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Home My WebLink About192-003THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M E E · L E W A T E R IA L U N D ER T'H IS MARKER C:LORI'uM~ILM.IM~ 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 drill. 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 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 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 OfficI Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 23, 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-13 API 50-029-22240 Permit Number 92-03 (~Kuparuk River U/nit Well 3R-10 API 50-029-22253 Permit Number 92-26 Dear Mr. Johnston: ARCO requests cancellation of approved permit to drill for Kuparuk River Unit 3R-13, and requests approval of application for permit to redrill well 3R-10A. 3R10A will be drilled to the same bottom hole target as was permitted for 3R-13. Plug and abandon operations on 3R-10 were verbally approved by Mike Minder on March 20, 1992, and were completed March 22. Sidetrack operations to drill 3R-10A are beginning March 23. 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 jUI ~iaska Oil & (Jas Cons. Commission gnchorag~ ALASKA OIL AND GAS CONSERVATION COMMISSION January 17, 1992 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: Well Name: Kuparuk River Unit 3R-13 Company ARCO Alaska, Inc. Permit No: 92-03 Sur. Loc. 1849'FNL,2395'FWL, Sec. 9, T13N, R9E UM Btmhole Loc. 1443'FSL, 754'FEL, Sec. 4, T13N, R9E, 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-3607. ~;i~i ~a~'~~~h~~i~;' ~oh na ~va 2t i on 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 2O AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory D Stratigraphic Test ri Development Oil X Re-Entry D Deepen r'l Service D Development Gas D Single Zone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. 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, Anchora~le, AK 99510-0360 ADL 355023, ALK 3573 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1849' FNL, 2395' FWL, Sec. 9, T13N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1225' FSL, 895' FEL, Sec. 4, T13N, RDE, UM 3R-13 #UG30610 At total depth 9. Approximate spud date Amount 1443' FSL, 754' FEL, Sec. 4, T13N, RDE, UM 1/20/92 $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-14 (proposed) 8,222' MD 3837 ~ TD feet 24' ~ 1300' MD feet 5175 6,905' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 1300 feet Maximum holeangle 38° Maximumsudace 2440 pslg At total depth (TVD) 3490 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit)/of cement Hole Casing Weight Grade Coupling Length MD TVD MD 'rVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 4628' 41' 41' 4,669' 4,122' 680 Sx Permafrost E & HF-ERW 420 Sx Class G 8.5" 7" 26.0# J-55 BTC 81 81' 41' 41' 8,222' 6,905' 165Sx ClassG HF-ERW Top 500' above Kuparuk 1 9. 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 Measured depth True Vertical depth Structural sCuOZ:cU:O RECEIVED Intermediate Production LinerJ: ,N - 3 399?- Perforation depth: measured Alaska 0il & Gas Cons. C0mmiSSi0~ true vertical Anchorage 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed j~.~ ~~~' .. Title Area Drilling Engineer Date ~/~ff~/~._- - ~/ ~ ' Commission Use Only Permit. J~,umber I APl number I Approve, d.._at~, ~',~,.... I See cover letter for y 2,,~~- ~) ,~ 50-C~ ~.Z_' ,~- ~ ~?- ;~. ~' ~:~'~ ~ - other requirements Conditions of approval Samples required r'~ Yes ~ No Mud log req~ed r'] Yes ~ No Hydrogen sulfide measures D Yes .'~ No Directional survey required /~[J Yes [~] 'No Required working pressure for BOPE rD 2M ~ 3M r"] 5M [-~ 10M D 15M Other: by order of /~7,~.~ App Commissioner the commission Date ~f ; .. Form 10-401 Rev. 7-2~4-89 ~it in triplicate DRILLING FLUID PROGRAM WELL 3R-13 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 10.4 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 2440 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3R-13 will be proposed Well 3R-14. 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 REC£1Vrr. D Alaska Oil & Gas Cons. Comm~ssiOO Anchorage ARCO ALASKA Structure · Pad 3R Well · 1.5 Field · Kuparuk River Unit Location · North Slope, Alaska Created by ' jones For: BRADLEY / FITZPATRICK Dote plotted : 26-Dec-91 Plot Reference is 1.3 Version #4. Coordinates are in fee( reference stat True Verticel Depths are reference wellhead. 2ffEASTMAN ~CHRISTENSEN N 32.92 DEG E 3662' (TO TARGET) o 0 o o · ' 400 -8 800 co 1200 - 1600- _ (~2ooo- q) - ~ 2400- - 2800- 0 - 3200- (D - 3600- 4000- 4400- 4g00- 6400- 6800- RKB ELEVATION: 52' 3000 300 600 900 1200 1500 1 BO021 O02400 2700 3000 I I I I I I I I I I I I I [ t I I I I I I TARGET LOCATION t225' FSL, 895' FEL SEC. 4, T13N, R9E TARGET '[VD=6577 IMD=7804 DEP=3662 NORTH 5074 EAST 1990 ID LOCATION: I 1443' FSL, 754' FEL SEC. 4, T13N, R9E -390D _ -3600 _ -3300 _ -2700 2400 ~2100 - -1800 - -1500 1200 KOP TVD=1300 TMD=1300 DEP=O 3.00 900 9.00 15.0~/ PERMAFROST TVD=1697 TMD=1700 DEP=42 600 21.00 BUILD 3 DEC / 100' ~-- 27.00 300 '~x 33.00 x~ EOC TVD=2488 TMD=2582 DEP=¢14 0 ~ T/ UGNU SNOS 0 '%. TVD:2772 TMD:2945 DEP:640 ~ J SURFACE LOCATION: '% J184g' FNL, 2395' FWLI 30o o I SEC. 9, T13N, R9E I T/ W SAK SNDS TVD=$547 TMD:5955 DEP:1256 %x D/ w SAK SNDS TVD=5922 TMD=4413 DEP=1553 ~'~~0 AVERAGE ANGLE 38.46 DEG RE, CEIVED T/ ZONE A TVD=6696 TMD=7921 BEP=5755 % % % m~ _ B/ KUP SNDS TVD:6748 TMD:8022 DEP:.3798- xx,,x~ amsKa Oil & Gas Cons Commission TD / LOGGING PT TVD:8905 TMD=8222 DEP=3922 ...................... Anchorage 400 800 1200 1600 2000 2400 2800 3200 5600 4000 Scale 1 ' 200.00 Verfieol Section on 32.92 azimuth with reference 0.00 N, 0.00 E from slot ~13 Scale 1 ' 50.00 East _)200 2250 2300 2350 2400 2450 J I I I I I I I I I I ARCO ALASKA, Inc. Structure: Pad 3R field: Kuparuk River Unit Location: North Slope, Naaka 2500 I I 2550 2600 I I I I 2200 2650 I I 1550 1600 1650 2OOO RECEIVED Alaska Oil & Gas Cons. CommissiOn ;Anchorage 1700 - 1750 - 1800 - 1850 -1900 -1950 -2000 -2050 0 I I 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3R-13 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 d t,N - ,] t992 · Alaska Oij & Gas Cons. Commission Anchorage 7 , 6 5 4 I I 13 5/8" 5000 P,.51 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 KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE UNES. 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 3(X)0 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 BOTTOM 9. RAMS TO 250 PSI AND 3(X)O PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD 11. AND 12. UNES 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 KdPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC 5 i HCR j \ 6 4 3 I 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 RECEIVED AJaska OiJ & Gas Cons. CommissiOn Anchorage SRE 2/6/90 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE /~ATE '[~ Lhru.,'~3]'':~ ~-- C9 ~hru<;~3 ~ [10 & 13] [14 thru 22] (5) BOPE /~/t,,"?/",~, ?-~ - ~f [23 thru 28] (6) Other /~'~,' '['29 t h'i~u 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. 29. 30. 31. 32. Company ~, ..~...~ Is permit fee attached ............................................... 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 ngrnber appropriate .......................................... Does well have a unique name & n~rnber ................................ 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 ~O~ 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 ............................................. Lease & Well YES NO 0 ,--,0 geology' en9 i neer i n9: DW~ MTM ~ LCS RP,~ BEW~_,_, ~ J H,j-~ I/~ rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ~ 11 Additional remarks'