3481 3G 3G' 3517 ~74' 750 ~x AS III & F-ER~ 350 sx Class G 8-1/2" 7" 26~ J-55 BTC 6827 .35 35' 6862 6383' 200 sx Class G tail F-ER~ Top of G 500' above 19. To be completed for Redrill, Re-entry, and Deepen Operations. K upa r u k 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 Conductor Surface IntermediateRECEIVED Production Liner 0C~'2 "'~ Perforation depth: measured true vertical ~.,~,.:.<,~, .. 20. Attachments Filing fee ~ Property pla~ ~" BOP Sketch ~ Diverter Sketch ~ D~lli'hg program DrJllJng fluJd program ~ TJme vs depth p~ot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby cer~hat the foreg~g is trUe and correct to the best of my knowledge / i~ /vl'''-- C°mmissi°nUseOnly~¢~(TEH) PD'/02' Permit Nu I AP, number I Approv" d'te I See cover letter ~-'/~ 50--~2 ~- ~ ~¢~ 10/31/88 for other requirements Conditions of approval Samples reqvired ~ Yes ~ No Mud log required ~ Yes ~No Hydrogen sulfide measures ~ Yes ~No ~irectional survey required ~Yes ~ N~ Required working p~sure f~ BOPE~M; ~3ML ~ 5M; ~ 10M; ~ 15M ~ by ordor of Approved by ( ~ .~ . ~ ~~~ Comm,ss,oner the commission Dat . .. Form 10-401 Rev. 12-1-85 Submit ,I '~ triplicate i , . HORI.7_~.~~ RROJECT_iONj SCALE 1 I#. = 100~ FEET P. dARCO2z.ALASKAwo/; Kuperuk Field, North Slope, Aleeke ~ooo :2000 3000. I 2000 WEST~AST ] 000 1000 1.000 _ .. 0 _ 1000 _ TVD-SeT4 , ' TAROT LOCAT l Ofl t 2530' i lrSl.. 2OEO' FEL SURF~ LOORT!OfI~ 1850", FSL. 819' FI[L SEC:. 11. TI1N. RGE TD LOOATZON~ 2652': FSL. 2342' PEL SEC. 11. TIIN. RgE .. N 65 DEG 1612' (TO 2 MIN W TARGET) IQO.O. ..... 2QO0 _ 6000 TARGET TVD-58Z4 TMD-627Z DEP-1612 T/ ZONE C TVD-588g TMD-6294 DEP-1620 "T/ ZOI~E"-'A~ TVD~6079 ?TMD-6$ I3 'DEl=" 1728 B/ KUP S#D$ TVD-6209 THD-6662 DEP-1802 TD (LOG PT) TVD-6383 TMD-6862 DEP-1900 7'00.0 1000 VERTICAL SECTION 2000 750 700 650 600 550 500 450 400 350 2250_ 22OO_ 2150 2100 2050 2OO0 1950 2700 I I I I I I I I I ; 31oo I I I I I I I I 1 2900 I I I I I I 2500 I ~ 2700 I I I 2300 I I ~ 2500 .~.~ O0 .. t 2300 1 900 '" -. * 500 "" 3.900 ,85o I ~ ~ o,o I 1800 _ J I I 1750 / / / / / 3900 / / / / 500 // .7 3500 0 500 "~PPoo ! ! ! / / / / / / ~'41 O0 / / / / / / / / ?4300 / ! / / \ / \ / v / 45Q0 J / ~11C~O / \ / \ _ 2150 2100 _ 2050 _ 2000 _ 1 950 1 900 _ 1 850 _ 1 800 1750 750 700 650 600 550 I I t 2250 2200 I I I I 500 450 400 ;350 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" casin~. 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. .,a,,,,. L_ CLEANER ~ SHALE SHAKERS 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 64' of departure, there are no well bores within 200' of this proposed well. Tw~/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 L 6 DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~:3N WELD STARTING HEAD 3. FMC D IVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRIM. ING SPOOL W/10' OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEFL VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASK/I~ INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION · 2 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 GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT ~HUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 PSI ~ ~ STAO( AOCtIvULATCR CAPACITY TEST 6 I, OEO< ~l) FILL ~Ta~ I~t[]=NOIR TO LEVEL WITH ~]C FLUID. ~ THAT AO3.MJLATCR ~ I~ ~300 I~I W/TH 1500 PS] ca~TRF_~ ~F T~E REGLLATC~, 3. (31~F. EV~ TII~F., TI-EN ~ AU. I.NI'I~ $IMJLT/k~EOL~LY AN:) REO]~ TIE TII~ AM) ~ REk~INII~ AFTER 4. REC(]RD (IN N~43C RICo ~ ~AB.E LO~ER LIMIT IS 45 ~r"CI~ CI.(~]I~ 'r]lv[ AI~ 12013 PS] [ I 3 2 13-5/8" BCP 8TA i,TE T I, FILL BI::P STACK Al4) Cl43~ IVlItN]FCLD WI'IH A,I~CT']'C DIE~EI.. 2. OEO< THAT N.L LOO< ~ ~ ]N I't~].LI-E~ AI~ ~LY ~T~~ ~T TEST ~ IN ~~ ~TH ~l~ JT ~ U IN L~ ~~ 3. ~ ~ ~~ ~ ~ KILL ~ ~ LI~ V~ ~~ TO ~ ST~ ~ V~S ~ ~ ~ ~ ~ 4. ~~ ~TO ~~ ~~DF~ I0~ ~ ~~ TO~~I ~~D~ I0~ ~ED ~~ TO 0 LI~ V~ ~ T~P]~ ~ ~~ V~ ~ ~ TO~~] ~~~] ~ ]N~4. ~I. 12- ~ ~~I~ V~ ~Y, ~Y ~ ~I~ PI~ ~ETY V~ ~ I~l~ ~ TO ~~l ~ ~I. ~~ ~ST I~~TI~ ~ ~~ ~ER ~ST ~E~Y ~~ F~I~LY ~TE ~ ~I~Y. ARCO Alaska, Inc. Post Otfice ~00360 Anchorage. A,-..~<a 99510-0360 Telephone 907 276 1215 October 4, 1988 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' Conductor As~Built Location Plat -~"2Z"Pad (Wells 18 - 21, 29) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you hav~ any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG:hf Enclosure GRU13/1.2 ARCO Alaska. Inc, i$ a Subsidiary o! AllanlicR~chfieldCompnn¥ , , ~ I .~, I II ~-BUI~T ~C~TED IN ' I, COORDINATES ~RE ~.~ ZONE SECTION II, ~ II N., R. 9 [., ~ / 2. ALL DISTANCES SHOWN ARE TRUE. UMIAT MERIDIAN. ~ 3. ELEVATIONS ARE B. RM.S.L. 4. REFERENCE FIELD BO0~: L-88-52, p~ ~-74~77~ 1 L-88-34, p~. 2-~ ~ L-88-~6~ p~. ~-4. I 2 5. O.G. ELEVATIONS ~OM NSK-5.2S.6-~ rev. I PROTRACTED SECTION CORNER 14i 13 6. HORIZONTAL POSITION B~ED ON 2-Z CONTROL I MONUMENTS PER LHD end ASSOCIATES. ,, ,, , , i , ,, i , · ~ , . 'Y' X LATITUDE LONGITUDE FE.L. .ES,~ Elev. El~v. ', ~ , ~ ' " ~ . 591 1796' 65.0 72.6" 18 5,966,552.92 i 529,117.01 70°19'10.907'' 149045;5° 50'; ' 19 5,966,605.96 ~ 529,088.86 70°19'11.430" 149°45'51.065" 619' 1849' 67.8' 72.5' 20 5~966,658.89 j 529,060.86 70o!9'11.952" 149°45'51.877'' 647' 1902~ 68.0' 72.6~ 21 5,966~827.08 [ 529,379.34 70019' I 3.594" 149045.'42.563" 327' 2069' 66.5' 71.6' 29 5~965,916.38 j 529,45~.15 70019' 04.633" 149°45'40.513" 258~ 1158' 67.3' 71.1' I ,.~ ~ I ; L..,.~ ! HEREBY CERTI~ THAT I AM PROPERLY ~ O~ A(~J " ...... REGISTERED AND LICENSED TO PRACTICE LANO SU,V~IN~ IN TH[ STAT[ OF ~*~." ~ '~ m '~ ALASKA ANO THAT TH~S PLAT ~;.' ~ '._~ '~. . ag . ii R;PRES~.TS ~ LOC~T, ON SU,V;~ ~*/49th ~ ~' ~, ~CO Abska. DIMENSIONS AND OTHER D~AI~ ~ CRAIG ~SAVAGE ARE CORRECT AS OF 8/29/88. w ~' · ~~ 4538-5 ~.%~-~ WELL CONDUCTOR AS BUILT ,.,,N.a ~ , 'Y' x , LATITUDE LONGITUDE F.E.L. ,ES.L- Elev. Elev. 18 '5,966,552.92 529,117.01 70°19'10.907" 149045;50.~50'; 591' 1796' 65.0' 72.6" I 9 5,966,605.96 529,088.86 70°19' I I. 430" 149°4§' 51.065" 619' 1849' 67.8' 72.5' 20 5,966,658.89 52.9,060.86 70°!9"11.952'' 149°45'51.877.' 647' 1902~ 68.0' 72.6' 21 5,966,827.08 52.9,579.54 70o19' I 5.594" 149045..'42.565'' 527' 2069' 66.5' 71.6' 29 5~965,916.58 529,455.15 70°19' 04.655" 149° 45' 40.51:3'' 258' 1158' 67.5' 71.1' .' (1) CHECK LIST FOR NEW WELL PERMITS Company /¢r~<~ /¢/~,¢~,- '-~C~ Lease & Well No. - Fee · ,,, (2) Loc thru 8) ' ' (8) (3) (9 thru'13) 10. (10 and 13) 12. 13. 1o,~,~ (14 :h~ 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2. Is well to be located in a defined pool ............ 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 .... 7i Is °perat°r the °nly affected party ................. 8 Can permit: be approved before fifteen-day-wait ....... Does operator have a bond in force .................................. ~F~ Is a conservation order needed ...................................... , ,, Is administrative approval needed ................................... Is the lease number appropriate ............................ ~ Does the well have a unique name ;;~ ;;;~;; '..'''''''.'''''''.''''.' Is conductor string provided ...eeoe.oeeeeee.e.eeeeeeeee.eee®.ee...®. 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 ' ...e....e.eeeeeeeeeeeeee.eee Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. REMARKS (29 thru 31) (6) Add: Geology: RPC .~/~L Engineering: LCS ~BEW/~ rev: 08/11/88 6.011 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 5"?0/o0 Additional Remarks: INITIAL GEO. UNIT ON/OFF CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX.' .. No special'effort has been made to chronologically" .o organize this category of information. ~IS Tape verification b$st~nq Center SChlumberger Alas,K& CosPut'nq 7~0EC~19S8 08~42 REI PAGEt ?-DEC,,,i 988 08142 PAGEt 1080 GL l 68, vet! PAGEt cen~er PAGgl l, $1E? '1'¥1~'1C - ¢#A# $0 7eD[C-t988 08=42 PAGE! Ceilte~ Ver! get' center verl~ '/,,,DEC-:~908 08:42 PAGEt 9 ?-DEC,,,! 988 08842 ~)AGE! ! ~, ver! 7-D1~C.~1999 08~42 Yeti t: :6 988 08142 PAGEt i& center "/-DEC-].9.t] Oli= 42 VA~U 1'7 Vert ~o~ ?-D[C-29~18 0B:42 P'IliG,KI 19 Ri ?.,~)i~C-1988 08:42 PAGI~t 20 ~e~ VAIr, U 0#$42 PAGE~ 22 LIS Va~e Vertficatio~ 988 08842 PAGE:! 2¸3 TRAI C ROFIL RED :# bE# ,. type co:#s I Ir' ! tO o004 FILE FILE SUM'NARY r i ~e ~,e,ade~ Ot)~ 0 ~N FILE IJN! ty~e ~HA, N Ir Date ~. XN 65 De~a fet.ue,~ ~,eeiii,ee~ie. record eb ~eet 0 0 DEBT FT M ~8 F 4 t8 :33¸ record o DEPT , XN 9 q Litttnq~ o~ tyl)e CH ~N OPR 4~ DE:P~ H,E:ADI:R ~8 ob Jeer o 0 78S6424 lin FT ~9L9SS 169'6 14 0 DEP? 786 I%# 65S0306 lift IJ M ,0'24 .m~"l~ t'l t, I ti1 bi:-] bro~ [:-] bm 9 IN 6 ! # 4¸8 024 (~Ord 0 DIEPT ?tS24i6 64 H $! ,026 · 0 §EP! 4 FT ~L tlCOtr)~ I 1~ SS } {{ ~N 8FTI M L 0 HEADER # ! 11 I o DE:P~ r record tyJJe 0 Df:PT H'I~ADI~R LIEN,~ ~ ! 28¸ L~ltt'~ Of ~t t4 type CONS , eb~,e'et o ~N ~nd o! set L End O! T~le 'tY~ CONS VAIfU ?S vO~6 SU~MM~I~Y Schlumberger ~IST HTBOI[]~ISA,DAT! 7~D~C~88 t~!491~9 P&g'e 76 SUMMARY irlb~S TAPES REELS ILR #PC