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Home My WebLink About191-120Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i ~/-~/~. ~) File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA ,-', Diskettes, No. D Other, No/Type OVERSIZED .r3' · · . Logs 'of various kinds Other COMMENTS: Scanned by: ~ Dianna Vincent Nathan Lowell .. , ,, n TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: is~ ( ",- \ BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 0"..,""..;:."",",1;,",,"",",b,.""p . ~,'.'\.. " ' .' _'In:~. , :',,~1 ' ."'ì" ' ~,."-,((:'7>' ;""i'.'~ May 27,2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Su bject: END2-54/Q-12 (PTD 1911220) Application for Cancellation of Sundry #302-344 Application for Sundry Approval for PWI with Rapid TxlA Communication Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 302-344 and Application for Sundry form 10-403 for Endicott weIl2-54/Q-12. Purpose of this request is to revise sundry requirements to those for rapid TxlA communication. Sundry 302-344 is for slow TxlA comm. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, jfJ( ~ Joe Anders, P.E. Well Integrity Engineer Attachments Application for Sundry Cancellation form 10-404 Application for Sundry form 10-403 Description Summary of Proposal Wellbore Schematic E""'" C E... :~ ~, ~,,:~::::'; JUN 022004 A\ask:ê\ Qii ~ r"\ l(ì\NAL ( STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ( 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Exploratory D PerforateD WaiverŒ) Annular Disposal 0 StimulateD Time ExtensionD OtherD Re-enter Suspended WellD 5. Permit to Drill Number: 191-1220 BP Exploration (Alaska), Inc. ~ bo m top bottom Liner 1519 7" 29# L-80 ' 1069õ - 175 9268.6 - 10601.8 8160 Liner 15 4-1/2"12.6# L-80 1173~ 11752 10205.5 - 10218.9 8430 Production 9446 9-5/8" 47# NT80S 3" §Y483 , 37.0 - 8292.3 6870 Production 1442 9-5/8" 47# NT95HS 94~3 - 10925 8292.3 - 9496.9 8150 Surface 2697 13-3/8" 68# NT80CYHIf-..- 38 - 273 38.0 - 2733.7 5020 Perforation Depth MD (ft): Perforation Depth TVD (ft): 7 Tubing' . Tubing Grade: Tubing MD (ft): 11788 - 11881 10251 - 101>3 I 5.5 " '17 # L-80 35 11894 - 11940 10347 - ¡03 ~4 \ \.\V ~ I. Packers and SSSV Type: \ Packers and SS'C{1D (ft): 3-1/2" AVA DWP Patch Packer \) \ 3713 3-1/2" AVA DWP Patch Packer \, J\~ 3730 4-1/2" Otis WD Packer - r ~ V 11737 5-1/2" TIW Big Bore Packer . 10569 12. Attachments: Description Summary of Prop al~. // ' ~ 13. Well CI~S after proposed work: Detailed Operations Program 0 BOP etch~ /./ " ExploratoryD DevelopmentD . ~ 14. Estimated Date for J 10 2004 \ 15. Well Status after proposed work: Commencing Operation: une '-.J Oil 0 GasD PluggedD AbandonedD 16. Verbal Approval: Date: WAG 0 GINJD WINJI'X1 WDSPLn Commission Representative: ~repared by Garry~atron 564-4657. StratigraphicD 9. Well Name and Number: 2-54/Q-12 10. Field/Pool(s): _/ Endicott Field 1 Enj'cott Oil Pool, Duck Island Unit PRESENT WELL CONDITION SUMMARY ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffec7ive epth TVD (ft): 10601.8 12137 10511.9 Length Size MD TVD 6. API Number 50-029-22218-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.10 KB 8. Property Designation: ADL-034633 11. Total Depth MD (ft): 12175 Casing ~... Plugs (md): None Burst Junk (md): None Collapse 7020 7500 4760 5080 2270 10661 ServiceŒ] 17. I hereby certify that the foregoing is true and com let to the best of my knowledge. Conditions of approval: Notify Commission sò that a representative may witness Contact Joe Anders, P .E. Printed Name Signature Title Phone Well Integrity Coordinator 659-5102 5/27/04 Commission Use Only I Sundry Number: 2 De/' 3o:.}- IT Form 10-403 Revised 12/2003 o. Fœœr~D JUN 022004 Alaska 0ï1~~~g~OO~~~~1¡ÌÎ~à~~~ Anchorage eU'u 2 9 ""fHI ,\t\n.~~.,. '. ¡ifl,. J l' ~11",1\ l SUBMIT IN DUPLICATE Plug Integrity D BOP TestD Mechanciallntegrity Test 0 Other: Subsequent Form Required: Approved by: f Endicott 2-54/Q-12 Description Summary of Proposal OS/27/04 Problem: Produced Water Injector with rapid T x IA communication. Well History and Status: Endicott weIl2-54/Q-12 (PTD 1911220) has rapid T x IA communication. The well currently has sundry #302-344 for slow TxlA communication. A leak rate test conducted 9/29/03 indicated the leak rate has increased to 1 BPM @ 1875 psi. Recent Well Events: > 12/02/02: AOGCC issued Sundry #302-344 for slow TxlA comm > 09/29/03: LLR-IA 1 bpm @ 1875 psi > 10/31/03: Set TTP 10650' md, CMIT-TxIA Passed to 3000 psi, pull TTP, Set SSSV > 02/24/04: MITOA Passed to 3360 psi This Sundry request is to allow for continued water injection in this well. The following supports the request: . A CMIT-T x IA passed to 3000 psi on 10/31/03, indicating the production casing is capable of withstanding injection pressure. . A MIT -OA passed to 3360 psi on 02/24/04, indicating the surface casing is capable of withstanding injection pressure. . Pressure and injection rates will be monitored and recorded daily and checked for indications of a production or surface casing leak. Proposed action plan: 1. Allow well to continue water injection only. 2. Record wellhead pressures and injection rates daily. 3. Perform 2-year CMIT-T x IA. 4. Stop injection and notify the AOGCC if there is an indication of a loss of production casing integrity. ~. R.T. ELEV = 55.10' B.F. ELEV = 16.20' MAX DEV = 42:34° @ 6300' TREE: 6" I 5000 pJI ,W WELLHEAD: 13-5/8" 15000 psi I McEvoy 0 -c: SSSV LANDING NIPPLE I 1560' OTIS (4.562" I.D.) 13-3/8", 68#/ft, NT80CYHE, Btrs I 2735' ~ .. -c: 5-1/2", 17#/ft, L -80, NSCC HES DWP Retrievable 5-1/2" straddle pack-off assembly w/1" GLM (ID 2.340") OAL: 30.24' , I 3709' ~~ a GLM's (5/1" OTIS), (RA Latch) No. MD-BKB TVDSS l~ I~I 3913 10527 3833 9103 9-5/8", 47#/ft NT80S XO to NT95HS 5-1/2" 'X' NIPPLE I I 10560' I ~ - . ~ (4.562" I.D.) 9483' ,... -¿f;;; 9-5/8" PACKER I I BIG BORE WI 10569' g: ~ 5-1/2", 17#/ft L-80, TAILPIPE 5-1/2" 'X' NIPPLE I 10629' I OTIS (4.562" I.D.) 2-7/8" 'X' NIPPLE TOP OF 7" LINER ) ~ - REDUCER (2.313" I.D.) I 10650' I I-SET IN 5-1/2" 'XN' NIPPLE I 10656' > -r . OTIS (4.455" I.D.) (L - 9-5/8", 47#/ft, NT95HS, NSCC " 5-1/2" SEAL I I I I ~... 10661' 10925',... NIPPLE PERFORATING SUMMARY X l' 7" 'OTIS WD PKR W/4-1/2" I ' I Re'f. Log: - X & XN NIPPLES (3.725" 11737 CO SIZE SPF INTERVAL --E- MIN I.D.) SOS 4.5" 5 11788'-11881' SOS 4.5" 5 11894'-11940' I --E- 4-1/2"WLEG I 11752' I SOS 4.5" 5 11952' - 12062' sqzd PBTD 112137' 7", 29#/ft, L-80, Btrs- I 12175' TKC Date By Comments I ENDICOTT WELL: 2-54/Q-12 11/27/91 PC PROPOSED COMPLETION API NO. 50-029-22218 1/20/92 JLH COMPLETION . COMPLETION DIAGRAM 5/5/96 JTP SAN DBACK/CMNT 6/13100 MAS Tubing patch I BP EXPLORATION (ALASKA), INC I 11 941' I f NSU, ADW Well Integrity Engineer From: Sent: To: Cc: NSU, ADW Well Integrity Engineer Thursday, May 27, 20042:28 PM AOGCC - Winton Aubert (E-mail) Reeves, Donald F; NSU, ADW Well Operations Supervisor; Engel, Harry R; Francis, Michael J; McMullen, John C; Patterson, Teresa J. (VECO); Dube, Anna T Sundries in the Mail Subject: Hi Winton. We just put 3 sundry requests in the mail, addressed to you: END2-34: A 10-403 for rapid TxlA comm. END2-54: The well has gone from slow to rapid TxlA comm. There's a 10-404 to cancel the exiting slow TxlA comm sundry and a 10-403 for a new rapid TxlA comm sundry. NS27: A 10-404 to cancel the existing sundry. The RWO fixed the TxlA communication. Thanks for the help, let me know if you have any questions when you get the sundries. Joe (907) 659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 ~""}j ~,.,.., (''''~ r-' ~ \ r ¡~."'" ff\ C:, \ ,.,~" r::,~ ~"l Ù" '" .JUN 02ïOOl) Ala~.:!\;j Oil 2; LI',ilì 1 \1 ',~ ' ¡ 1 RECL,¢ED STATE OF ALASKA ALASKA OIL AND ~ COMSERVATION COMMON Mec~ Impaq, Tee~ NOV 28 199i' Alaska 011 & Gas Cons. CommJs~n Anchorage ~qJBlttG ~ON FLUID: P = PR~ WRTER tNJ, $ = ~ALT WATER eLI M = M~S¢~eU~ m~. SCANNED DEC 1 9 2002 ! -- IN,IE~ N = NOT IN,~CTIfa3 AIIIN;UI..~ FLUID: P.P.S. Grad, Ill/ELL 'lEI. T: DIESEL, ~.7 ~ 0.36 IrdtJal GL~ ~ ~-" 4- Y~ SALTWATER '~ - ' - 0.~ ~~r~ ~ILLI~ ~ ~ 0.~ ~er o~_ ~, .. A~ REP SIGNATURE OPERATOR REP SIGI~TURE dATIF2DOJCL$ SENT BY :ARCO ALASKA 907 276 7542;# 1/ 4 · 11-27-97 ' ? ? ? Zc,_~ ............ ,s(:;,~,~g'.i(~-..~-~-ib.~':i' ................. R C t-E?'EO ................ · .,, ~..... ~--...-- ....................... ~.~,,q~ ~- ..~. q~..~ ...... ~... . ....... ' .................................................................................... ~i'OIl'l"Oa~ ~. Oommissio~ ............. Anchorage .. -,~l~m,, ~....~, .,.,.,,.,. ,,,~, i~.~ ,, ,, ,~...~.l ,.,..,, ............... -- -,P,~,~ ........................- ..... , ............. ' ............ ~'~"-~ ........... · , , . Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: C~ ~_ ~{ ~D DATE Re: Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to ddil. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or multilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E E 'L E W ATE R IA L U N D ER TH IS M A R K ER ARCO Alaska, Inc. Post Office Box 10~! Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 26, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Well 1R-18 Deepen API 50-029-22188 Permit Number 91-120 Kuparuk River Unit Well 1R-21 API 50-029-22211 Permit Number 91-113 Kuparuk River Unit Well 1R-23 API 50-029-22200 Permit Number 91-101 Gentlemen: ARCO requests cancellation of permit to drill for Kuparuk River Unit 1R-18 Deepen, and requests approval of revised applications for permit to drill wells 1R-21 (now horizontal to old bottom hole location of 1R-18 Deepen) and 1R-23 (now drilling to old bottom hole location of 1R-21). Drilling operations have not yet started. We appreciate your patience in this matter. If you have any questions, please contact Ellen Fitzpatrick at 263-4638. Sincerely yours, A. Wayne McBride Area Drilling Engineer ALASKA OIL AND GAS CONSERVATION COMMISSION September 20, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1R-18 DPN ARCO Alaska, Inc. Permit No. 91-120 Sur. Loc. 698'FSL, 214'FEL, Sec. 18, T12N, R10E, UM Btmhole Loc. 1904'FSL, 629'FEL, Sec. 7, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to deepen the above referenced well. The permit to deepen does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. ~David W. -~ohnst~n, Chairman Alaska Oil s Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AIJ~,-,KA OIL AND GAS CONSERVATION COMM,,..,.,ION · PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill m Redrill _ ~ lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil X Re-Entry _ Deepen XI Service _ Development Gas ~ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc, RKB 88', Pad 45' GL feet Kuparuk River Field 13. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628 ALK 2561 !4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 698' FSL, 214' FEL, Sec. 18, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (TARGET) 8. Well number~..,,~ Number 1405' FSL, 599' FEL, Sec. 7, T12N, R10E, UM 1R-18 O¢~.t #U630610 At total depth 9. Approximate spud date Amount 1904' FSL, 629' FEL, Sec 7, T12N, R10E, UM 20-Sept-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1R-12 9864' MD 1904' @ TD feet 119' at 400' MD feet 2437 6693 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400' feet Maximum hole angle 90° Maximum surface 2310 psig At total depth (TVD) 3483psicj @ 6693 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~l Weic~ht Grade Coupling Length k/E) TVD lVD TVD linclude stage dataI 24 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' 222 SxASI 12.25 9.625 36.0# J-55 BTC 5275' 43' 43' 5318' 4028' 1070Sx. PFE HF-ERW 8.5 7" 26.0# L-80 NSCC 9821 43' 43' 9864' 6693' 300 Sx Class G Top 500' above Kuparuk 1{). To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 5350' feet Plugs (measured) EZSV @ 4490' MD true vertical 4049' feet Effective depth: measured 4490' feet Junk (measured) true vertical 3500' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 8 0' 1 6' 222 SX AS I 1 2 3' 1 23' SurfaCeproductionlntermediate 5275' 9-5/8" 1070 Sx PF E 5318' 4028' Liner Perforation depth: measured 4155'-4175' S'~P true vertical 3 2 78'- 3 2 91' AlasJ(a 0ii & 6as Cons. 60mm_issie.f 20. Attachments Filing fee ~ Property plat __ BOP Sketch _.)[. Diverter Sketch _ Drilling program" Drilling fluid program X~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements X~ 21, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/'~ ~//~/~'~ Title Area Drillincj Engineer Date ~,~/~/ Commission Use Only ~ern~i_[ Number APl number~ ~ ~ I~ Approyal~ (;late! I otherSee coVerrec~uirementsletter for i~/'j ... /~O I 50- O.2.,~-~ .,- ~ _~. N o Mu~l'10g required __ Yes ~No Conditions of' 'approval Samples required __Y e ~ /~//~' Hydrogen sulfide measures __ Yes ~ N o Directional survey required ~ Yes__ N o Required working pressure for ROPE ~2M; .~ 3 M; __ 5M' __ 10M' __ 1 5 M Oth~~~ ..... by order of ~//~ Approve(T~ ..~ ~,~(~ ~J ~,~. %~ Commissioner the commission Date ~ ! Form 10-401 Rev. Submit in triplicate DRILLING FLUID PROGRAM (1R-18) Drill out to Weight up weight up to TD Density 9.0-9.6 1 1.0 PV 5-15 10-18 YP 5-8 8-12 Viscosity 30-40 35-50 Initial Gel 2-4 2-4 10 Minute Gel 4- 8 4 - 8 APl Filtrate 8-1 0 4- 5 pH 8.5-9 9.0-9.5 % Solids 4- 7 1 0-1 2 Drilling Fluid System; - Tandem Brandt Shale Shaker - Tandem Derrick Shale Shakers - Solids Processing System to minimize drilling waste - Mud Cleaner, Centrifuge, Degasser - Pit Level Indicator (Visual and 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 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2310 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The surface hole portion of 1R-18 has already been drilled and cased. The nearest well to 1R-18 is 1R-12. The minimum distance between the two wells is 119' @ 400' MD. The wells diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the annulus of the last well drilled. The annulus will be left with a non-freezing fluid during any extended shut down (<4 hrs)in pumping operations. - The annulus will be sealed with 175 sx of cement followed .b~ylarcti(Dpack upon completion of fluid pumping. ~C VE P 1 ? ~r..~.~ Gas Cons. Commission Anchorage ARCO AI ASXA, Structure · Pad 1R Well · 18 Field · Kuparuk River Unit Location ' North Slope, Alaska Created by ' jones Date plotted : 13-Sep-91 Plot Reference is 18 Lateral Version #7. Coordinates are in feet reference slot #18. True Vertical Depths are reference wellhead, --- EASTMAN CHRISTENSEN --- <-- West 1200 1000 800 600 400 200 0 200 400 TD LOCATION: 1904' FSL, 629' F-EL SEC. 7, T12Nr RIOE N 3.5 DEG W 5999' (TO TARGET) TARGET LOCATION: { TARGET - T/ 14.05' FSL, 599' FEL 1 SEC. 7, T12N, RIOE TARGET T/ Zo,~ 3200 'A/0=6695 · DEP-5999 0 NORTH 5987 0~ 3400~ WEST38.5 T/ Zo,qe Cl ! T/ Za~ea C-234 ~000]. 50'004~'~"x TIE-IN POINT 7VD=3895 TMD=5250 DEP=2998 ® '~] 44.°0 : ECEIVED > _ AVERAOE A~OLE ~ ~.~_ "~5:5-D'E'C-'- ~aS~a,Oil & Bas Cons. Commissio~ ~ ~- Anchorage - TARG~ - T/ A3 - FINAL LOG ~_ WD=6693 TUD=9364 DEP=5999 TARGET ANGLE m ~=6693 TM0=9864 0EP=6499 90 DEG 70~ I I I I I I t I I [ I I I I I I I I t I I I I I I I I I I I I ScoIo 1 : 100.00 Ve~Ical Section on 356.~2 azimuth with reference 0.00 N, 0.00 E from sial -7000 -6800 -6600 -6400 _ -6200 _ -6000 _ -5800 _ -5600 _ -5400 - -5200 5000 48O0 - -4660 _ - 44430 - -4200 - -4000 - -3800 - -3600 - -3400 -3200 - -3000 -2800 -2600 - 300 250 200 150 100 50 5O lO0 150 200 150 100. 50 0 50 100 150 I I I I ;00 I '~ 1400 3600 ~'t1200 34ob ~ 1000 ~ ~oo :~oo , R CEIV' D soo ~ $ ~P t 7 IB9~ 400 Alaska Oil & Gas Cons. Commission ~000 ~800 8OO ,~oo ~ 2OO I I I I I I I I I I ")nn '~ .'=;n '~ no $o o 50 1 oo 1 50 200 _ 350 _ 3OO .250 _ 200 .150 . 100 .5O .0 _ 5O _ 100 150 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-18 Squeeze Temporary Disposal Interval and Drill to Kuparuk 1. Move in and rig up Pool Rig 7. 2. Install and test BOPE. 3. Pull injection tubing and packer. 4. Cement squeeze disposal perforations at 4155'-4175'. 5. Drill out cement and pressure test squeeze. 6. Drill out cement and 10' of new hole. Perform leak off test. 7. Drill 8-1/2" hole to TD according to directional plan. 8. Log with LWD equipment. 9. Run and cement 7" casing. Pressure test to 3500 psi. 10. ND BOPE and install temporary production tree. 11. Secure well and release rig. 12. Run cased hole cement evaluation and gyro logs. 13. Move in and rig up Nordic #1. 14. Install and test BOPE. 15. Perforate and run completion assembly, set and test packer. 16. ND BOPE and install production tree. 17. Shut in and secure well. 18. Clean location and release rig. ,6 , I I I I 5 I I 13 5/8" 5000 JI BOP STACK 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 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 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. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'FI'OM PIPE RAMS. TEST BO'I-rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND 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 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSi CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED $ E P 1 7 1991 ~(~;~,Cji ,& Gas Cons. Com[nissio~ '", Anchorage SRE 8/22/89 CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE D~TE/ [2 ~hru ~ (3) Adm in /~/~( ~/~//~ ~ [~ thru ~3] ' [10 & 13] [14 thru 22] (5) BOPE ~~,,~ [23 thru 28] (6) Other /~Oc, ~/~./~.~ [29 thrU'31] (6) Addl ~.~. ~/~-~/ Company ./~, '~~ 1. Is permit fee attached ............................................... e 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is well to be located in a defined pool ............................... Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & n~nber ................................ 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 & surface ............ Will cement tie in surface & interTnediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. 29. 30. 31. 32. ,geology' DWd eng i nee r ing MTM ~ LCS.~:~:"~ BEW RAJ). JH~ rev 03/29/91 jo/6.011 IN'ITIAL GEO1 UNIT ONIO~'F POOL CLASS STATUS AREA ~ SHORE 0 --I -cZ ,'-~ 0 cr~ ..-!