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Home My WebLink About191-073Pages 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. //~/-~7~ 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. [] Other, No/Type OVERSIZED · · · n · Logs 'of various kinds [] Other COMMENTS: Scanned by: Beverly Dia~athan Lowell Date:~.? is/ n TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2 2000 E E PL E W M A TER IA L U N D E TH IS M A.R K E R C:LORIXMFILM. DOC R Memorandum To: State of Alaska Re: Oil and Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE: Point McIntyre 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 reddils 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 ddil. The APl 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 (welibore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ALASKA OIL AND GAS CONSERVATION COMMISSION May 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 Ancorage, Alaska 99510-0360 Re .' Well No. Kuparuk River Unit 1R-30 ARCO Alaska, Inc. Permit No. 91-73 Sur. Loc 336'FSL, 144'FWL, Sec. 17, T12N, R10E, UM Btmhole Loc. 336'FSL, 2038'FWL, Sec. 17, T12N, R10E, UM Dear Mr'. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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 mechanical integrity of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3) before operation. Please contact the commission at least 24 hours before pressure testing so that a representative of the commission may witness the test. r'man Alaska Oil'~3~as Conservation Commisison BY ORDER OF THE COMMISSION dlf/Enclosure CC.' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Posi Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Application for Permit to Drill KRU Field Well 1R-30 (Permanent Disposal) Attached is an application for Permit to Drill for the above referenced well. This well will be used for permanent disposal of drilling fluids and other fluids incidental to the Kuparuk River Field. The plan for handling these fluids utilizes a solids processing module to eliminate the need for a reserve pit at Drill Site 1R. Most, if not all, of the drilling fluid waste would be pumped down this well instead of the annulus of the previously drilled well. The exact injection interval will be selected from open hole logs of the well. After log analysis of the well, the 9-5/8" casing would be run to 4,6',I.7' MD or 4,1~I~'~ TVD. A CBL would be run to ensure cement integrity, the well pcN'Torated, and a packer and tubing run for the completion assembly. We have reviewed the likelihood of formations in this well having recoverable hydrocarbons, and anticipate that the Ugnu and West Sak sands are water wet in this area of the Kuparuk River Field. A final decision on 1R-30 will have to be made after review of the open hole logs. If for any reason that this method of disposal is impractical, ARCO would utilize annular pumping that has been standard procedure in the past. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdCompany RECEIVED ~,laska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Either Mark Prestridge or myself would be happy to visit with you further if you need more information regarding the project. Thank you for your assistance in this matter. Sincerely, A. W. McBride Area Drilling Engineer AWM/MLP attachment RE( EIVED ~AY 1 ? 1991 Alaska 0ii & Gas Cons. CommisSiOn Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlardicRichfieldCompany Ali:~l/ (;()07, (; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill [~ Redrill D I lb. Type of Well Exploratory [-] Stratigraphic Tesl r"] Development Oil [-] Re-Entry ["] Deepen r-~I 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 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25635, ALK 2568 4. Location of well al surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 336' FSL, 144' FWL, Sec. 17, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1 R-30 #UG3061 0 At total depth 9. Approximate spud date Amount 336' FSL, 2038' FWL, Sec. 17, T12N, R10E, UM 7/1/91 $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 1 R- 1 6 4, 6:2,,7' MD 3242' @ TD feet 60' at SURFACE feet 2448 4,1 ~¢~I'VD 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 30° Maximum sudace 2482 psig At total depth (TVD) 2030 psig 18. Casing program Settin(~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~lht Grade Coupling Length IVD TVD IVD 'rVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 43' 43' 123' 123' +200 CF 12.25" 9.625" 36.0# J-55 BTC 4,634' 43' 43' 4,6?--7-' 4,19"3' 750 Sx AS III & HF-ERW ~.7 5'0 450 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. 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 ~.a~jrfd~c~el~ ~ True Vertical depth ur , Conductor Surface Intermediate Production MAY 7 t99t Liner Perloration depth: measured Alaska 0ii & Gas Cons. true vertical An(~h0rage 20. 'Attachments Filing fee [] Property plat r-] BOP Sketch [~ Diverter Sketch ~' Drilling program ~ Drilling fluid program ~J' Time vs depth plot r-] Refraction analysis D Seabed report D 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L/~,~'~,~ ~..' Title Area Drillin~ En(:jineer Date ~"",/~/ Commission Use Only Number IAPI number IApprova, date05/20/9]_ ISoo cover letter for Permi/.~.. 7~ 50- O ~--~P -" ~..Z,/ 7 7 r recluirements Conditions of approval Samples required D Yes No Mud log required r"] Yes No sulfide measures [] Yes ~' No Directional survey required ..~' Yes r"] No Hydrogen Required working pressure for DOPE D 2M .~ 3M ~] 5M r~ 1OM r'~ 15M Other: o~ by order of Appr Commissioner the commission Date ~ ./ Form 10-401 Rev.-~/~'-2'4=89 -- ' - - Sd iplicate 200 _ 150 _ 100 _ 50 _ O m 50 _ 100 _ 50 0 50 1 O0 1 50 200 250 500 35O 5000 [ '400 .800 2800 3200 ""1"00"0 ~ zSO-~ '"12'0O' °'T4'O0 _ 200 I I _ 150 _ 100 " i I I i I I I i ~ 50~ 100 50 0 50 1 O0 1 50 200 250 :300 :350 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1R-30 Permanent Disposal Well , . . . . el . 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Pool 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,6[7' MD). Log well with open hole wireline logs from TD to surface. Run and cement 9-5/8" casing. Pressure test to 2800 psi. ND diverter and install 11" 3000 psi casing head. Run cased hole cement evaluation logs. Install and test BOPE. Rig up wireline and set bridge plug and permanent packer. Run 7" casing from surface to below permafrost (1,762' MD). 7" casing is not cemented. Run 2-7/8" tubing. Displace hole with diesel. Stab into packer. ND BOPE and install injection tree. Pressure test tubing annulus to 1500 psi. AOGCC representative must witness pressure test. Shut-in, secure well, and release rig. Perforate well with wireline. NOTE: All operations will comply with the following regulations, set forth by the AOGCC in the Alaska Administrative Code, Title 20, Chapter 25: ( I ) Article 1, Section 030: Casing and Cementing (2) Article 3, Section 252: Underground Disposal (3) Article 5, Section 412: Injection Well Casing RE( EiVED 1 ? t991 Alaska Oil & Gas Cons. CommiS~'ton Anchorage RECEIVED Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids DRILLING' FLUID PROGRAM (1R-30) Spud to 9-5/8" surface .casing 9,0-10,0 15-35 15.35 50-100' 5-15 15'40 10'12 9-10 10% ± Anchorage Drllllna Fluid .System: T~ndem B~,a-ndt Shale Shakers 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 'i'i~[~'~'prac~Jc~es Will be in accordance W'iti'i"i~l~'-e' appropriate regulations stated in 20 AAC 25.033. Maximum anticipated sudace pressure ts 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 2482 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1R-30 is 1 R-16. As designed, the minimum distance between the two wells would be 60' to surface. The wells would diverge from that point. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds, ARCO ALASKA, II10. Structure: Pad 1R Well' 30 Field ' Kuporuk River Unlf Loooticn : North Slope. Alosko te ~i~tt~d ~ 13-Way-gl ~,o,, ': ,oo.oo East --> I ! I I I I ! I [ I I I I ! I I I I ! I I I I J.00K°P T~"4~° TMD"4°° pcP"° ~~ 3~' rSL, 4#dv rv¢l ,.UPARUK RIVER UNi. 20" DIVERTER SCHEMATIC I I 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF TH IS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) R ¢EIVED ~AA¥ 1 ? t99t Alaska 0il & Gas Cons, commissior~ 1. 16" CONDUCTOR ;Anchorage 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION lB. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/61 ,6 , 5 4 3 , I 13 5/8" 5000 F,.,i BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC 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 STACKAND 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. TESTALL 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 PREVENTORAND MANUAL KILLAND 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 NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTFOM 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 WEEK AND 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 Oil & Gas Co s. Commission Anchorage ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE [2 thru 8] (4) Casg ~.v.~'.- -, - [14 thru 22] [23 thru 28] [29 thru 31] geology' eng i neer i ng~ DWJ~g-~ MTM_~ LCS ~/-~ rev 03/29/91 jo/6.011 Company 1. Is permit fee attached ............................................... 1 3. 4. 5. 6. 7. 8. 1 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 .................................. Lease $ We 11 ~./~,,z~_ 2 3',~.~ ~' ' ~~ /~- ~ YES NO RE~RKS / ,- __ . ......... L 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 & nLrnber ................................ 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 & intermediate 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 3~.~. 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. INITIAL 'GEo1 UNIT ON/O'FF POOL CLASS STATUS AREA ~ SHORE 'L