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Home My WebLink About189-040 © Pages 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. /~-~-~ F ileNu m berof Well HiStory File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is/ [] TO RE-SCAN Notes: Re-Scanned by: Beverly 8ren Vincent Nathan Lowell Date: ~si NOT~.,annecl.wl~ T_ttE MATEI~!AL MICROFILMED ON OR BEFORE E W May 24, 1989 ARCO Alaska, Inc~ Post Office~ ~/100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RES EN(~I~ SR ENG ~R ENG ENG ASS'I~ ENG ASST,.. - SR GEOL~I~ ~], GEOL ASST ~f~ GEOL ASST 0C( STAT TECH ~STAT TECH , _ FILE Ill , , Mr. C. V. Chatterton · Commi s s i one r State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Conductor As-Built Location Plat (Wel~ls~'and 38) Dear Mr. Chatteron: Enclosed is an as-built location plat for any questions, please call me at 263-4618. Sincerely, the subject wells. If you have D. Martin Engineering Aide DM: czm Enclosure RECEIVED MAY 2 6 1989 Alaska 0il & Gas Cons. Commission Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Telec~, (tO7) 276;7542 Re, P~oe: ]Say ~.DS 9-37 pe~t He, 89,'i40 · ~r, Lo~-. 1881'F~., iO60'FEL, See. 2, TIOH, R1SE, ~, Enclosed is abOVe pe~s r~r~ by~ ~ ~ e~lsove~nt~~e~es' and ~ no~ a~thor~ze c~et~aS ~L .~. ope~ae~s ~til all o~her h~a prto~ ~o e~e~ ~s~Ila.~ o~ ~ ~A~u-~ p~en~xon b~o~e, d~t!i~ below ~ sh~ o~ ~he eon~e~r p~P · C. V. A!as~'.~. OtI and Ga8 Conse2~,,a~ion Commission BY ~~ OF ~ 8~lSS]ON ~olosure Habitat Section w/o e~cl. ~V~~nmal Conservaelon w/o eric . PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill I~ Redrill ©1 lb. Type of well. Exploratory [] Stratigraphic Test [] .Development Oil [] Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone SE' Multiple Zone [] 2. Name of Operator 5. Datum ElevatiOn (DF or KB) 10. Field and Pool ARCO Alaska, Inc RKB 52' PAD 20'GL feet Prudhoe Bay Field 3. Address 6. ProDertvDesionation Prudhoe Bay 0il Pool ,.o. ^, 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1881'FSL, 1060'FEL, Sec.02, T10N, R15E, UN Prudhoe Bav Uni't: S~;at:ewide At top of productive interval (~ 8952'TVD) 8. Well nurpber Number 1450'FNL, 800'FWL, Sec.02, T10N, R15E, UN DS 9-37 U-630610 At total depth 9. Approximate spud date Amount 1401'FNL~ 108'FEL~ Se,'c.03~ T10N~ R15E~ UN 0~f/0;Z/{}~ $200.0o0 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Pr(~posed depth(MD and TVD) property line 108' ~ TD feet L~S66~D/~35'TVD feet 2560 ~)~'~D feet , 16. To be completed for deviated wells 26.4 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1 000 ' feet Maximum hole angle o Maximum surface 3071 pelg At total depth (TVD) 3 9 87 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade CouPling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110' 2000# poles~t; 17-1/2" 13-3/8" 68# K-55 BTC 20' 30' 30' 50' 50' 2000 sx C5 III & lj~# L-80 BTC 3159' 50' 50' 3209' 3000' 600 sx CS II 12-1/4" 9-5/8" 47# L-80 ~TC/Nod 9453' 30' 30' 9483' 8617' 500 sx Class G ~-1/2" 7" 29# L-80 BTC 909' 9183' 8348' 10092' 9161' 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Surface MAP, 2 9 Intermediate Production ~ OJ~ & Ga~ Con~. Liner '! Perforation depth: measured true vertical 20. Attachments Filing fee ~' Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program (~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify th,~t~ foregoing is true and correct to the best of my knowledge~ · --'r". ~?~~.,¢.,~/,,~ Date 3/Z¢1~ Signed /,. Title Regiona3 Drilling Engineer ~ Commission Use Only ((;$W) PD3/074 ~ Permi_.t Number APl number I Approval date I See cover letter ~;~rd~~i~~~~s~pe~p~surSe~mp~e~f~;qu~d~N~~r-]~iiYr~es;~ct~~n~a~~~u~;!~i~~~u~~~~~Yr~sN~~ fNOor other requirements Required working pr sure f_or BOP I~M; [] 3M_; ~5M; [] 10M; '[] 15M Other: , n ~e.~: /,]' ~/,/ ~/ __ /"" j '"~/' /" .~/"~__...,..~,~J ' by o rd er o f i//// Approved by ( /_ ,-j", ( "_~'~~ Commissioner the commission Date Form 10-401 Rev.~-1-85 , Subrf i triplicate 1. MIRU drilling rig. PBU DS 9-37 OPERATIONS SUMMARY 2. Spud well and drill 17-1/2" hole to 500' and kick off. Build angle at 2.5°/100' to 26.4° at N 60-0 20' W. Drill 17-1/2" hole to 3000' TVD, 3209' MD. 3. Set 13-3/8" casing and cement same. Test casing to 2500 psi for 30 minutes. NU BOPs and test. 4. Pickup 12-1/4" bitandBHA. Drill 10' of new hole and perform leakoff test. Drill to 6552' TVD / 7175' MD. 5. Run wireline logs as programmed. 6. Drill maintaining angle and direction to 8617' TVD, 9483' MD (10' TVD above the Sadlerochit Sand). 7. Set 9-5/8" casing and cement same. Test casing to 3000 psi for 30 minutes. . Drill 10' of new 8-1/2" hole and perform formation integrity test to 12.5 ppg EMW. Drill 8-1/2" hole to TD at 9161' TVD, 10,092' MD (100' MD below the Base of the Sadlerochit). Please note that two 10' pressure cores will be taken in the Sadlerochit interval. 9. Run wireline logs as programmed. RECEIVED 10. Set 7" liner and cement same. lldaalftl.OllS' GaS ~. 11. Cle~ out liner and test casing to 30~ psi for 30 ~nutes. Ckculate we~ to brine and ~eeze prot~t ~ ~esel. 12. Release rig. Run cement evaluation logs and gyro after rig release. 13. MIRU completion rig. Run 5-1/2" tubing and packer assembly. Nipple up 5-1/2" tree and test to 3000 psi. Notify the AOGCC 24 hours in advance to final pressure testing of casing, tubing, packer and tree. 14. Rig up wireline and perforate. 1. MIRU drilling rig. PBU DS 9-37 OPERATIONS SUMMARY 2. Spud well and drill 17-1/2" hole to 500' and kick off. Build angle at 2.5g/100' to 26.4~ at N 60°- 20' W. Drill 17-1/2" hole to 3000' TVD, 3209' MD. 3. Set 13-3/8" casing and cement same. Test casing to 2500 psi for 30 minutes. NU BOPs and test. . Pick up 12-1/4" bit and BHA. Drill 10' ofnew hole and perform leakoff test. Drill to 6552' TVD / 7175' MD. 5. Run wireline logs as programmed. 6. Drill maintaining angle and direction to 8617' TVD, 9483' MD (10' TVD above the Sadlerochit Sand). 7. Set 9-5/8" casing and cement same. Test casing to 3000 psi for 30 minutes. 8~ Drill 10' of new 8-1/2" hole and perform formation integrity test to 12.5 ppg EMW. Drill 8-1/2" hole to TD at 9161' TVD, 10,092' MD (100' MD below the Base of the Sadlerochit). Please note that two 10' pressure cores will be taken in the Sadlerochit interval. 9. Run wireline logs as programmed. RECEIVED MAR 2 9 tg~9 10. Set 7" liner and cement same. ga~l~l.~il.&' {;as Cons. 1 I. Clean out liner and test casing to 3000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. 12. Release rig. Run cement evaluation logs and gyro after rig release. 13. MIRU completion rig'. Run 5-1/2" tubing and packer assembly. Nipple up 5-1/2" tree and test to 3000 psi. Notify the AOGCC 24 hours in advance to final pressure testing of casing, tubing, packer and tree. 14. Rig up wireline and perforate. PBU DS 9-37 OPERATIONS SUMMARY CONT. NOTE; a. Excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. ~ b. Well within 200' of the proposed well are: DS 9-32 DS 9-35 DS 9-34 DS 9-33 49' @ 6035' TVD / 6600' MD 58' @ 300' TVD / MD 119' @ Surface 179' @ 100' TVD / MD The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi / ft). e, Based upon previous logs on DS 9, no potential productive zones are anticipated above 4000' TVD. f. No potential hazardous levels of H2S are anticipated in this well. g. This well will have altemating cycles of water and gas injected into it. NOTE: a. PBU DS 9-37 OPERATIONS SUMMARY CONT. Excess non-hazardous fluids developed from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. Well within 200' of the proposed well are: C. DS 9-32 DS 9-35 DS 9-34 DS 9-33 49' @ 6035' TVD / 6600' MD 58' @ 300' TVD / MD 119' @ Surface 179' @ 100' TVD / MD The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. d, eo Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi / ft). Based upon previous logs on DS 9, no potential productive zones are anticipated above 4000' TVD. f. No potential hazardous levels of H2S are anticipated in this well. g. This well will have alternating cycles of water and gas injected into it. DS 9-37 MUD PROGRAM DEPTH DENSITY (TVD) (PPG) PV YP INT. 10 min (CP) (#/lOOsqft) GEL GEL FL OIL SOLIDS TYPE (cc/30min) % % Surf 8.8 Funnel 40 to to 100 to 13-3/8" 9.2 to 60 Csg Pt. 250 30+ 50+ 25 0 8 Gel - Benex Spud Mud 13-3/8" 8.8 Minimum 2 2 5 25 0 3.5 Low Solids to to Possible to to to to to Non-Dispersed K-10 9.6 4 4 10 10 6.5 K-10 9.6 10 6 4 8 8 2 4 Low Solids to to to to to to to to to Non-Dispersed 9-5/8" PT 10.2 20 10 8 12 6 5 8 9-5/8" 8.8 5 2 2 5 8 2 4 Low Solids to to to to to to to to to Non-Dispersed TD 9.2 10 4 4 10 6 5 8 The above properties are to act as a basic guideline, actual fluid properties are to be adjusted to the hole conditions encountered. 1, 2. 3. 4. 5. 6. 7. EQUIPMENT- DRILLING FLUID SYSTEM Degasser Shakers Pit level indicator (with both visual and audio warning devices) Drilling flow sensor (with readout convenient to the driller's console) Trip tank Agitators Mud cleaner and centrifuges DS 9-37 MUD PROGRAM DEPTH DENSITY (TVD) (PPG) PV YP INT. 10 min (CP) (#/100sqft) GEL GEL FL OIL SOLIDS TYPE (cc/30min) % % Surf 8.8 Funnel 40 to to 100 to 13-3/8" 9.2 to 60 Csg Pt. 250 30+ 50+ 25 0 8 Gel - Benex Spud Mud 13-3/8" 8.8 Minimum 2 2 5 25 0 3.5 Low Solids to to Possible to to to to to Non-Dispersed K-10 9.6 4 4 10 10 6.5 K-10 9.6 10 6 4 8 8 2 4 Low Solids to to to to to to to to to Non-Dispersed 9-5/8" PT 10.2 20 10 8 12 6 5 8 9-5/8" 8.8 5 2 2 5 8 2 4 Low Solids to to to to to t.o to to to Non-Dispersed TD 9.2 10 4 4 10 6 5 8 The above properties are to act as a basic guideline, actual fluid properties are to be adjusted to the hole conditions encountered. EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaner and centrifuges ~AR 2 9 /~I~1~ .Oil & ,, N~chorage MUD SYSTEM NABORS 28E MUD CLEANER SAND TRAP 4 BBLS TRIP TANK PIT I 171 BBLS 130 BBLS PIT 2 PIT 3 81 BBLS 137 BBL$ II I PIT 5 117 BBLS PIT 4 179 BBL$ PILL PIT 20 BBLS I PIT 6 135 BBLS I ECEiVED MAR 2 9 ]98q CAVIEM SB-7 MUD CLEANERS (2 @ 750 GPM EACH)/i. JasJ~a.0Jl.& Gas Cons. Com.tlsslon DESANDER 3 X 12" DIAMETER CONES ' , ~l~lchorage DRILCO DEGASSER BRANDT CENTRIFUGE MUD PUMPS: 2 CONTINENTAL EMSCO FB-1600 DACRO GAS BUSTER JG 8/6/87 © MUD SYSTEM NABORS 28E MUD CLEANER MUD CLEANER SAND TRAP 4 BBL$ TRIP TANK PIT I 171 BBL8 130 BBLS II I I I PIT 2 PIT 3 81 BBLS 137 BBL8 I II I I I III PIT 5 117 BBLS PIT 4 179 BBL8 PILL PIT 20 BBLS II I Ill II I III PIT 6 135 BBLS CAVIEM SB-7 MUD CLEANERS (2 @ 750 GPM EACH) DESANDER 3 X 12' DIAMETER CONES DRILCO DEGASSER BRANDT CENTRIFUGE MUD PUMPS: 2 CONTINENTAL EMSCO FB-1600 DACRO GAS BUSTER JG 8/6/87 1000 2000 ~000 4000 5000 6000 ................. ~"' ' ' ' ' ' .................. 20" Casing TVD=] l0 TMD=II0 ~OEP--0 ~o~ ~_-~ AR(20 ALA.SKA, I~IC. D S 9- 3 7 10.0 ~,~.o ~.~7.~ SHL: 1881' FSL, 1060' FEL ..:~o~ ' SEC: 02, rl0N, R15E, UM 52~ TM~-~,8 Dm'~ 3¢ THL: 145 D' FNL, 800' FWL SEC: 02, I'10N, R15E, UM i N6020' 'VDt500 TMD~885 DI/P=-1720 AVERAGE M~IGLE= 26.4 ~40 TVD=?4~7 T~ ~)=$~65 9-5/8" Casing TVE =8617 TMD=9483 DE~3768 LCU/Sadlerochit TV] ~=8627 TMD=9494 DEP=3773 ' GOC TVD=8637 TMD=9501 DEP=3,.~77=Sacrl~_ _ \~. TAR( ~ET TVD=S952 Base of Sadlerochit 'IVD=9072 TM]3=9991 )EP=-3995 TI) TVD=9161 TIvID= 10092 DEP=4040 ...................................................... 10o0 2o0o 3o~0 7O00 80O0 10000 0 1000 20O0 3O00 400O 5000 6000 VERTICAL SECTION 7000 0 1000 2000 3000 4000 $000 ~000 7000 RI(FI ~T .h-~VATTONr: $2'~ 20" Casing TVD=IIO TM]~IIO DEP=O ARCO ALASKA, INC. to.o ! ~t'~.~ SHL: 18 FSL, 1060 FEL V:~ ' SEC: 02, ~ION, R15E, UM 521 TMD=1558 DEP~:39 THL: 145p' FNL, 800' FWL SEC: 02,F, T10N, R15E, UM N 60 20' Ar . 13.31R,, ca.~in~ TVI h::3000 TME~-3200 DE P=q'74 .... 'VD=4500 TMD=4885 DEP=I?20 AVERA~. ~OI-~- = 26.4 K-10 TVD=?437 TImiD=8165 DEP--3181 9-5/8' Caming TVE=8617 'I3VlD=9483 DE LCU/Sadl~rochit T~ )=-862'/ TMD=9494 DE TARe }ET TVD=-8952 TMI)= )858 DEP=-3936- BmeofSadleroclxit 3 V'D=9072 TMD=9991 )EP=3995 TI) TVD=9161 ~ 10092 DEP=4040 .................................................. 0 1000 2OOO 3OOO 7OOO 8O00 10000 0 1000 2000 3000 4000 5000 6000 7000 VERTICAL SECTION ARCO ALASKA, INC. DS9-37 N6020'W E - W COORDINATES -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 ~ .... LIIll ...... Ill Illllllll rill ................................. flllflfl 0 ) 50t - 5000 400t 4000 3O 3000 2000 2000 1000 0 -1000 -1000 -2000 -2000 -3000 .~ .~ ~ _~ .~,.,~,o R~~,iV~.i)~~___-. Alasl/a 0il & Gas Oons..C;omrol~lon ;~ '.~chotaga © ARCO ALASKA, INC. DS9-37 N 6020' W E - W COORDINATES -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 2000 ~.~ 2000 -2000 -2000 -3001 ) ...................................................................... 3000 -6000 -5000 4000 -3000 -2000 -1000 0 1000 2000 ARCO ALASKA, INC. DS9-37 N6020'W E - W COORDINATES -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 2000 -3000 -3000 -6000 -5000 .4000 -3000 -2000 -1000 0 1000 2000 ~ i i i i i i i i ii i i i i i i i ii i i i i i I I !I I f ......... i l"~, 71~d.. I I I I I i i i i 7~71 7119- 0!)-33 , ~.~,~ , ~67 ~-35 ~1~89 1~9-32 ~ ~ $710 . ~9~ ~ ~~~ . I ........................................................................ ARCO ALASKA, INC. .DS9-37 N 60 20' W E - W COORDINATES -5000 -4000 -3000 -2000 - 1000 0 1000 2000 · 5000 ) ~~~ ............... ~ ............. ,, ................. , I f~' ~"~ - ' ,,' t~=o · 7571 7112 4000 0~)-33 09-35 ~9-32 ~ . , ~~ o -1~ -1~ i ' .2~ i -3~ -3~ ........................... ' ........ ~ ........ -~ -5~ · ~ -3~ ...... ~ ....... ~ ........ ~RCO ALASKA, INC~ DS9-37 E- W cooRDINATES -500 -400 -300 -200 -100 0 200 60O 09-35soo 300 300 2OO 2OO ~_~ 0~32 0 0 -100 .100 -200 -200 -300 -300 -500 -400 -300 -200 -100 0 100 200 E- W COORDINATES ,,~CO ALASKA, 1NCO DS9-37 E - W COORDINATES -500 -400 -300 -200 -100 0 200 09~3550o .... ~ , 4342 . , ,.,. 400 ~ 400 300 300 ~ 2oo ~" ~'~ :~,n 2oo Z ../_ z ~ ~ N~ ~ z ~1~~ .... MAR 2 9 19~° ~asg Oil .t ~as ~n~. Commission ~ ~ ~c~ 3rage .................................................... -300 -50~ -400 -300 -200 -100 0 100 E- W COORDINATES .300 2OO ARCO ALASKA, INC. DS9-37 E- W COORDINATES -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 1300 1300 1200 09-32 1100 1200 1100 ! Z 700 ......... , , , ~ s , , , ~ , ' ~ ' ' ...... ' ' ' ' ' ' ....................... I I ! I I I I I I I I I I I I I I I I I I I I I 5929 7OO -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 E - W COORDINATES -21 O0 -2000 4900 -1800 ARCO ALASKA, INC. DS9-37 09-32 1300 1200 1100 O 70O E - W COORDINATES -1700 -1600 -1500 -1400 -1300 ' ' , -- $009 -1200 1300 1200 1100 1000 7OO -2000 -1900 -1800 -1700 -1600 E - W COORDINATES -1500 -1400 -1300 - i 20o 0 0 NABORS 28E DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE., I I RISER ' ! FLOWLINE I . i 20" ~ 2000 PSI DIVERTER , 10" BALL "1 I10" BALL VALVE ,, I CONDUCTOR 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 LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A ~N~'E RESERVE PIT lO" VENT LINE WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. NABORS 28E DIVERTER SYSTE,M SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I RISER IFLOWLINE i Ii 2000 PSI DIVERTER 10" BALL VALVE 10" BALL VALVE ,,I CONDUCTOR 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 LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 RESERVE PIT imm m m m m m m m mm mm m m m m m m m m m m mmm m m m m '10" VENT LINE WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. 13-5/8" PSI BOP STAC IAGRAM ACCUMULATOR CAPACITY TEST I ' ,I IpANNULAR REYENTER c ¢1 I ~'~-~ i)RLG ~ ALL BOP EQUIPMENT 5000 PSI RATED 15. 14. 15. 16. 17. 18. 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEYEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERYE 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 IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TI ME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. $. CLOSE ANNULAR PREYENTER AND UPSTREAM YALYES. 4. FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO .~ND HOLD FOR A MINIMUM OF $ MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREYENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE T :PSIOn, ND HOLD FOR AT LEAST $ MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE YALYES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :~ MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PI PE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST $ MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD YALYES (IF ANY) WITH 5000 PSI UPSTREAM OF YALYE AND ZERO PRESSURE DOWN- STREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. 12. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST $ MINUTES. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL YALYES ARE SET IN DRILLING POSITION. TEST STANDPIPE YALYES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. RECORD TEST INFORMATION ON BLOWOUT PREYENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERYISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. 13-5/8" PSI BOP STACKOIAGRAM ACCUMULATOR CAPACITY TEST I I IpANNULARRI REVENTE I ' PIPE RAHS / BLI ND RAHS / DRI LLI #G ~ SPOOL __PI PE RAHS DRLG SPOOL ~ GSG · SPOOL ~ STARTING HEAD ALL BOP EQUIPMENT 5000 PSI RATED 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 IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF $ MINUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO $000 PSI AND HOLD FOR A MINI MUM OF :~ MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST $ MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :~ MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST :3 MINUT'ES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. 12. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST $ MINUTES. 15. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. 14. TEST STANDPIPEYALYES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO $000 PSI. 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DALLY. REEEI. VED Alas~ 0il .& Gas Cons. Commission ', Rnchora.qe CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE . (3) Admin __ 9. 10. ~10 ~ 1~> 12. 13. (4) Casg ,,~..~. (14~ thru 22) (5) BOPE (23 thru 28) Company A~-e,-.,C~ +.~i~./~_.~.~ ~,,~,, Is the permit fee attached ~ ~" · ~/eee'e~'.eeeeeeee~eeee~e~eeeeeeeeeee~eee YES NO am. mZs 2. Is well to be located in a defined pool~ .... , ......................... Is w~ located proper distance from property line . ~. Is su~iCient undedicated acreage available in this 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the.well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source o~ drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings-... ,,~. Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this 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 the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of ~ ambBOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO psig .. Does the choke manifold comply w/API ~RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) Add: Geology: DWJ ~ ~c/~ Engi.neer..in~: / rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: / ~ ~ ~ Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ................................... /~ ....... ~d/z~ ~-l,~ ~ m~. , ,~, ? ~-~ .~'.-~' ~ ~~ [,~ . ~ - ~-, . ...... INITIAL OEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE O