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Home My WebLink About192-004THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M L A T E E E W T E R IA L U N D ER H IS M A R K ER C:LOR1WIFILM.~ Memorandum State of Alaska Oil ~md Gas Conservation Commission To: Well File: C~ ~. _ ~~3C~ DATE Re: Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX AP1 # 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 AP! 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 ddli. 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 AP! numbering methods described in AOGCC staff memorandum "Multi-lateral (weiibore segment) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 25, 1992 Mr. David W. Johnston, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Well 3R- 14 APl 50-029-22241 Permit Number 92-04 Kuparuk River Unit -~' ~°",~C., ¢4..,'~/,~ ~. ~~ ~. Well 3R-17 ~-- ~ / APl 50-029-22242 Permit Number 92-05 Dear Mr. Johnston: ARCO requests cancellation of approved permit to drill for Kuparuk River Unit "~'~-, 3R-14, and requests approval of revised application for permit to drill 3R-17 due to bottom hole location change. 3R-17 will now be drilled to the bottom hole target permitted in 3R-14. Drilling operations have not yet sta~ed. 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 RECEIVED MAR 2,5 1992 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION January 17, 1992 AWMcBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well Name: Kuparuk Ri 14 Company ARCO Alaska, Inc. Permit No: 92-04 Sur. Loc. 1872'FNL, 2403'FWL, Sec ~oc. ll90'FNL, 1683'FWL, WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 /. , R9E, UM Dear Mr. McBride Enclosed is the ap~ referenced well. to drill the above The permit to drill does permits required by law authorize conducting permitting determinati¢ overnmental agencies, and does not )perations until all other required lade. Blowout prevention equ. (BOPE) must be tested in accordance with 20 AAC 25.035. notice (approximately 24 hours) of the BOPE test performed befo drilling below the surface casing shoe must be given so that )sentative of the Commission may witness the test. Notice may by contacting the Commission petroleum field ins Slope Pager at 659-3607. .ncerely, avid W. Chairman 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 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r'l I b Type of Well Exploratory [] Stratigraphic Test r-1 Development Oil X Re-Entry ~--1 Deepen D Service D Development Gas D Single Zone X Multiple Zone D 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 52', Pad Elev: 11' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 355023, ALK 3573 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1872' FNL, 2403' FWL, Sec. 9, T13N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1315' FNL, 1815' FWL, Sec. 9, T13N, RgE, UM 3R-14 #UG30610 At total depth 9. Approximate spud date Amount 1190' FNL, 1683' FWL, Sec. 9, T13N, RgE, UM 2/3/92 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3R-13 (proposed) 7,038' MD appx 1683' ~ TD feet 24' ~ 1300' MD feet 5175 61806' TVD feet 16. To be completed for deviated wells '~ 17. Anticipated pressure (se~ ~5.035(e)(2)) Kickoff depth 4500 feet Maximum hole angle2,,9 o Maximumsu~face 2411,,,/ pslg At total depth (TVD) 3500 pslg 18. Casing program '~ Setting Depthf size Specifications \ Top ~// Bottom Quantity/of cement Hole Casin~ Weight Grade Coupling Length ~ MD TVD //'MD TVD linC~iude sta~le data) 24" 16" 62.5# H-40 Weld 80' 4~' 41' ~4'21' '121' -t-200 CF/ 12.25" 9.625" 36.0# J-55 BTC 4031' 41~, 41' // 4,072' 4,072' 590 Sx I:~rmafrost E & .... HF-ERW , ,'~ / , , 375 Sx Class G 8.5 7 26.0# J-55 BTC 6997 41 '~ 4~ 7,038 6,806 160Sx Cla~sG HF-ERW \// Top 500' ab~ove Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. /~X, Present well condition summary /~ Total depth: measured feet / 'l~ugs (measured) true vertical feet/~ Effective depth: measured feet/ Junk (~easured) true vertical fo~ ~ Casing Structural Length Size / Cemented ~ Measured depth True ~ertical depth ~u°r~dacuect°rE C E IV 'l~rtoe; umc~oina te ~~ - - P erforati pth: trrnue~S~retidcal ~ Alaska 0il & Gas Cons. C0m / ;Anchorage 20. Attachments Filing fee X PT~"perty plat D BoP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs dep~th plot D Refraction analysis D seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is tru~and correct to the best of my knowledge Signed ~'~//~/.,~'-',~/'~/ Title Area Drillincj En~ineer Da to //,~/~ ~., - ~ - / ' Commission Use Only Per ~_,t~ Number I APl nur~ber J Approva, date I see cover letter for ~'~;~ --~) ~; 50-~ .;~ '-~- ~ ~_ ~:- ~/" j/ ~ [ ~ .._./4;;;:~, other requirements Conditions of approval S/amplesrequired ,~? Yes I'-I No Mud logrequired ,~ Yes r'l No Hydrogen sulfide measures D Yes ~ No Directionalsurveyrequired ,~ ~es O No ; Required workingpressureforBOPE D 2M ~ 3M D 5M D 10M D 15M Other: Appr ,, Commissioner the commission Date Form 10-401 Rev. 7-24-~,..~ Submit in triplicate DRILLING FLUID PROGRAM WELL 3R-14 Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 9.0-10.0 9.0-9.3 10.3 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 API Filtrate 10-12 8-10 4-5 pH 9-10 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 <10-12 Drilling Fluid System: - Tandem Brandt Shale Shakers - Triple Derrick Shale Shakers - Solids Processing System to minimize drilling waste - Mud Cleaner, Centrifuges, 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/ff. This shows that formation breakdown would occur before a surface pressure of 2411 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3R-14 will be proposed Well 3R-13. As designed, the minimum distance between the two wells would be 24' at 1300' MD. The wells would 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 surface/production casing annulus of the last well drilled. That 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 by arctic pack upon completion of fluid pumping. Spud mud should be adjusted to a funnel viscosity between 100-120 sec/qt to drill gravel beds. RECEIVED JAN - t992 Aiaska Oil & Gas Cons. Commissio~ Anchorage ARCO ALASKA, Structure' Pad 3R Well ' 14 Field · Kuparuk River Unit Location ' North Slope, Alaska Created by ' jones For: FITZPATRICK / BRADLEY Date plotted : 26-Dec-91 Plot Reference is ]4 Version t4. Coordinates ore in feet reference slot Frue Vertical Depths ore reference wellhead. EASTMAN ~CHRISTENSEN A Boker Hughe~ c~mpany N 46.55 DEG W 810' (TO TARGET) <-- West 1000 900 800 700 600 500 400500 I I I I I I t I I I I I I I I I 400 8oo ~ - 1200- _ 1 BO0- ('~2000- - 2400- 2800- - 3200- - 3600- - 4000 - 4400- _ - 5200- 5600- - 6000- 6400 6800 7200/ TD LOCATION: [ 190' FNL, 1683' FWL SEC. 9, T15N, R9E PERMAFROST 'P/D= 1692 / TARGET LOCATION:[ ~ 1515' FNL, 1815' FWL SEC. 9, T15N, RgE TARGET TVD=6472 TMD=6655 DEP=810 NORTH 557 WEST 588 T/ UGNU SNDS TVD=2742 T/ W SAK SNDS TVD=5482 B/ W SAK SNDS TVD=5872 K-10 TVD=3927 L 9 §/8"CSG PT T'VD=4072 KOP "rvo=¢500 TMD=4500OEP=O 3.00 g.o0 5.00 BUILD 5 DEG / 100' 21.00 EOC TVD:5414 TMD=5454 OEP=233 TARGET - T/ KUP SNDS TVD=6472 TMD=6658 DEP=810 T/ ZONE A '[VD=6553 TMD=6750 DEP=85¢ 8/ KUP SND$ TVO=6630 1'M0=6858 OEP=B96 TD / LOGGING PT TVD=6806 TMD=7038 DEP=992 I I I I I i 0 4O0 80O 12O0 AVERAGE ANGLE 28.61 DEG Scale 1 ' 50.00 200 1 O0 0 I I I I I 100 - 900 _ - 800 L 700 - 500 J 400 Z 300 200 1 O0 -- 0 1 O0 O0 SURFACE LOCATION: J 1872' FNL, 2403' FWL SEC. 9, T13N, R9E RECEIVED JAN - 5 t992 Alaska Oil & Gas Cons. L~ommissio~ Anchorage Scale 1 ' 50.00 East Z200 2250 2300 2350 2400 2450 2500 2550 2600 ARCO ALASKA, Inc. Stm~,',: Peal 3R Field: Kuparuk River Unit Location: North Slope, Alaaka 2650 1550 1600 1650 500 2OOO 1800 ~3200 RECEIVED ,)AN - ~ t99~ ,A)aska Oil & Gas Cons. OommissiOn Anchorage 1700 -1750 -1800 -1850 -1900 - 1950 - 2000 -2O5O I I , , , 10 11 12 13 14 15 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3R-14 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED JAN - ,3 3992 A~a~ka Oil & Gas Cons. Commission Anchorage 7 , 6 5 I3 13 5/8" 5000 PS1 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 12(X) 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. 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 PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST 8. ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO'I-rOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 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 Alaska Oil & Gas Cons. Commission Anchorage ~.UPARUK RIVER UNI'I 20" DIVERTER SCHEMATIC HCR I ' J 5 4 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., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 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 6. 20" - 2000 PSI ANNULAR PREVENTER J ECEIVED J,,,'-,,N - 3 ~992 Alaska 0il & Gas Cons. Commissio~ Anchorage SRE 2/6/90 CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATI~ (2) Loc /' [2 thru 81 (3) Adm i B~']~; ' E9 thru 13] ' : E~o ~ ~3~ [14 thru 22] (5) BOPE '~,,~--~.~/..-,,~-'~/ [23 thru 28] ., [29 thru '313 geol · DWJ og~_:.~ eng i nee r i ng] MTM~-~ LCS ,'-/: ,, RPC/~/~ BEW ,~. RAD]) ~- ~ ~ - ~ ~ rev 03/29/91 jo/6.011 CompanY 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property iine ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6 Is well to be deviated & is wellbore plat included.. .... 7 Is operator the only affected party ................ 8 Can permit be approved before 15-day wait. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. Does operator have a bond in force .................. ' ................. Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nL~nber ................................ Is Wil to Is Wil Wil Wil Is Is Is NO ' RE~RKS conductor string provided ......................................... 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. ~ . .. enough cement used to circulate on conductor & surface ............ ~ 1 cement tie in surface & intermediate or production strings ...... ~ 1 cement cover all known productive horizons ..................... ~ ..... 1 all casing give adequate safety in collapse, tension, and burst. ~ well to be kicked off from an existing wellbore ................... '~ old wellbore abandonment procedure included on 10-403 ............. 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 2000 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... requirements ............................................. ~ 32. Additional Additional ,/ ~ , , INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,,. ~ ,./ ~/ . 0 -rZ ~0