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Home My WebLink About191-082XHVZE 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. l~ t ~, 0~¢- File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type OVERSIZED -El' Logs-of vadous kinds . El Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell Date:¢2~.~ TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: is~ THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 P M L A T E E ~ : ~A: ~:~ E W TE R IA L U N D ER HIS MARKER Memorandum To' Re: State of Alaska Oil and Gas Conservation Commission D^T Cancelled or Expired Permit Action EXAMPLE' Point Mclntyre P2-36AXX API# 029-22801'95 This memo wffi remain at the front 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 ddll. 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 multilaterals 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 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 (weilbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMa~ns ' t Statistical Technician WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 12, 1991 Gary S. Bush Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, AK 99519-0247 re: Trading Bay Unit K-8RD2 UNOCAL Corp. Permit No. 91-82 Sur. Loc. 725'NSL, 133'WEL, Sec. 17, T9N, R13W, SM Btmhole Loc. 1702'SNL, 1245'EWL, Sec. 19, T9N, R13W, SM Dear Mr. Bush: 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 tests that it wishes to witness. Alaska Oil~ ConseDavid ~' Johnstd~,~ Chai%vaantion Commi BY ORDER OF THE COMMISSION dlf/Enclosures ssion cc' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA Al. .,:A OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL - 20 AAC 25.005 la. Type of Work Drill X Redrill X lb. Type of Well Exploratory~ Stratigraphic Test __ Development Oil Re-Entry Deepen __ Service __ Development Gas ~ Single Zone ~ Multiple Zone 2_. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool UNOCAL Corp. fARCO Alaska, Inc, is sub-0peratQr) RKB 1Q¢ feet McArthur River 3. Address 6. Property Designation ~",~1~ P. O. Box 190247, Anchorage, AK 99519 ADL 18777 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 725' N & 133'W of SE corner, Sec 17, T9N, R13W, SM Tradina Bay Unit Statewide _ At top of productive interval 8. Well number Number 2027' S & 1895' E of NW corner, Sec 19, TgN, R13W, SM K-8RD2 #UG3061 0 At total depth 9. Approximate spud date Amount 1702' S & 1245' E of NW corner, Sec 19, TgN, R13W, SlY June 1-1991 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and property line K-19 14624 MD 1171' @ TD feet 152' at 5780'MD feet 1 9 02 9617 TVD feet 16. To be completed tot deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1 0808feet Maximum hole angle 53 Maximum surface 2745 psig At 9650(TVD) 4,000 psig 18. Casing program Setting Depth size Sp,ecification Top Bottom Quantily of cement Hole Casing Weight Grade Coupling Length IVD TVD bO TVD (i,nclude stage datat existing9.625 47# N-80 ,BTC 11341 35' 35' 11376' 7715 , 8.5 7" 29# N-80 BTC 4124' 10500' 7192' 14624' 9617 800 cu ft class"G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 14548 feet Plugs (measured) K-8RD will be P&A @ 10800'md true vertical9842 feet K-8A will be side tracked from K-8RD Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 2571 13-3/8 YES 2571 2285 . Intermediate 11376 9-5/8 YES 11376 7705 ~. Production .. Liner 3638 7 YES 14546 9840 Pedoration depth: See attached sheet measured .; i ) :...'~... ',',.~' ,,.. .. ~';. ~ · true vedical ~i\ !'~.' "~'""" , 20. Attachments Filing fee ~ Property plat _2~ BOP Sketch ~ Diverter Sketch X Drilling program X Drilling fluid program ~ Time vs depth plot _ Refraction analysis ~ Seabed report __20 AAC 25.050 requirements 21. I hereby certify that the fore~joing is true and correct to the best of my knowledge Signed ~ ~ ~,..,.~ Title Drillinc~ ~ Date ~--'5\ ,/.~ ~.~ C°mmissi°i Use Only /c~-- f __~JNo Permit Numb;gr "...~ APl number Ap~l,ov,,~al e (~ See cover lelter for ¢/__ ~2~_.~ 50- 7~..~ ~'- .~--~.'¢ ?~-4:~ ~ -- / other requirements es o Conditions of approval Samples required ~Y e s ~ N o Mud log required ~ Y N Hydrogen sulfide measures ~ Yes ,~ N o Directional survey required ,~ Yes Required working pressure for BOPE ~2M; ~ 3 M' ~ 5M' ~ 1 0M' __ 1 5 M Other: /. Approved Commissioner the commission Date ,~ Form 10-401 Rev. ~ ~ ' lriplicate ARCO Alaska, Inc. PROPOSED.. Well K-~RD2 Spud Date: 11-9-84 Original RKB: 100' MSL Top of Hemlock: 13720" Annulus Fluid: Sea water TL ling Bay Unit- King Salmon ~ fform APl#: 80-733-20097-02 Completion Date: 08-91 Hanger Type: 4-1/2" FMC Maximum Hole Angle: 57° Last Revised: 05-24-91 All Depths are RKB MD to Top of Equipment. Well Type: Producer New I~1 Workover I'-1 RKB to Hanger: 35.00' Angle at Perforations: 45© Reason: Jewelry 1 300' 2 13550' 3 13625' Camco TRDP-4A SSSV ID = 3.813" Baker FB-1 Permanent Packer 3-1/2" tubing tail Casing and Tubing Size ~ 11 13-3/8" 61# 12 9-5/8" 47# 13 7" 29# 14 4-1/2" 12.6# 15 3-1/2" 9.2# 16 Gas Lift Information Depth Stn. TVD Grade Thread To D J-55 BTC 35' N-80 BTC 35' L-80 BTC 10500' L-80 BTC 35' L-80 BTC 10475' Mandrel Size TvDe Valv~ _ _ Bottom Description 2571' Casing 108[]0' Casing 14750' Liner 10475' Tubing 13625' Tubing Latch Port Sz. TRO 7 MANDRELS - 4 1/2" 5 MANDRELS - 3 1/2" Perforation Data - DIL depths Zone ToD-MD/~;~; Perf Interval 0 1 2 3 4 5 6 7 FT SPF PBTD = 14700' MD TD = 14750' MD Datum .... ' MD ( 9350' SS, 9450' TVD) Gauge Ring and Fill Level Data Dat~ Size Depth Comments K-8RD2 GENERAL PROCEDURE 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) 14) 15) 16) 17) 18) 19) 2O) 21) 22) 23) 24) RU ARCO Rig # 58. MIRU wireline unit. Set plug in lower packer @ 14295"md. Kill well. ND tree. NU BOPE. POOH. LD completion assembly leaving the top packer @ 13560' in the hole. MU 6" bit with scraper and RIH to top of packer. Circulate hole clean. POH. MU 7" retainer on DP and RIH. Set @ 13500'md. Establish an injection rate. Cement squeeze Hemlock with 350 cu. ft. of slurry (leaving 500' of cement on top of retainer). PCH. MU 9-5/8" RTTS w/ 3 stands of 3-1/2" tail pipe on DP and RIH. Test casing above TOL w/ 2500 psi. Spot a 75 cu. ft. balanced plug (150' below and 100' above the liner top). Squeeze as required. POH. WOC. PU 8-1/2" bit and RIH and dress off top of plug at 10800'. POH. PU whipstock or casing cutter and RIH and sidetrack well @ 10800' to TD. Run open hole logs. RIH and condition well for 7" casing liner. POH. Run and cement 7" casing liner. Clean out well to PBTD. Displace well to completion fluid. Perforate preferred zones with 4-1/2" tubing conveyed guns. RIH w/ work string. RU frac equipment. Frac well. POH. LD work string. Make a clean out run. RU and run completion string. 25) ND BOPE. NUtree. 26) Release rig. K-8RD2 Drillinq Fluids Proqram From Sidetrack Point to Total Depth Density 8.8-9.4 Funnel Viscosity 38-46 PV 10-20 YP 5-15 Initial Gels 2-10 10 minute Gels 5-20 Fluid Loss 10-5 pH 8.5-9.5 % Solids 4-10 Drilling Fluid System - Dual tandem shale - Mud cleaner - Centrifuge - Degasser - Pit level indicators - Trip tank - Fluid flow sensor - Fluid agitators shakers (visual and audio alarm) FROM:GREAT LAND DIRECTIONALf TO:KRV/CI/NV DRILLING MAY 22, 1991 1: 11PM A/ ALASK"~:.i~'." 'INC. OE 5402 64t4 7866 6788 91~ TBU K-dRD (LOCATION PLAN VIEN CLOSURE ..... : 9498 fl: S 75.tB N DECLINATION.: 23.50 E SCALE .......: i inch ,, 1700 feet DRAHN ........ 05/22/9t B)! ~eat Land D~rectlonal ZT~tllin# 3400-- 6600- 10200--. S;IDEIRACK GYRO 1 ! 8500 SHOO 5t00 3400 1700 O FROM:GREAT LAND DIRECTIONAL TO:KRU/CI/NU DRILLING _AH_co ~BO0. ,1~00- 5600 ........ 7000-'f ........ 8400--' 9800-- 1: llPM P. ia::] TBU K-SRD (LOCATION B) VERTICAL SECTIDN VIEW Section at: N 63.49 W TVD Scale.' I inch- ~400 feet Dep Scale.: I inch -- ~400 feet ~Dr'awn ..... :05/22/91 ..... i i mi _ ~e~t Lend ~J~ect~onaY ~/"~22~n9 ' 9) S)DET~CK K~ 1080B ~ C) ~O l.O/iO0 DROP 10823 , D) ~O Z.5/tO0 TURN 1~303 : FJ T~GET/HIO HENL~ 14007 ' ~ Fi TO t4560 TVD 5~CTN ZNCLN 0 0 0.00 736g 42t5 53.29 737B 4224 53.t4 8266 53~6 53,14 ~88 6891 53. t4 9620 7134 53.14 I~O0 1400 28OO 4~00 5600 ~,ect: ~on Depar, tuPe .......... . 7000 FROM:GREAT LAND DIRECTIONAL..--. TO:KRU/CIxNV DRILLING · MAY 22, 1991 I:IOPM P.B2 GREAT LAND DIRECTIONAL DRiLLiNg, INC. o~/22/91 Client .... : ARCO ALASKA, INC. Field ..... : McARTMUR RIVER, KENAI, ALASKA Well ...... : TBU K-8RD (LOCATION B) Section at; N,63.49,W Engineer..: JAMES TRANTHAM Computation...: RADIUS OF CURVATURE Survey Date...: 05/22/91 RKB ~levation.: 100.00 ft Reference ..... : Magnetic Dcln.: 23.50 E W~LL PROPOSAL Target Location: 1900 FNL 1600 FWL S19 T9N R13W MARKER IDENTIFICATION KB SIDETRACK KOP END 1.0/100 DROP END 2.5/100 TURN TOP HEMLOCK MEAS INCLN VERT-D~PTHS SECT DIRECTION REL-OOORDINATES DOG DEPTH AN~LE BKB SU~-8 DIST BEARING FROM-WELLHEAD LEG 0 0.00 0 -100 0 N 89.99 E 0 N 0 E 10808 53.29 7369 7269 4215 S 79.12 W 3393 S 6402 W <TIE 10823 53.14 7378 7278 4224 S 79.50 W 3395 ~ 6414 W 1.93 12303 53.14 8266 8166 5328 N 63.49 W 3233 S 9566 W 1.60 13652 53.14 9095 8995 6407 N 63.49 W 2752 S 8532 W 0.00 TARGET/MID HEMLOCK BASE HEMLOCK TD ~4007 53.14 9288 9188 6691 N 63.49 W 2625 S 8786 W 0.00 14361 53.14 9500 9400 6974 N 63.49 W 2499 S 9039 W 0.00 14560 53.14 9620 9520 7134 N 63.49 W 2429 S 9182 W 0.00 K-8RD~2 TOP' HB-6 TARGET 1900'FNL 1600'FSL G-29 9266 ELL LOCATIONS TOP · ,. 0 G_ ~'t~¢hmtent ~ ~ 1__3-5/8" 3, 00 PSI BOP STA . , [NN LAR! PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 1. FMC TYPE II! UNIHEAD 2.13-5/8" 5000 PSI HUB X 3000 PSI FLANGE ADAPTER 3.13-5/8' - 3000 PSi DRILLING SPOOL 4.13-5/8' - 3000 PSI BLIND RAMS 5.15-5/8"- 3000 PSI PIPE RAMS 6.13-5/8" - 3000 PSI ANNULAR 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 TIIVE AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WiTH CHARGING PUIVI= OFF. 4. RECORD ON THE [ADC 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 HOLDq:3OWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE AJ~IULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3(XX) PSI UPSTREAM OF VALVE AND WFTH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAIVIS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES 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. RECORDTEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COIV~LETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 9, 1987 (FOR TBU WELLS) r' ~ |~'000 PS1 F DIAPHRAGM CHOKE LINE (3 (M ADJ. ,,(I.,..L tK HYDRIL PIP~ ~^M$ BLIND RAMS LU (N R CHECK VALVE Z <: I- CHOKE MANIFOLD & KILL LINE W/B.O.P. ON KING PLATFORM 10-3-77 ALASKA OIL AND GAS CONSERVATION COMMISSION June 12, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 80.59 Re: The application of Union Oil Company of California, oper&tor of the Trading Bay Unit (TBU), to drill and complete the TBU K-SRD2, well as part of the pressure maintenance project approved by Conservation Order No. 80. Mr. Gary S. Bush Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, Ak 99502-0247 Dear Mr. Bush: Your application of May 31, 1991 for a permit to drill the TBU K-8RD2 indicates that the drilling and completion of the TBU K-8RD2 well will provide additional oil recovery from the Hemlock Oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU K-SRD2 well pursuant to Rule 5 of Conservation Order No. 80. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION ^ i)\ , STATE OF ALASKA ' ,/1 L,/~.//~¢~KA OIL AND GAS CONSERVATION COMMISSION p,. { AC' ICATION FOR SUNDRY APPROVALS 1. Type of I~eque~prl/..~ Suspend _ Operation Shutdown _ Re-enter suspended well _ ~,,////,7 .~ttKer casing _ Repair well_ Plugging _ Time extension _ Stimulate _ 7 /Change approved program _ Pull tubing X Variance _ Perforate Other 2. Name of OiSerato¢ UNOCAL Corporation (ARCO Alaska, Inc. is sub-opercttor) 3. Address P. O. Box 190247, Anchorage, AK 99519 5. Type of Well: Development X_ Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface Leg 1, cond. 7, King Salmon Platform 725' N & 133'W of SE corner, Sec 17, T9N, R13W, SM At top of productive interval 2027' S & 1895' E of NW corner, Sec 19, T9N, R13W, SM At effective depth 1900' S & 1641' E of NW corner, Sec 19, T9N, R13W, SM At total depth 1702' S & 1245' E of NW corner, Sec 19, T9N, R13W, SM 12. Present well condition summary Total Depth: Effective depth' 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Trading Bay Unit 8. Well number Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 14548 feet Plugs (measured) true vertical 9842 feet K-SRD 9. Permit number 84-184 ' 10. APl number 50-733-20097-01 11. Field/Pool Hemlock 14524' measured 14524 feet Junk (measured) 14297' true vertical 9824 feet ~~ ~// Length . Size ~ Cement M S ched sheet true~.vertical See ~sheet Tubing (size, grade, and measured depth) 4-1/2",N-80 BTC @ 10863MD; 3-1/2", N-80, BTC fr 10863'-13604' Packers and SSSV (type and measured depth) Baker FB-1 pkr @ 14295'md;Baker FHL@ 13560'md, Camco TRPD1-A @ 267' ,th True vertical depth 2285' 7705' ECEIVED JUN - ,5 1991 Ieet . Alaska 0il & Gas Cons. Commission Anchorage BOP sketch X Suspended _ 13. Attachments Description summary of proposal _ Detailed operation program X P&A present BHL, Drill sidetrack to new BHL (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: June 1, 1991 ou x Gas _ 16. If proposal was verbally approved Name of approvei: ... Date approved Service Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. (~ ~ FOR COMMISSION USE OI~LY Conditions of approval: Notify Commission so representative may witness BOP Test Location clearance __ Subsequent form require 1Or zt'©'~' Plug integrity_ Mechanical I_ntegrity Test ~pp, ~,,~= ..... CoPY · Returned Commissioner Date ~:¢ '"'" '~ -"- ~ / SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 K-8RD2 GENERAL PROCEDURE for P&A 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) RU ARCO Rig # 58. MIRU wireline unit. Set plug in lower packer @ 14295"md. Kill well. ND tree. NU BOPE. POOH. LD completion assembly leaving the top packer @ 13560' in the hole. . MU 6" bit with scraper and RIH to top of packer. Circulate hole clean. POH. MU 7" retainer on DP and RIH. Set @ 13500'md. Establish an injection rate. Cement squeeze Hemlock with 350 cu. ft. of slurry (leaving 500' of cement on top of retainer). POH. MU 9-5/8" RTTS w/ 3 stands of 3-1/2" tail pipe on DP and RIH. Test casing above TOL w/ 2500 psi. Spot a 75 cu. ft. balanced plug (150' below and 100' above the liner top). Squeeze as required. POH. WOC. PU 8-1/2" bit and RIH and dress off top of plug at 10800'. POH. Prepare to Side Track well K-8RD2 t?EC£1VED Alaska 0ii & Gas Cons. Commission Anchorage ~xi~ting perforations K-8RD APPLICATION FOR SUNDRY APPROVALS PERFORATION DEPTHS Interval 13734-13786 13828°13838 13870-13910 14115-14195 14320-14353 52 10 4O 80 33 jr/mac 05/21/91 'I'VD 9265-9301 9331-9338 9360-9388 9533-9589 9677-9700 gECEIVED JUN .. ~ tggt Alaska Oil & Gas Cons. Commission ~nohora~e TOTAL Oi'..iT.. ',/QL, ~ 4~5 ,~u,~"' FY .4t-tO cu, f'. x (i 0908-I 0800) -~-,2085 x (~i'058-I0908) = 75 cu.ft .2085cu.,,,. ,, X (14295 !3~0i X i50%=230 Cu.ft 11058' 13000' I,q50n' 13545 3560' 14524 ,j/,T 5,99,'q~, CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 1 ) Fee .~,PL_. ~',/~,/~-~ [2 thru 8] · '[9 t. bru,,l~] ' -' J~¢', ~...., !:'., ./~ ".;" '~. .'"/ [ 10 & 13] · .. (4) Casg ~.~.~..~'.~.-?/-.~? [1~ ~hru 22] ( 5 ) BOPE ,~,.~i]~<~, ~-?/- ~ ! [23 thru 28] (6) Other /(/*~ thrum] [29 (6) Addl YES NO Lease g Well ~ /~f49~ / ~ 77 Z .2' ~2~/J~r REMARKS 1. Is 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 well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... ~ Is lease nLrnber appropriate .......................................... L Does well have a unique name & nLrnber ................................'/~_ 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 ...... 32. 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 ~--~~BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O©opsig ..... 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 ............................................. o -4 geol~~ DWJ RP~ rev 03/29/91 jo/6.011 engineering: MTM,/'~ BEW =~ RAD INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks'