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Home My WebLink About190-070Pages 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. /~'~7~ File Number of 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: Beverly ~ Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 E E C:LORrkMFILM.DOC PL E W M A T E R IA L U N D ER TH IS M ARK ER Memorandum State of Alaska Oil and Gas Conservation Commission To: Well File: C)~ ~ -'0~) r'~ 0 DATE Re: Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre 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 redriils 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 ddil. 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) Ddlling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. McMains ' t Statistical Technician Telecopy No. (907) 276-7542 June 5, 1990 Gary S Bush Regional Drlg Mgr UNOCAL P O Box 190247 Anchorage, Alt 99519-0247 Trading Bay Unit M-6 UNOCAL Permit # 90-70 Surf Loc 1036'FNL, 608'FWL, Sec 33, T9N, R13W, SM Btmhoie Loc 14]8'FNL, i080'FEL, Sec 28, T9N, R13W, SM Dear Mr Bush Enclosed is the approved application for permit to drill the above referenced well. The pe~it 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 tests that it wishes to witness. Ver~y truly yours, C V Chatterton Chairman Alaska Oil and Gas Conservation ¢o~ission BY ORDER OF THE COFR~ISSION jo Enclosure Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA ,.)IL AND GAS CONSERVATION CuMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill [2]I lb. Type of well. EXploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen,,Ei]!, Ser,,,vic,..e .[] Developement Gas ~] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California* 160 feet McArthur River 3. Address 6. Property Designation Middle Kenai Gas P. O. Box 190247, Anchorage, AK 99519-0247 ADL 18730 Poo.1 , 4. Location of well at surface 7. Unit or property Name " 11. Type B~)n~i(,ee 20AAC 25.025) 1036' FNL, 608' FWL, Sec 33, T9N, R13W Trading Bay Unit Blanket Bond At top of productive interval 8.'Well nurpber Number 1650' FNL, 1250' FEL, Sec 28, T9N, R13W M-6 5194234 At total depth 9. 'APproximate spud date Amount $200 000 1418' FNL, 1080' FEL, Sec 28, T9N, R13W July 8, 1990 ' , 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 6256 TVD 4000 feet 4.3 feet 3840 9159, ~ feet "16 To be completed for deviated wells 17. AntiCiPated pressure (see ~o AAC 2~.035(eX2)) @ 6235 ' TVD Kickoff depth 475 feet Maximum hole angle53.~J Maximum surface 3000 psig At total depth frVD) 3717 18. Casing program Settin.,g Depth size Specifications Top Bottom Quantity of cement , H°le Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26" 20" 133 !X-56 RL-4C 880 70 70 950 950 1400 sx 22" 16" 75 !K-55 BTC 1397 70 70 1467 1~50 1400 sx 17-1/2" 13-3/8" 61 iK-55 BTC 2978 70 70 3048 2650 1625 sx ,, '.12-1/..4" 10-3/4" 55.5~N-80 BTC 430 70 70 500 500 2200 s,x 9-5/..8" 47.0 N-80 BTC 8659 500 500 9159 6250 ... *Marathon Oil Company Sub-Operator. RECEIVE iv~AY3 ] ]97~~ ;:~,!aska 0it & ~as Cons, C0mmis$i0r,~ Anch0rag~ 20. Attachments Filing fee J~ Property plat t~ 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 ~'~ify that the f,of, egoing is true ap, d,.c~rect to the best of my knowledge ' Oomm,s.,o.'""e Oa,e Perm~ Number J APl number . ,' ,/'" / Approval date I See' cover letter ~O - ~o J,, 50- ~'--~'?"-'?-~ ~/Z_/~ (~6/06/90 . J for other requirements C;onaitiono ot approval Oample:~ requ, ire. d [] Yes ~ No Mud log requi/ed L-][] 6YeSN'~N° Hydrogen sulfide measures [] Yes ~No Directional survey required }~'Yes Required working pre~s.s~ure fg~ B.,O. PE~F-I~I); 'j~ 3~; [] 5M; [3 10M; ~] 15M ' Other: //~// /~ byorderof' /_ Z /... ~Approved .by .. ( ....' .../ .~ .~ _/.~~~i~ Commissioner the commission Date~'/~'/7,~ Form 10-401 Rev. 12-1-85 Submit in :rinli~,~t~ DRILLING AND COMPLETION PROGRAM MAR/ ON OIL COMPANY ALASKA REGION WELL: M-6 LEG: B-2 SLOT: 1 FIELD: AFE No.: TYPE: Trading Bay Unit, Steelhead Platform Grayling Gas Sands Dual producer REVISION NO.: DATE: 5/18/90 SURFACE LOCATION: TARGET LOCATION: BOTTOMHOLE LOCATION: 1036'FNL, 608' FWL Sec. 33 T9N, R13W 1650'FNL, 1250'FEL Sec. 28 T9N, R13W 1418'FNL, 1080'FEL Sec. 28 T9N, R13W KB ELEVATION: GL ELEVATION: FORMATION AC-1 A-1 B-1 C-1 D-1 D-16bc TOTAL DEPTH TYPE CONDUCTOR: AUXILIARY: SURFACE: PRODUCTION: SIZE 2O 16 ESTIMATED FORMATION TOPS: DEPTH(MD) DEPTH(TVD) 1509 1490 3192 2735 3956 3185 5019 3810 5544 4120 8805 6035 9159 6250 CASING PROGRAM SET GRADE THREAD FROM POTENTIAL CONTENT gas/water gas/water gas/water gas/water gas/water gas/water SET TO 133 X-56 RL-4C Surf 950' 950'TVD 75 K-55 BTC Surf 1467' 1450'TVD 13.375 61 K-55 BTC Surf 3O48' 2650'TVD 10.75 55.5 N-80 BTC Surf 500' 9.625 47.0 N-80 BTC 500' 9159' HOLE SIZE 26" 17-1/2" U/R to 22" 12-1/4" U/R to 17-1/2" 12-1/4" CASING DESIGN SETTING FRAC FORM SIZE WEIGHT GRADE DEPTH GRAD PRESS MASP TVD @ SHOE @ SHOE 20" 133# X-56 950' 12.1 16" 75.0# K-55 1450' 12.1 716 989 13.375" 61.0# K-55 2650' > 14.0 1266 2122 10.75" 55.5# N-80 500' 2180 9.625" 47.0# N-80 6250' > 14.0 2842 2842 DESIGN FACTORS TENS COLL BURST 5.64 1.35 2.66 1.46 1.10 3.70 3.60 13.7 2.96 6.55 1.43 2.42 DIVERTER SYSTEM The diverter system will consist of a 29-1/2" x 500 psi annular preventer, a 30' x 500 psi riser, and two 16" diverter lines each equipped with a 16" hydraulically actuated full-opening ball valve. A preselected diverter valve will open automatically and simultaneously when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4" x 5000 psi Hydril type GK annular preventer, a 16-3/4" x 10000 psi Hydril double gate ram type preventer outfitted with blind rams in the bottom and pipe rams in the top, a 16-3/4" x 10000 psi drilling spool (mud cross) equipped with a 4-1/16" x 10000 psi outlet and a 3-1/16" x 10000 psi outlet, and a 16-3/4" x 10000 psi Hydril single gate ram type preventer outfitted with pipe rams. A 16-3/4" x 5000 psi riser will be utilized between the blowout preventers and the casing spools. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system, both with a readout convenient to the drillers console. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2500 psi. MUD PROGRAM DEPTH TO WEIGHT VISCOSITY WATER MUD ppg sec/qt LOSS TYPE 950' 8.8-9.0 60-80 <30cc's Spud 1450' 9.0-9.2 60-80 <30cc's Spud 2650' 9.2-9.4 40-50 <20cc's PHPA 6250' 9.4-9.8 40-50 <10cc's PHPA Mud discharges will be monitored and reported per EPA requirements MUD EQUIPMENT The solids control equipment consists of an Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. WELLHEAD SYSTEM STARTING FLANGE: 30" series 300 CASING HEAD: 20" S.O.W. x 21-1/4" 2000 psi FMC segmented clamp hub w/2" L.P. outlets CASING HEAD CLAMP: 21-1/4" 2000 psi FMC segmented clamp CASING HEAD: FMC Unihead Type II, 2 step, 16" pack-off bottom w/21-1/4" 2000 psi clamp hub x 16-3/4" 5000 psi flanged top w/2-1/16" 3000 psi outlets TUBING HEAD: FMC TC-60-ET, SPCL 16-3/4" 5000 psi STD BTM x 16-3/4" 5000 psi FLNGD top w/2-1/16" 5000 psi outlets and four 1/4" SCSSV control line ports CEMENTING PROGRAM CONDUCTOR: 20" @ 950' MD LEAD SLURRY TYPE: Premium cement w/15 Ib/sk Thix Lite 373 TOP OF CEMENT: SURFACE WEIGHT: 12.8 ppg. YIELD: 2.17 cu. ft./sk WATER REQ.: 11.9 gal/sk PUMPING TIME: 6:00+ hrs:min EXCESS (%): 100 % ESTIMATED VOLUME 1000 sx TAIL SLURRY TYPE: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium cement w/3% CaCI2 800 ft. 15.8 ppg. 1.15 cu. ft./sk 5 gal/sk 6:00+ hrs:min 100 % 400 sx AUXILIARY: 16" @ 1467' MD LEAD SLURRY TYPE: Trinity Ughtweight cement w/.75% Halad 344 and 1% Calcium Chloride TOP OF CEMENT: SURFACE WEIGHT: 13.6 ppg. YIELD: 1.21 cu. ft./sk WATER REQ.: 5.85 gal/sk PUMPING TIME: 4:00+ hrs:min EXCESS (%): 100 % ESTI MATE D VO LU M E 1000 sx TAIL SLURRY TYPE: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium Class G cement w/3% CaCI2 1265 ft. 15.8 ppg. 1.15 cu. ft./sk 5 gal/sk 6:00+ hrs:min 100 % 400 sx CEMENTING PROGRAM SURFACE 13-3/8' @ 3048' MD LEAD SLURRY TYPE: Trinity Lightweight w/1% CaCI2 + 1.5% Gas Ban and .4% Halad 344 TOP OF CEMENT: SURFACE WEIGHT: 13.6 ppg. YIELD: 1.21 cu. ft./sk WATER REQ.: 5.83 gal/sk PUMPING TIME: 3:50 hrs:min EXCESS (%): 50 % ESTI MATE D VO LU M E 1250 sx TAIL SLURRY TYPE: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium cement w/1.5% Gas Ban & 1% CaCI2 26OO ft. 15.5 ppg. 1.19 cu. ft./sk 5.3 gal/sk 3:00+ hrs:min 50 % 400 sx PRODUCTION: 9-5/8" and 10-3/4" @ 9159' MD LEAD SLURRY TYPE: Trinity Lightweight w/1.5% Gas Ban, .14% LWL TOP OF CEMENT: 2600 ft. WEIGHT: 13.6 ppg. YIELD: 1.22 cu. ft./sk WATER REQ.: 5.95 gal/sk PUMPING TIME: 4:00 hrs:min EXCESS (%): 30 % ESTIMATED VOLUME 1200 sx TAIL SLURRY TYPE: TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Premium cement w/.75% Gas Ban,. 12% LWL 63O5 ft. 15.6 ppg. 1.18 cu. ft./sk 5.2 gal/sk 4:00 hrs:min 30 % 1000 sx DIRECTIONAL PLAN DESC MD TVD INCL AZIM NORTH COORD EAST COORD SECTION RKB 0 0 0 0 0 0 0 KICK OFF 475 475 BUILD @ 1.5 deg/100ft. KICK OFF 951 950 BUILD @ 2.5 deg/100ft. END OF BUILD 2822 2517 TOTAL DEPTH 9159 6250 54 HOLD 54 N36.26E 0 0 0 N36.26E 24 18 30 N36.26E N36.26E 769 4903 564 3594 954 6079 POTENTIAL INTERFERENCE: WELL DISTANCE DEPTH M-3 WITHIN 100' M-4 WITHIN 100' M-28 WITHIN 100' M-27 WITHIN 100' M-2 WITHIN 100' M-1 S/T#1 WITHIN 100' M-5 WITHIN 100' G-9 35' G-18R D 95' RLF-1 100' 0-1300' 0-1800' 0-1300' 0-1000' 0-1100' 0-1700' 0-1300' 7444' 7550' 1500' LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. AUXILIARY: No logging is planned for this interval. SURFACE: Possible GR/SP/CAL/DIL from 3048' to 1467'. PRODUCTION: GR/SP/Cal/DIL/LSS from 9162' to 3048'. FDC/CNL/Cal/GR from 9159' to 3048'. COMPLETION' A Cement Bond Log (CBL/GR) and a directional gyro- survey will be run prior to perforating. DRILLING PROGRAM CONDUCTOR: Nipple up diverter and function test same. Drill a 26" hole to 975' RKB. (Nudge wellbore away from platform while drilling.) Run and cement 20" conductor WOC. Perform top job if necessary. Back out and L/D landing joint. Set wear bushing. Test diverter and 20" conductor to 500 psi. AUXILIARY: Drill a 17-1/2" hole to 1467' RKB. Underream the 17-1/2" hole to 22" from 950' to 1467'. Pull wear bushing. Run and cement 16" auxiliary casing. WOC. Back out and L/D landing joint. Install FMC Unihead w/16" pack-off and test void to 700 psi. Nipple up BOPE. Test BOPE and choke manifold to 2000 psi. Test 16" auxiliary casing to 1850 psi. Set Unihead wear bushing. SURFACE: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg equivalent test pressure. Drill a 12-1/4" hole from 1467' to 3048' per the directional program. Log if necessary. Underream the 12-1/4" hole to 17-1/2" from 1467' to 3048'. Pull wear bushing. Run and cement 13-3/8" casing. WOC. Set pack-off and test void to 1100 psi. Test BOPE and choke manifold to 3000 psi. Test 13-3/8" surface casing to 2150 psi. Set Unihead wear bushing. PRODUCTION: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill a 12-1/4" hole from 3048' to 9159' per the directional program. Log. Pull wear bushing. Run and cement 9-5/8" casing. WOC. Set pack-off and test void to 2800 psi. Test BOPE and choke manifold to 3000 psi. Test production casing to 4200 psi. Set wear bushing. COMPLETION: Cieanout casing to PBTD. Run gyro and CBL. Perforate and flowtest the D-16A and D-16BC sand with TCP guns. Kill well, POOH. Set permanent production packer with plug above perfs. Perforate and flowtest the D-3B and D-6 sands with TCP guns. Kill well, POOH. Retrieve packer plug and wear bushing. Run dual strings of 3-1/2" tubing and dual packer. Land tubing. Nipple down BOPE. Nipple up and test tree to 5000 psi. Unload tubing with CTU and nitrogen. CORING PROGRAM No cores are planned for this well. TESTING PROGRAM No open hole tests are planned for this well. HORI ZON'~L SCALE J IN. PROJECTION = lO00 FEET NARATHON OtL Ceml~.nX ,. ,.,, Platform, Cook No' H-6 Proposed Inlet, Alaska z C~ I 5000 4000 3000 2000 1000 1000 1000 0 , I TARGET TVD-~40 TND-8802 DEP-$?~ NORTH 4666 EAST 3422 TARGET LOCATION, 1650' FNL. 1250' FEL SEC..,~J~. TeN. Ri3W SURFACE LOCATION, ~035' FNL, 608' FWL SEC. ~3. ?9N. R!3W WEST-EAST 1 000 2000 I I TD LOCAT [ ON, 1418',FNL. 1080' FEL SEC. 28:~; T9N. RI 3W 3000 4000 I I N 36 DEG 15 MI N E 5786' CTO TARGET) .6000 1450 200O ~475, 0°0' 0.00 SEC. 29.65 SEC. 467, 20'2' 150.49 SEC. E~O ~OALE 1',2000FT. NOTE~ COORDINATES RELATIVE TO SLOT .2000 ,0 2517 136 TVD 7000 ,I 1000 V. SECT I ON PLMIE~ I 2O00 N36' 14'E PROPOSAL ~ P00,147 · SCALE I ' ~ IO00FT. II I I ~' ' I I I I I I III I MARATHON OIL COMPANY $ EEL Al) ..,,,,., ,, WELL' H'"6 UT' B2"2 50 0 50 ! O0 ! 50 200 250 30O 250 2OO 150 100 5O 5O lO0 1800 6400 2000 / / / I / 1600// 1600 l / ! ~$oo / / / / / / lO 1 40~ 1400 / 4000 / ! 1 400 i / / )0 200 / ,~'1 200 ~oe'o 000 800 ~0 1200 1000 1800 / / / / / ~6oo / / / / / / / / / /1800 i m 300 250 200 150 100 5O 0 50 100 5O 0 50 1 O0 1 50 200 250 200 300 400 500 600 ?00 800 1100 1000 900 800 7OO 600 5OO 400 300 I I I 2900 / / 280F I / / I / / 5000 O0 ! ! ! /~2000 / ~9000 / / / 3leO ?2600 / / 3o9o / / ~500 5300 :00 7400 ! /~'2200 O0 ;00 5500 5400 rgo0 rTOO ! ! ! ! 300 5700 O0 MOO O0 I000 / / / / 2500 / / / / 2400 O0 8300 ;5OO 8500 8400 / / / / / w'2700 / / ! ;600 / 2600 ;?00 llOC 100C 900 800 700 600 5OO 400 300 200 300 400 500 600 700 800 BO0 900 1 000 11 O0 1 200 1300 1400 1 900 1800 1 700 1600 1 500 1400_ 1 300 _ 200 _ 1 00_ 6800 6700 6600 6900 7000 / / / ;700 / / / /31 O0 ! ! / / / / 3200 i900 ! / '000 / / / / / 3300 7' 3500 ! 3400 '200 '300 /"3000 I I 800 900 1000 I 1 O0 1200 1 300 1400 1900 1800 1 700 1600 .1 500 .1 400 _ 1 300 _ 1 200 .1100 1400 1 500 1600 1 700 1800 1 900 2000 2700 2700 I 2600 _ 2500 _ 2400. 2300 _ 2200 _ 2100_ 2000 _ 900 _ ! ! ! ! ~3600 ! 'i ' 1400 ! / ! ! ! ! ! ,/ 3800 1 500 1 600 ! ! ! ! 3900 1700 ! ! ! / 4000 1800 ! ! ! ! 4100 4200 1900 I 2OOO 2600 _ 2500 .2400 .2300 .22OO .2100 _ 2000 .1 900 1 900 2000 21 O0 , , I I I 2200 23;00 2400 L I t ,,, 2500 I , 3;500 _ 3400 _ 3;3;00 _ 3;200. 3;100 _ 3;000 _ 2900 _ 2800 _ 2700. . 3;50( 3;40C · -"FAO0 / / [ I //4soo / / / / / ~4300 ! / / / ,/ / 4400 ! / 4500 / ,. I i 900 2000 2100 ' I 'Ii ......... I .... 2200 23;00 2400 i 2500 33;00 . 3200 3;100 . ;3000 . 2900 . 2800 .2700 2500 2600 2700 2800 ~ I I ,, I i ii ii 4300 4200_ ] ! I 4100_ I i 4000_ [ I I 3900_ I 3800_ I I 100 3700_ I I 3600_ I I I 3500. /. ~ '~=='~i~= ! .... ! / / / / / / 2OO / / / / 5100 ! ! P'5200 ! ! '"5300 2500 2600 2900 I / / / / / 5400 ! ! / 5500 3000' 3100 I I . ! ! ~oo 2700 2800 2900 3000 31 O0 430C 420C _ 4100 _ 4000 . 3900 3800 _ 3700 . 3600 _ 3500 3100 I 3200 I 3300 I 3400 ,I 3500 I 3600 ,, 3700 I 5100_ 5000 _ 4900 _ 4800 _ 47OO _ 4600 _ 4500 _ ¢400 _ 300 _ ! ! ! ! 5800 ~00 31 O0 3200 / / / ! ! ! ! 6000 5900 I 3300 I 3400 ! ! ! ! ! ! 6100 ! ! 3500 ! ! "'620O I 3600 ,,, 3700 5100 50O0 4900 4800 4700 4600 4500 4400 4300 ,--. - .-- MUD -- CENTRIFUGE CE'TRIFUGE q CLEANER ! DESANDER CLEANER PIT ~ A ~ PIT PIT ] PIT ' PIT ~ 113 Bbls Cap ~ - -~ 105 Bbls Cap ' i 100 Bbls Cap ,~ 113 Bbls Cap 100 Bbls Cap o.99 ebts/in lOS ebls Cap i 1.11 ebls/i. RESERVE PiT ~ 1.11 Bbls/in ~.03 ebts/in i 0.99 Bbts/in .~ 1'03 Bbls/in ~ ~,' 509BblsCaP4.97 Bbls/in '~-~/ ] ~ o - o o , o o I -f- ~ ...... ! 0 ~ ~. 0 ~ SUCTION PIT ,'1 SUCTION PIT ~'2 ~/ 320 Bbls Cap 320 Bbls Cai= 3.05 Bb!s/in ~/ ~, 3.(~5 Bbls/in . i MIX PIT PILL PIT 82 Bbls Cap 80 Bbls Cap 0.77 Bbls/in 0.75 Bbls/in 0 0 0 0 ( ~ Mud Return Line ~~~~j _- Charge Pumps Charge Pumps From Substructure _ MUD RETURN DITCH N ~ Mud System , _EQUALIZER STEELHEAD PLATFORM AGITATOR MUD PIT LAYOUT I Mud Pump Mud Pump 0 MUD GUN :ldA.I. 3.LV~) NOEI:II,91VO lsd 000~ .91./L-£ :I~lV H.LVd /~Oq=l NI $3^'1V^ 'i'IV VV N01103S i-,..-. V I :~Nm-m =~)~OHO I SI:I::I)IVHS ::I'IVHS 01 IN:aA )IOIEII:I:IQ 01 O"lOdlNVl/ll 3)IOHO ' IhlBO_-llVqd OV3H"I3315 1:13J.$n~] SV~O 01 Plan View STEELHEAD PLATFORM . DiVERTER SYSTEM Rig Substructure N~ Ceramite filled.. ~ ~' _ Ceramtte filled 16' Remot ~'"-'~ Line Section View Operated Ball Valve Riser Conductor. 29-112" 500 psi Flange Kill Line Fillup Line 16-3/4' 10,000 psi Doublegate Check Valve Blind Ram's Flow Line Hydril 16-3/4' 5000 Type GK Annular Gate Valve Gate Valve Gate Valve HCR Valve Choke Line · Pipe Rams 16-3/4' 10,000 p8i Singlegate 16-3/4' 5000 psi Riser STEELHEAD PLATFORM Preventer Schematic Ball Valve Wellhead ...sm, I I CRECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc ~ 8~ (~ thru (8) ' (3) Admin ~ A-~2/~.~ 9. 11. (tff and 13~ ' 13. (4) Casg ' ~ (23 thru '28) Company ('~,/,v-,~.~ / ' ~ ' ' YES NO ~/ RE~.S Is the permit fee attached .......................................... /~. -- 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is weil 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 of 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 ail known productive horizons ..................... A~ 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 adequately_ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thr~ 3']~)~ 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 ............................................. Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE / , , ,