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Home My WebLink About191-071XHVZE Pages NOT Scanned in this Well History File 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~) 7/File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: [] Gmyscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED . . · [3 ' Logs-of various kinds [] Other COMMENTS: Scanned by: ~ver~ Dia athan Lowell TO RE-SCAN Notes:- Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: is/ THE MATE~AL ~DER THIS COVER HAS BEEN . MICROFILMED II ON OR BEFORE NOVEMB ER 2,, 20.00 E E PL E W MATERIAL U N D'E TH. IS M A R K ER R Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: ~ I '" 0 ~ r-~ ~ DATE Cancelled or Expired Permit Action EXAMPLE- Point Mclntyre P2-36AXX AP1 # 029-22801-95 This memo will remain at the from of the subject well ~e. 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 redrills and or muitilaterals 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 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 AP! numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician WALTER J, HlCKEL, GOVERNOR PHONE: (9~ ~-1~3 Nay 2 0, 19 9 Z TELECOm: (~ 2~7~2 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Well No. Kuparuk River Unit 1L-27 ARCO Alaska, Inc. Permit No. 91-71 Sur. Loc. 536'FNL, 217'FWL, Sec. 32, TllN, R10E, UM Btmhole Loc. 1795'FNL, 1726'FWL, Sec. 4, T10N, 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 Commission will advise you of those BOPE test that it wishes to witness. SinCerely, . ~Chairman Alaska O~1~ Gas 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 OIL AND GAS CONSERVATION ION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill I~ Redrill L.]I lb. Type of Well Exploratory r""l Straflgraphic Test r""] Development Oil Re-Entry I--! Deepen I"1I Service r""! Development Gas r""l single Zone I~1 Multiple Zone I--I i Z. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB 129'~ Pad 86' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O, Box 100360~ Anchorage, AK 99510-0360 ADL 25663~ ALK 472 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 536' FNL, 217' FWL, Sec. 32, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1375' FNL, 1290' FWL, Sec. 4, T10N, R10E, UM 1L-27 #UG30610 At total depth 9. Approximate spud date Amount 1795' FNL,-1726' FWL,. Sec. 4~ T10N~ R10E~ UM 6/7/91 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MB and TVD) property line 1 L-1 9 11,878' MD 1,726 ' ~ TD feet 27' ~ 661' MD feet 2560 6,367' TVD feet 16. To be completed for deviaied wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 350 feet Maximum.hole angle 63° Maximum ,ur~ace 2155 p$1g At total depth (TVD) 3090 pslg 18. Casing program Settinc~ Depth size specifications Top Bottom Quantity of cement Hole Casing Weight Grade Couplin~l Len~lth . IVD TVD IVD TVD (include sta~e data! 24" 16" 62.5# H-40 Weld 80' 43' 43' 209' 209' :]:,?.00 CF 12.25" 9.625" 36.0# J-55 BTC 5878' 43' 43' 5~921' 3~640' 880 Sx AS III & HF-ERW 650 Sx Class G 8.5" 7" 26.0# J-55 BTC 11835 43' 43' 11~878' 6~36,7' 230 Sx Class G HF-ERW Top 500' above Kuparuk 19. To be comidated 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 Meas~d~l E I VuE~i~ical depth Structural Conductor surfaca MAY 1 6 t99! Intermediate Production *~l~as~(:a 0il & Gas Cons. Commission Liner ;Anchorage Pertoration depth: measured true vertical 20. Attachments Filing fee [] Property plat I--i BOP Sketch J~ Diverter Sketch I~ Drilling program Drilling fluid program I~ Time vs depth IdOl r"l Refraction analysis I'1 Seabed report I"1 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~//~~ Title Area Drilling Engineer Date"-- - / ' ~" , Commission Use Only ~/, 7/ , 50- O Z'~P - ~, ~ / 7 -~ 0 5 / 2 0/9 1 o~j~r require, ments Conditions of approval Samples required r"l Yes ,J~ 'No Mud log required !"1 Yes~ No Hydrogen sulfide measures D Yes ,,~ No Directional survey required ~1 Y' D No Required working pressure for BOPE r""! 2M I~ 3M r"""l 5M r""! 10M r"! 15M Other: Appr Commissioner the commission Date~J1 O / DRILLING FLUID PROGRAM (1L-27) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.6-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 1'0% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Weight up to TD 10.3 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling Fluid System: Tandem Brandt 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 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 2155 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest Well to 1 L-27 is 1 L-19. As designed, the minimum distance between the two wells would be 27' @ 661' MD. The wells would diverge from that point. 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 of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) 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 FV between 100-120 sec/qt to drill gravel beds. RECEIVED 1 6 t991 ;Alaska 0il & Gas Cons. uomm%ss~on Anchorage [ARCO ALASKA, Inc. I Structure · Pad 1k Well · 27 Field · Kuparul< River Unit Location · North Slope, Alaska Irreated by : jones For: E FITZPATRICK ate plotted : 13-May-g1 lot Reference is 27 version #2. oordinotes are in feet reference slot ~27. ue Vertical Depths are reference wellhead. I-J~EASTMAN IZ~IIICHRISTENSEN A IOk~ "u~# S 46 DEC 4 MINE 8821' (TO TARGET) 100o- _ 1500 ~ _ 2000- _ 2500- - . ¢o00- ~- _ _ SURFAC£ LOCATION; I 556' F-NL, 217' FWL SEC. 52. TllN, RIOE _,.,,,.,:,o,,.oo East--> 0 800 18IX)2400 521X}4000 ~800 5800 6400 7200 iiiiiiiiiiiiiiiiiii TARGET LOCATION: I sec. +: TION, RI0E TARGET 1V0=6055 TMD-11198 DEP-8821 SOUTH 6119 FAST 6355 -1600 -24~0 - 6400 7200 RKB ELEVATION: 150' 3.00 KOP 1¥D=350 TMD=550 DEP=O 9.00 15.00 BUILD 3 DEC/lO0' TO LOCATION: I 21.00 1795' FNL, 1726' F'WL 27.00 I SEC. 4, TION, RIOE } ~9x ;°x ~.%° E~ ~2048 TMD-2~2 ~U SN~ ~-2405 'D=3222 ~P=1729 ~ B/ W ~ SNDS ~D~ TMD~84 DEP~37~ ~E~E~N~AVERAGE ANGLE ~ Alas~ Oil &AnchorageGaS Cons uu~misst0~ TMD=9286 OEP=7121 B/ KUP ~DS ~6275 ~D-11678 OEP-92~ - TD / L~ING PT ~-6~7 ~D-11878 DEP-9426 Scale 1 ' 250.00 i ~ i i i i i i i i i i i i i o ~o 10oo ~soo 2ooo 2~oo 3o0o 35oo Vertical Section on 135.92 azimufh wifh reference 0.00 N, 0.00 E from slof i~27 1 O0 1 50 200 250 300 ;350 400 I I I , I I I I 35O 400 450 500 550 SOO ~50 700 . 750. - I ............. ~ 350 I _ i soo I _ 400 I I I I - -,~oo [ _ soo i '~soo -,~o ",~ oo , - ~-~,. ~ ~ , . sso I . -'~oo ~ ~ m '~ ~ ~oo ~ ~ -,~oo ~ ~~~ _ i ', '-~oo ~ q'~~ ~oo - I ,,oo '~4°°'' .... ' [~ RECEIVED , , I .... u~X.~ ~ ~ ..... ,~.. ,, ~oo - ~.Off & Gas_~on~. u~,,,~mss~u,, ~ ~ 100 . Anchorage las~ j ...... 750 I I I I ~ I I 1 O0 1 50 200 250 300 350 400 · . . . . . . 8, . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1 L-27 Move in and rig up Pool Rig 7. Install diverter system· Drill 12-1/4" hole to 9-5/8" sudace casing point (5,921') according to directional plan. Run and cement 9-5/8" casing· Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to logging point (11,878') according to directional plan. Run open hole evaluation logs. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 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 MAY 16 lggl ~I~ ,Oil.& 6as Cons. ~,u,i,nJsslon ,,, I I 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUMC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLO~E 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~ P~I 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 KILLAND CHOKE LINES. 6. TESTTO 250 PSI AND 3e0~. PS, AS IN STEP 4. 7. 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 ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(X)0 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF 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 ENES 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" - 2(X)0 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 MAY 16 t99! Alaska 0ii & Gas Cons. bummission Anchorage PARUK RIVER UN . 20'" DIVERTER SCHEMATIC 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 THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) RECEIVED MAY 16 t99t 1. 16" CONDUCTOR Alaska Oil & Gas Cons. Commission 2. SLIP-ON WELD STARTING HEAD AJtCtl0r~ns-"u 3. FMC DIVERTER ASSEMBLY WffH ~O 2-1/16~ 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SP~L WITH ~O 10" OU%ETS. 5. 10" HCR BALL VALVES WI~ 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNU~R PREVEN~R. VALVES CAN BE RE~TELY ~N~OLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNU~R PREVENTER SRE 2J6/ ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE . · [2 thru 8] . (4) Casg ,~.~~, ~'-t~-~)'/ [1~ thru 22] (5) BOPE ~.~'-/7-~/ [23 thru 28] Other [29 thru 3i] (6) Addl 1 2 3 4. 5 6. .-7 9. 10. 11. 12. 13. Company Is perrnit-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 pemit be approved before 15-day'wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease mmber appropriate ................................ .......... Does well have a unique name & n~nber ................................ Lease g Well YES J '~:-:::~ NO REMARKS "~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 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,~~ 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 ' eeeeeeee..eeeeeeeeeeee~eeeeeeeee..e..e, eeeee O 'rz ~O geo 1 ogy · eng i nee r i ng: gWd MTM. ~ LCS~ RPC,/('~/~ BEW ~ RAD ~ - . ,JH/' rev 03/29/91 jo/6.011 INITIAL GEOI UNIT ON/OFF POOL CLASS STATUS AREA # SHORE Additional remarks: