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HomeMy WebLinkAbout190-154XHVZE ? 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,~ Num~ o, w~,, H,s,o~ ~,,e PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED · [] ' "' Logs'of vadous kinds . [] Other COMMENTS: Scanned by: E~ve~ Dian~an Lowell [] TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 E E P L ,~': ~A E W M A T E R IA L U N D E THIS MARKER R C:LORBMFILM.DOC Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: q~)-- G[~'~¢' DATE Re: Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well file. Our adopted conventions for assigning AP! 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 muitilaterais 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 ddll. 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 AOGC, C staff memorandum "Multi-lateral (wellbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMains ' r Statistical Technician February 22, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOP¥: (907) 276-7542 J. D. Gillespie Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Arroyo State' #1 ARCO Alaska, Inc. Permit No. 90-154 Sur. Loc. 889'FSL, 501'FEL, Sec. 22, T12N, R14E, UM Btmhole Loc. 761'FNL, 1024'FWL, Sec. 27, T12N, R14E, UM Dear Mr. Giilespie: 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. Sufficient notice must be given to allow for a representative of the commission to witness the BOPE installed on the surface casing and a test of same prior to drilling out the surface casing shoe. Sin. cerely~ ~-~ · Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 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. :'-'J~' Post Office b~,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 !215 February 11, 1991 D.W. Johnston Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak 99501-3192 Subject: Arroyo State #1 Dear Mr. Johnston: As per our phone conversation on January 8, 1991, with Russ Douglas of your staff, the attached velocity profile is provided to augment the Permit to Drill for the above referenced well. The profile shows no anomalous Iow velocity intervals and hence, no over pressured zones are expected. Thank you for your help in this matter. Sincerely, ., : '-'.'/ (/_ //(-" ~.~ ~..D. Gillespie,./ RegionaJ Drilling Engineer /czm ARCO Alaska, Inc. is a Subsidiary of AtlantfcRichfJeldCompany /.,t~ -:~, ;~, :- C ARCO Alaska, Inc. Date: Subject: Internal Correspondence January 28, 1991 Velocity Analysis for Arroyo State # 1 From/Location: D.A. Fisher - ANO 878 Telephone: X6031 To/Location: J. Schumacher - ATO 1456 Attached is a plot showing the results of conventional stacking velocity analyses carried out in October, 1990 by Halliburton Geophysical Services Inc. Their analysis of the surface seismic data provided the root-mean- square (RMS) velocity function shown on the graph from which the average and Lnter~;al velocity ~.~nctions were derived. This study was carried out on line PM902D-370 at cdp 192 which is appro~dmately 1300 feet north of the proposed bottom hole location for Arroyo State # 1. There are no anomalous low velocity intervals, and no over pressured zones are expected. D../L Fisher dvh XC: Well File - ANO 879E D. Suchomel -ANO 896 ARCO Alaska, Inc. is a Subsidiary of Atlant/cRichfietdCompany AR3B-6001-B ..... I-- .... I-- I I I I I I .~ I ..... I-- '1 I I I I I I I I I I. .I I__ .... I__ __ __/ __ I I I I ! I I ! I I I I I I I I I I I I ..... I ..... I .... t-------I---- ~--- INTERVAL I~_ I ~~,1 .... L. _ _ --I .... VELOCITY I I -I .... I"' - - --I- I I I I I I I ! I ! I I I I I I I ! I I 100. AVERAGE RMS INTERVAL TRANSI'I' TIME (MICRO-SECONI~/F'OO'F) DRTE - 01/24/91 ~TIME - 15: 33:35 LINE PM902D 1.'S"70_ XL.,,. VELOCITY VELOCITY I I I I I 1 150. ARCO Alaska, Inc. Post Office b~,x 100360 Anchorage, Alaska 99510-0360 ~? ,one ..... 276 ! 5 January 3, 1991 Alaska Oil and Gas Conservation Commission Attn' Mr. Mike Minder 3001 Porcupine Dr. Anchorage, AK 99501-3192 Subject: Arroyo State #1 Dear Mr. Minder: As per our phone conversation on December 31, 1990, on the Permit to Drill for the above referenced well, ARCO Alaska, Inc., does plan to drill 10' of new formation then perform a Leak-Off-Test on both the 13-3/8" and 9-5/8" casing strings prior to proceeding with drilling below these casing strings. The revised steps to the Proposed Drilling Procedure are shown below. 3. Drill 10' of new formation. Perform leak off test as per AOGCC regulations. Record and plot test results. Drill 12-1/4" hole to 7092' TVD / 8037' MD holding angle and direction. Drop angle from 31 degrees at 7092' TVD / 8037' MD to 19 degrees at 7747' TVD / 8755' MD. TOH. Run open hole logs and extract sidewall cores. RIH condition hole. 5. Drill 10' of new formation. Perform formation integrity test to 12.5 ppg EMW in accordance with as per AOGCC regulations. Drill 8-1/2" hole to TARGET at 7797' TVD / 8810' MD. Core well as required. Drill 8-1/2" hole to TD at 8576' TVD ! 9634' MD. TOH. Run Open-Hole logs and extract sidewall cores. RIH condition hole. Thank you for your help in this matter. Sincerely; ///J. D. Gillespie~' /,,,/ Regional Drilling Engineer ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany /,i:'-.i,', ,V,r:: C .... STATE OF ALASKA ' ~ ~ , NFIDENTIAL ALASKA _~,L AND GAS CONSERVATION PERMIT TO DRILL la. Type of work Drill.~ Re-Entry - 20 AAC 25.005 Redril,----I lb. Type of well. Exploratory,~ Stratigraphic Test Deepen ?1 Development Oil Service -- Developement Gas ;_- Single Zone - Multiple Zone 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 889'FSL, 501'FEL, Sec.22, T12N, R14E, UM At top of productive interval 652'FNL, 1269'FWL, Sec.27, T12N, R14E, UM At total depth 761'FNL, 1024'FWL, Sec.27, T12N, R14E, UM 12. Distance to nearest property line Target 652' feet 13. Distance to nearest well Pt. McIntv #5 Surface '~[~' 16. To be completed for deviated wells 3 1° Kickoff depth 5cc' feet Maximum hole angle 18. Casing program size Hole Casing 30" 20" 16" 13 -3/8 12-1/4'i 9-5/8" 12-1/4'] 9-5/8" 8-1/2" 7't 19. 5. Datum Elevation (DF or KB) RKB 4 2 ' feet 6. Pr~p~t...y I~jsj. i~lnation ADL: 28300 7. Unit or property Name N/A 8. Well number Arroyo State #1 9. Approximate spud date 12/15/90 i14. Number of acres in property feet 2 5 6 0 o 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2 9 8 0 psig At total depth FrVD) Specifications Weight I Grade/Coupling I Length 91.5#I H-49 Weld [ 80' To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: 10. Field and Pool Wildcat 11. Type Bond ise~ 2o ^AC 25.025) Statewide Number No. U-630610 Amount $200,000 15. Proposed depth (MD and TVD) ~ "~D feet 4265 psig Setting Depth Top Bottom MD TVD ] MD I 35' 35'I 115r 34' 34'I 3716r Quantity of cement TVD (include stage data) 115' 2000# ?oleset 3400' 1200 sx AS III/300 sx 4500' 7747' 8576' None 800 ax' ~1G 18b'"~x' C± ~ measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface I n termed i ate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth RECEIVED NOV 1 1990 '." 20. Attachments Filing fee ~ Property plat ~ BOP Sketch :1~ Diverter Sketch~ Drilling program ~ Drilling fluid program .[~"'Time vs depth plot ~ Refraction analysis [] Seabed report Q 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge · Commission Use Only (DN) PD4¢Q12 Permit Number [ APl number [ Ap..p..ro~La,I ~,te |See cover letter ?o I50--Oz..~'- ~ ~./O ¢z ~/-Z~/-bLL~ /for other requirements Conditions of approval Samples required ~ Yes [] No Mdd Icg required ,.,t~ Yes [] No Hydrogen sulfide.measures ~ Yes ,,~ No D rectional survey required ,,~ Yes Q No Required working pressure for BOPE []2M; [] 3M; ,i~ 5M; [] i0M; [] 15M Other: /; ;: by order of ; ' Commissioner the commission Date _7__ . zz -'i ~ , Approved by ~ /~.~,,._~ (_~ Form 10-401 Rev. 12-1-85 Submit in triplicate 'G' . . . ...... . -- ,,.CONFIDENTIAL Arr,.-.. State ~ Proposed Drilling Proc .u MIRU Pool 5 or other comparable ddlling rig. Drill 16" hole to 500' MD / TVD. Kickoff and build angle at 2.0 degrees / 100' MD to 31 16' degrees in a S 66 16' degrees W direction. Drill to 3400' TVD / 3716' MD. TOH. Run and cement 13-3/8" casing. NU and test BOPE. Drill 12-1/4" hole to 7092' TVD / 8037' MD holding angle and direction. Drop angle from 31 degrees at 7092' TVD / 8037' MD to 19 degrees at 7747' TVD / 8755' MD. TOH. Run open hole logs and extract sidewall cores. RIH condition hole. 4. TOH. Run and cement 9-5/8" casing. . Drill 8-1/2" hole to TARGET at 7797' TVD / 8810' MD. Core well as required. Drill 8-1/2" hole to TD at 8576' TVD / 9634' MD. TOH. Run Open-Hole logs and extract sidewall cores. RIH condition hole. 6. T©H. Run and cement 7" liner. Clean out well. 7. Install dummy hanger and dry hole tree. Release drilling rig. 8. Run cased hole logs. . 10. MIRU completion rig. Run completion string as needed after reviewing open-hole logs. Release completion rig. Perforate and stimulate, if needed, and flow test well to temporary production facilities, taking production logs as needed. NOTE: Excess non-hazardous fluids developed from well operations and as necessary to control the fluid level of the reserve pit, will be pumped down the annulus of an approved near by well, until such time after 9-5/8" casing is set in Arroyo State #1. The Arroyo State #1 annulus will be left with a non-freezing fluid dudng any extended interruption in the pumping process. The Arroyo State #1 annulus will be sealed with cement followed by Arctic pack upon the completion of the pumping process. o The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. o Maximum surface pressure is based on a BHP of 4265 psi at 8576' TVD, less a 1500' TVD oil column, less a gas column to surface. The wells within 200' are: No wells exist within 200'. Hazardous levels of H2S are not anticipated while drilling th~~. ~ ~ [ ~} ,j. 1990 ~ *~ ~® ~'~ ~ ,_..l:, ~,lIPIIntl~,l~l?l · I '"' I I I ' ' I I ' I ' I I , I ' I I ' I I I f I I I I ' I I I I I I I I I I I I I I I I I I '~ ' ' ' 3 .~ RK~ EI~ATION 42' 20" C~g ~=~15 ~115 D.. ~ AR( O A OYO-1 6.0 8.0 1000 1~0 ~4.o SHL: U 12N 14E 22 889' FSI. 501' FEL ~16.0 ' ~8.o ~L: i~o B~: U 12N 14E 27 761' m' 1024' ~2a.o S 66 16' ~.0 ~OST ~1836 ~=1889 DE~329 2~0 ~19~ T~=20~ D ~16 3~ ~g ~=~ ~=3"16 D~=1273 4~0 A~GE ~'G~ ~ 31 16' ~5~ ~[~3 DE~I~2 98 T~8 D~=2 5~ ~00 ~STS~ ~92 T~=7333 D~=3152 K-12 ~=66~ ~7565 D~=3~2 BOD ~::7092 T~=8037 D~ EOD ~~ ~=8651 DE~3~78 ~ t~.~ 9-5/8' CAS~G ~4~ K-10/8~B~ ~=77~ T~E'P ~=~7~ ~88 L0 D~=3829 8~0 ~/K-~ ~8~ T~=~ K~: TOP ~8277 K~ BASE ~=83~ ~ ~=8576 ~~ DE~8 ~0 ' I ............................................................. 0 1~0 20~ 3~ 4~ 5~ 6000 7~0 ~RTICAL SECTION 10000 '~ I J INI-li II'INI ! IR! TVD=115 TMD=115 ~o~ ~o AR¢?.O ALASKA, I/'~'C. ~o OYO 1 ..o ARR - 6.O 8.0 ,I0.0 C~/'~ A T ~'. 2 12'0 SHL: U 1 !N 14E 22 889' FSI, 501' FEL ~.o THL: U 1 >.N 14E 27 652' FN2 1269' FWL 18.0 xo° BHL: U 1 ~-N 14E 27 761' FNL, 1024' FWL S 66 16' '3:::1987 TMD=2064 D1~--416 tg TVD=3400 TMI~-3'~ 16 DEP=1273 AVERAGE Al'q GI,.E -- 31 16' TV~-4500 TMD=:[003 DEP=1942 - 8~8 TMI~5468 DEP=2:.84 Wl ST SAK ~92 T VID=-7333 DEP=31$2 K-12 TVD=~90 ?MD=7565 DEP=3272 BOD TV~.:7092 TMI~8037 DEl: II 21.3 EOD TV1~7647 TM1~8653 DEP=-3778 9-5/8" CASING 'IVD=7747 TMD=8755 DEP=-3811 _ K-10/SEABEE TVI~7797 TMD=88~ DEP=3828 - TARGE'F TVD=7797 TMD=88 10 DEP=3829 HRZ / K-~ TVD=8047 TMD=9lr/ 3 DEP=3914 KUPARU31TOP TVD=8277 TME~9316 DEP=3993 KUPARUK BASE TV1~-8387 TMD=9433 DEP---4031 ~ D ......... i ........................................ 1000 20(10 30~ 5OOO 701)0 8000 10(KI0 0 1000 2000 3000 4000 5000 6000 7000 VERTICAL SECTION ARCO ALASKA, INC. ARROYO-1 S 66 16' W E - W COORDINATES -5000 -4000 -3000 -20(0 - 101X) 0 1000 2000 -6000 3000 2000 1000 Z-2ooo -5000 -6000 [}......... I ......... I r r I r r r I ~ Ir t I ~ ......................................... ) _ ' ................. i ..................................................... 30O0 · 2000 1000 -1000 -2000 -3000 -4000 -5000 -4000 -3000 -2000 -1000 0 1000 -5000 2000 00~ 00£ 00~ 00~ 0 00~ 00~: I. J I I I I I ,, 00£ - 003 - 00[ - ~mm 00l - 00~ - 00£ - 00t~ ' l I I I 00~ 00£ 003 o0~ ~...~ _006 .,.- O01g .*,,-' 00£ & ~ ~ i OOg l.., ~ I I I I I I { ' 00~ I I ' 00£ I oot o oo t ooZ - - ,[ 00~ OOS CONFIDENTIAL Arroyo State #1 Proposed Mud Program DEPTH DENSITY YP INT 10 min FL OIL SOLIDS (TVD) (PPG) VIS (#/ft GEL GEL cc/30min (%) (%) MUD TYPE Surf 8.8 300 70 30+ 50+ 25+/- 0 to to to 13-3/8 9.9 100 40 Csg Pt 8 Gel-Benex Spud Mud DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) MUD TYPE 13-3/8 8.8 5 2 2 5 15 0 2 tO tO tO to tO tO to to 9-5/8 10.2 10 10 5 12 10 6 Add .25-1.5 ppb excess PHPA polymer for torque and drag. LSND DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) MUD TYPE 9-5/8 9.7 10 10 5 12 8 0 4 to to to to to to to to 7 10.2 15 15 8 14 5 6 LSND 11000 PPM CL Add .25-.5 ppb excess PHPA polymer for torque and drag. Maintain as fine of screens as possible on the shakers to use 75% of screen area. Report the hours all solids control equipment is run and screen sizes on the mud report. This mud program is a guidline only. Actual hole conditions will dictate the actual mud properties needed. Any major changes should be discussed with the Drilling Superintendent or Drilling Manager. Do not weight up prematurely to control swelling shale in the K-shales. Use high vis sweeps as needed to clean hole. SOLIDS CONTROL EQUIPMENT' Shale Shakers Mud Cleaners Centrifuge Trip tank Degasser Pit Level Indicators (visual and audio) Fluid Flow Sensor Fluid Agitators Pool 5 Mud .. Syste,,, CONFIDENTIAL Pill Pit (49 BBLS) Pill Pit (59 BBLS) Suction Pit (274 BBL$) Reserve Pit (313 BBLS) (76 BBLS) I I I I (3) Centrifuges (2) Brandt Shakers (3) Derrick Flo-Line Cleaners IDegasserI (104 BBLS) IDesander I I DesanderI (104 BBLS) IMud CleanersI IMud Cleaners (104 BBLS) Trip Tank (96 BBLS) Other Equipment- (1) Agitator Per Pit (1) Drilling Flow Show Sensor w/ readout convenient to the driller's console (1) PVT Sensor Per Pit ARCO~ ~ALASKA, INC .... Accumulative Measured depth vs. Tim~. Date: 10/12/90 CONFIDENTIAL 1000' 2000' 3000' 5000' 6000' 7000' 8000' 9000' 12000 ii ~ Ru, anclce~entl3-!/8 :as~g .......... i ...................... i ........... ~X{- ..... i ...................... i ...................... ! ...................... l .......... , ........... l ..................... i .................... ! .................... i ........... .......... i ...................... ! ...................... i ...................... i ..... L og;--gi-de~ ratt--~-ore- --mnian-d cement-9--5/8"--cadn-gi ........... ~ ~ ,~ ,~ ~ ~ Drill and core 8-]/2" hole .......... ~ ............. L-6~;-'~-i-~ [~-~I'-6-6 ~;--~'fi--~ id-'~-~ it--7-"]l~'x ...... [ ..................... t .................... ~ ...................... : : : : ~ ~ ~ ', ! ~ : ;~ ~ ~" Run!cogtplet}on , t abing ~ ~ , , , .......... ~ ...................... ~ ...................... ~ ..................... ~ ...................... ~ ...................... ~ ..................... ~ ..................... i ...................... ,~ ...................... ~ ........... , , , .......... ~ ..................... ~ ...................... ; ...................... ; ..................... ; ...................... ; ..................... ~ ..................... . .................... x ..................... ~ ........... ~ I ' ~ " ' ' " " I " I ' I ' 4 8 12 16 20 24 28 32 36 40 Estimated time Time (days) Arroyo State #1 CONFIDENTIAL Refraction analyses for the detection of surface gas have been performed on wells previously drilled in the area and would be available for viewing in our Anchorage office as desired by the Commission. The Arroyo State #1 well will be drilled adjacent to the Pt. Mclntyre #5 well (approx 500' to NW drilled during April 1989) which did not encounter any surface gas. Other Pt. Mclntyre wells drilled in the vicinity likewise did not encounter any surface gas therefore, Arco Alaska, Inc. requests an exception to AOGCC regulation article 20 AAC 25.061 (a). Similarly, the drilling of several wells in the Pt. Mclntyre area have indicated no abnormally pressured zones based on actual mud weights. The sonic Icg plot for Pt. Mclntyre #5 is attached. The maximum mud weight during drilling was 10.2 ppg, however the mud weight was increased to 11.2 ppg while logging and running open hole logs to help control sloughing shales at TD, no over-pressured gas was encountered. Therefore, Arco Alaska, Inc. requests an exception to AOGCC regulation article article 20 AAC 25.033 (e) (1). ,,g/S-6 ,,g/8-8 L mIaim IIImlmimii mlImm..Imlmiliilim mlImIimmm imilim IImmlmml ilmml~ imm ~miii iiimiiI, .::::: '.."'.:::' :.'.'.":: ::: :-:-':.'".:: ',.-.--:~ ......................... :::::: ::. ::: :::::: :::::: :::::: ::::::: :::::: ::.-,-:-:: :- ...... ....... ii~ ............ i ...... :::::~ -':- --.:: :o :' :::!~ ....... :::::: ::::.t::::: :::::::::::: ::::: ::::::::= :::::.;~:.iii .................. i ..... .................. , ....... ::1: .... ~,-, ................. %- .............................. ~ .... ~,., · Illl. Iii .Ill ~ I~I --I~ IlIIl' ,ImI~ II Illm, ,lliiI IIlilIl, i.~mIl, IlmI~IlmmlI ~1111 i, .III , I I ... I .~ III II .III. Il I I II ~., ................... '~ .......................... ' '"!" O00,E :::::: lu@!peJ~.--:;~: ............................ ,.-. ...... !!!::::!:: :::::::::::: ':::::::::: !::::::!! ::::::!:: !::!!!t!!!::!~!::!!! !!! ::! '-:::: ::::: :::::::::::::::::: :::: ..... ~u~,o~ .... ~ i ooo~ ',::::: :::::: :::::: :::::: :::::: ::::::: ::: SO-~d',:::: (UOllefi ]od spunod) e~nsse]cl 0000~ 0OO6 O00g O00Z OOO9 O00S O00P 00£ OOl OS (y/oesfl) ~v · ON eJ~UlOlAI ~U!Ocl 1VIIN]O IJNOS ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER . LEVEL WITH HYDRAULIC FLUID. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH BPMIPE RAMS~ ND RA~ SPOOL [~ CASING ~ SPOOL ~IPE RAI~~ BRADEN HEAD 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 THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 1 5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES . 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PRESSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PiPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DALLY. Surface Hole Diverter System ARCO Alask~ In~ FILL-UP LINE RISER FLOWUNE I 20" 2000 PSi DIVERTER I 11:7' BALL VALVE 1(7' BALL VALVE I 1. I CONDUCTOR I NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT MNE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. RESERVE PIT 1(7' VENT LINE 10" VENT UNE DIVERTER LINES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEE~ ~f:, ,~.,. ,~/ (8) , (10 ~ ~). (14 :hr= (29 :~ 31) rev: 01/30/89 6.011 - 1. Is =he pe-~'--i= fee ar=ached ,. .......................................... . Z. IS ve!l no' be locauad ia a dali:ed pool ............................. 3. is well locaued proper ~tsr~ce ~r~m property. ]_i~e .................. ~ 4. Is we J_! iota=ed proper di~=znce ~r~m o:her yeLLs ........ ; ........... ~_ 5. is suffiaie~= undedica:ad acreage avs_i!able in :his pool ............ 6. Is veil =o be deviaued and is ve~_lbore pla: ia~luded ................ 7. Is opera:or =he c:ly affecued parry. ................................. /~ 8. Ca: permi: be approved before fif:een-day ~ai= ....................... .f 9.' Does opera=or have a bond in force .................................. 10. IS a aonser~a=ion order needed ...................................... 1!. I~ a~:inis=Ta:!ve approval needed ................................... 12.' IS :he !a~se number appropriaue ........................... 13. Does :he we!_l have a un/que ~e and number ..................... ' .... 14. IS c6nducuor s:~-~§ provided ........................................ , ,, 15. W~ sur~2ace casing prouac~ ~]~ zones reaso~h!y ~ecued se~e ~ ~ ~dar~o~ source of dr~g ~a:ar ..................... 16. ~ ~ou~h c~en: ~ed :o ==~a:a on conducxor ~d s=~aaa ......... 17. W~ c~: =ia ~ ~rface ~d ~a~e~a or produc~ la. W~ ~1 c~= cover -~ ~ producx!ve hor~o~ ..................... 19. ~ ~ c~~ ~ive adequa:a s~a~y ~ co,apse, 20. ~ :~ ~e~ :o be ~c~d off ~rom ~ ~=~E v~ora ............. , ,., 21. Is old w~bora ah~do~: procedure ~c!udad on 1~03 ............ ~. ~ adequa:a ~e~bora separz:ion proposed ..................... 24. Is ~e ~~~ fled pro~r= s~e~=ia ~ ~s= of eq~pm~: ~. ~e n='=ass~ ~a~r~ ~d desc~p=icns of ~ve~ar 26. Does BOPE ~ve s~ici~: pras~re ra=~8 - Tes: :o 17. Does ~e ~oka ~oid c~17 ~/~I ~-53 (~y 84) .................. ,, , ~. ~ ~e pr~ea of H2S Sas probable ............................. =... ~or ~iora:o~ ~ S=ra=i~aphic we~sr 29. ~a ~=a prasen=~d on po=~=i~ ~e~ress~a zones? ................. 30. ~e se~c =~7=is ~=a pres,=ad on sh~~ ~ zones .............. 31. ~ ~ offshore loc., =e ~e7 ras~:s cf seabed con~=ions , , , il I Ill ' I1 , 11 I I I Il . , Il Ill I 1111 ~ 32. Addinional requireme:rm .............................................