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Home My WebLink About193-109· XHVZE 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. 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 -~ Logs-of vadous kinds [] Other COMMENTS: Scanned by ianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: isl ~ --- HAS BEEN ON' OR BEFO W c:t.o~lt.t~.D°c Memorandum To' Well File: State of Alaska Oil and Gas Conservation Commission Re.' Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 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 APl number and in some instances the well name reflect the number of preexisting reddlls 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 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 APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weiibore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician 3 ALASKA OIL AND GAS CONSERVATION COMMISSION August 16, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 44.49 Re: Application of Shell Western E&P Inc. to drill, complete and produce the Middle Ground Shoal No. A13A-01 well in the Middle Ground Shoal Field. R. G. Blackburn, Mgr. Alaska Oprns Contntl Div Shell Western E&P, Inc. 601 West 5th Av Ste 800 Anchorage, AK 99501 Dear Mr. Blackburn: The referenced application was received on July 30, 1993. The Middle Ground Shoal No. 'A13A-01 well is to be drilled to the steeply dipping west flank of the reservoir. Structural complexities in this portion of the field require producers to be drilled at less than 80-acre spacing to insure adequate drainage. The subject well will be the fiPth prodUcer in a governmental quarter section. The Commission has reviewed the evidence available and hereby authorizes the drilling, completion and production of the referenced well pursuant to 'Rule 6 of Conservation Order No. 44. Commissione BY ORDER OF THE COMMISSION ALASKA OIL AND GAS CONSERVATION COMMISSION August 16, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 R. G. Blackburn Manager Alaska Operations Shell Western E&P, Inc. 601 W. 5th Ave., Ste 810 Anchorage, AK 99501 Re: Middle Ground Shoal A13A-01 Shell Western E&P, Inc. Permit No: 93-109 Sur. Loc. 1621'FSL, 326'FEL, Sec. 11, T8N, R13W, SM Btmhole Loc. 3463'FSL, 5245'FEL, Sec. 1, T8N, R13W, SM Dear Mr. Blackburn: 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. Blowout prevention equipment (BoPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Sincerely, Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. - .. '.~'--'. STATE OF ALASKA '-~ ALASKA . AND GAS CONSERVATION CU.. MISSION PERMIT TO DRILL' 20 AAC 25,005 la. Type of work Drill I~ Redrill F11 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenI-11 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Shell Western E&P Thc. 116' KB feet 3. Address 6. Property Designation G Pool 601 W. 5th Ave, Ste 810, Anchorage, AK 99501 ADL 18754 Location of well at surface Platform "A" L~eg 3, 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 4¢,onductor 24, 1621' FSL, 326' FEL (~f ~ec. 11 Middle Ground Shoal AN oRpl3ofW, SM Blanket T8 t't productive interval 1501' FSL, 4682' FEL 8. Well nu.mber Number of Sec. 1, T8N, R13W, SM A13A-01 400 Hm 7522 At total depth 3463' FSL, 5245' FEL of Sec. 1 ,9. Approximate spud date Amount T8N, R13W, SM September 15,. 1993 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 13,000' MD-KB 1,817 feet 440 feet 2746 9,965' TVD-KB feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1000 feet Maximum hole angle58 0 Maximum surface 2100 psig At total depth (TVD) 5700 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) SEE /~TTACHED TABLE 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 1';!, '' Conductor ~, ?. Surface Intermediate J U L. ,~ (..) Production Liner Alaska Oil & (Sas Cons, Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ Property plat FX BOP Sketch E~ Diverter Sketch EX Drilling program Drilling fluid program [~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~,..~./~.~'~'~'~ Title Manager Alaska Operations :'"- '-- Commission Use Only Permit Number I APlnumber IApprovaldate ISeecoverletter ~;:~,~ -//O'~ 50_/~S ,.~ _, ~:~_., ~/z.,~. ,~. ;,: ~)..-,/,'~, ....~'. ~-*,~ for other requirements Conditions of'approval Samples required [] Yes ~r No Mud Icg required Lq Yes ~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey required ,~ Yes [] No Required working pressure for DOPE rq2M; [] 3M; [] 5M; [] 1OM; '] 15M Other: by order of Original Signed By Commissioner the commission Date Approved by D~vid W. , Form 10-401 Rev. 12-1-85 Submit in triplicate A13A-01 PERMIT TO DRILL 18. Casing Specifications Setting Depth Quantity of cement program size Top Bottotn Hole Casing Weight Grade Coupling Length ND TVD ND TVD (include stage data) 17-1/2" 13-3/8" 54.5 K55 BTC 2r518 0 0 2~518 2f. 500 1770 sx "G" + additives 17-1/2" 13-3/8" 61.0 K55 BTC 757 2,518 2,500 3,275 3,216 12-1/4" 9-5/8" 43.0 L80 LTC 8,304 0 0 8.304 7,000 770 sx "G" + additives 12-1/4" 9-5/8" 47.0 LBO LTC 947 8,304 7,000 9,251 7,~0 8-1/2" 7-5/8" 29.7 Pl10 FL4S 1,619 8,851 7,382 10~470 8~516 240 sx Trinity lite ware + additives 6-3/4" 5" 18.0 Pl10 LTC 2,930 10~070 8~238 13w000 9,965 380 sx Trinity lite ware + additives Alaska Oil & (~as Cons. ' "' ' * Connmssmn Anchorage SHELL MINIMUM BOP STACK REQUIREMENTS Min. M,n. No. Item I.D. Nominal I Flowline 7" 2 Fill up Line 2" 3 Drilling Nipple 4 Annular Preventer 5 Two single or one dual hydrualically operated rams 6 Drilling spool with 2" and 3" min. outlets 7 Gate Valve 3 1/8" 8 Gate Valve Power Operaled 3. I/8" "~--~ Li~ to Choke manifold 3" ..... 10 Gate Valve 2-1/16" i-f- Check Valve "2-T1/16'' ............ i 3 Cas-lng SpoOl ..... 14 Valves Gate i* 13/16" .i5-__! .COmpound Pressure Gaugeconnect°r 16:= Control_ . . plug or valve ,I.- 13/16". 17 Kill line to rig mud pump manitold :2" ia :~'; x 2;' x 2,;,:'r0~s' ' 'NOTE: Additional specillcalioni Io~' Air/Gas Service -.re given in Shell Well Conlrol Manual, Appendix 6.18. A rolallng head si'tall he provided on Air/Gas Service OPTIONAL w.__:, o.. ;~---Gate valve / ~- Line to roadside cotmeclion ~ 2" ~T- Rotating I)lowout preventer ~ ~ate val~e power 0Perate~- DRAWING & CttECK LIST 104A StlELL CLASS 5M SURFACE INSTALLATIONS NORMAl_ AIR/GAS* i':OFI Altt/(JAS DRILl. lNG CONFIGURATION A ....... - .... ~~ . ANNULAR PREVENTER BLIND RAM PIPE RAM Q . SHELL MINIMUM AUXILIAR>~-r'.C VIENT REQUIREMENTS "Aaster control w~m Hvol. .,'assure requlatlnq valve. ~ ,J,rll~ remote con,roi , ~vOraul~c BOP operating unit. See OelOW tot Detail. , . K. etlv coct(s ~ UDDer ~[] Lower ;-essure Ratino 5,000 · ~ellv saver sun with protector ruDDer. · ins~Oe BOP. surface type. for each s~ze ~rlil olde. - ~-,J~l ooen~ng Dali valve for eacn s~ze orlit O~De ~n use. · Labelled crossover suds for each Different connection ~n Or, ti etruria. OPTIONAL AUXILIARY EQUIPMENT · Circulating neap for each s~ze Drill mae ~n use with steel OlDe and C~iksan tolnts to reacn stand connection. · I ns~ae BOP - Drop or oownnole type, Cup or plug type BOP tester with spare seals. SHELL MINIMUM HYDRAULIC OPERATING UNIT SPECIFICATIONS Accumulator volume -- must oeiiver 1.5 times :ne volume to make Oos,tlon change on a~l nvoraul- icaliv operated units ancl retain 1200 Os, (200 psi above orecnargel without Dumps. Pump caPaciw to potion 200 Ps~ above accumulator precnarge pressure ~n two ~2) minutes or ~ess, · A/nile ctosmq annular preventer and opening choke line valve. See Section 4.31. Power for Dumps - 2 sources reclulreo - Air-Electric or All Air (r~g a~r Olus separate air tanK~ -- 2 Dumps reoulreCl. Lines from ooeratln§ un,t to BOP units 5,000 Del Minimum Yietd ~ Seamless steel lines .90" mlmmum I.D. :~ Seamless steel lines wltl~ Chiksan iolnts. ~ Hose per. Section 4.32 Ooeratln~ unit fluicls: Hydraulic oil or soiuDle pit. All controls snail be clearly marked to snow untt operated. Blind Ram control to nave easily removecl latch or ~juaml. Sufficient Ooctlect nitrogen or ortner 0acK-uo storage system to equal accumulator cauac~w, manifolded to bv-oa_~_ Lc~__,mulator and close BOP directly. Alarm. or visual indicator to stqow when accumulator ~s shut off from preventers. SHELL MINIMUM MUD SYSTEM REQUIREMENTS Pump stroke counters each Dump. Oegasser. Pit votume recorUer wttn alarm. Flow line mort,for. OPTIONAL MUD SYSTEM EQUIPMENT Trio tank (witt~ 6th mini Flow tine gas separator. MISCELLANEOUS EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS 1. All connections shal! hi w~tdlCl, studdecl, flint)ecl or Cameron clamp of coml~ra~e ratmq. 2. All flang~ shell be APl 68 or 68x aha ring cj~klt$ s1'~1! be APl stem RX or eX. OD not re-u~ BX r~ncj~. Always UlI nlw rags oeiow iow~' mot't DreVente~ wl~en fllngl~ 14'e ~)lrTecl. 3. Drilling .la(~ots tail be forgecl or forgect and wiidecl. Pilx si3oms not 4. BOP slack simile be t3rlGKI tO subl3a~e or smtat)le supl3(3r! OY turnOucklecl line1 or rocls. (No rigid connections. 5. All ~tI valve1 sl~al._.~l be equil)l~l whh hen(tM Rams shoulcl hive n~lnuellV M3eratecl screw tock~ncj extensions (extenctecl beYonCl sul30~) reaclv for use. 6. For lancl rlc~ the master contro~ station anct ol:)lratlncj unit shell be tocatecl at grc~lncl levM a minimum of 50' from tl~e w~lt. The remote stltlor! is to I~ Iocatecl near the clrlller'l Dosmon. Inol3erative conchtion of tt~e remote unit ts not to interfere wttll o13~1t1(3~ of the master control umt. For platform ancl I~lrge rig~ the mastlr control station ancl olxritlng unit may De on the ng floor w~th the remote station Iocatecl so that Is DrOtecfecl from tl~e well area ancl acclss~Ole from a lO. col evacuation route. HVclraulic line1 may be high prel~ure hose prowclecl they meet the reamre- rnen~s ~n Section 4.32 in the Shell Well Control Manuel. 7. Housing ancl halt,rig sttouicl be provlcllcl for accumulator, blowout preventers, cl~ol(e ITtlnifOId where concl~uons warrant. 8. Contractc,' shall make no connection to cas~ncJ I~eacl slcle outlets exCM:)t Dy orcler~ of Shell. 9. One sari let of ram OlO(;K$ for the clni113ig m use snalJ be kept on rKj~. 10. Any mlselicjnrnen! of ri~j shoulc~ be cofrKtecl tO IVOICl unaue wear of casing. 1 1. Four wlv valve~ tal__~l be ke~t open or claN. not ~n nautili · fVor ~3plicaOle rD will Mrv~ing wttnour drill pipe. 4.28.12 6.7,5" & 8.5" HOLE 5000 PSI STACK TOP OF DERRICK FLOOR i BOTTOM OF ROTARY BEAM FILL UP LINE / FLOW LINE NIPPLE fl [,~ P Rfff NTf R bJ ~~ / ] 173_5/8,, 5000 PSi FLANGE BMND RAM 5000 PSI PIPE RAM 5000 PS[ DRILL, iSPOOL 5000 PSI RISER DSA RIG CELLAR FLOOR Alaska Oil & Gas ~'~,o~,o.''':' Anchorage WEL~EAD ROOM FLOOR DRILLING SPOOL [CASING HEAD __ 13-5/8" 5000 PSI FLANGE 3-1/8" CHOKE LINE 13-5/8" 5000 PSI FLANGE 13-5/8" 5000 PSI FLANGE il" 5000 PSI FLANGE 2" 5 KSI 13 5/8" 3000 PSI FLANGE 3000 PSI 12.25 HOLE 3000 PSI STACK TOP OF DERRICK FLOOR r 1 i BOTTOM OF ROTARY BEAM ' ] I DRILL FLOW LINE NIPPLE · FILL UP LINE , ANNULAR x ;~ ~ PREVENTER ~ 5000 PSI -5/8" 5000 PSI FLANGE ( BLIND RAM 5000 PSI PIPE RAM 5000 PSI 13-5/8" -- - -- FLANGE 2-1/16" KILL LINE ~ ~ ~ ~ ~ m I DRILL ! 3-1/8" NE 13-5/8" 5000 PSI FLANGE RIG CELLAR FLOOR I 5000 PSI RISER ~, ~,.. ,--¢-. ~ ,:: .~. ,..,,:', .--.. 13-5/8" 5000 PSI FLANGE ~' ~' ~'a ~; · DRILL ala~...G,I .& Gas Cons. Commisslm~ SPOOL Anchorage CASING WE~EAD ROOM FLOOR HOLE 2000 PSI STACK BOTTOM OF ROTARY BEAM FILL UP LINE RIG CELLAR FLOOR WELLHEAD ROOM FLOOR TOP OF DERRICK FLOOR V 7 \ / DRILL ?LOW LINE I NIPPLE ANNUI~R 20" RISER 20" 2000 PSI FLANGE BOTH 10" MECHANICAL FULL-OPENING VALVES WILL BE IN AN OPEN POSITION. UPON CLOSING THE ANNULAR PREVENTER, THE PROPER DIVERTER LINE IS SELECTED. 20" 2000 PSI FLANGE TO BE CONNECTED SO THAT VALVE IS AUTOMATICALLY & SIMULTANEOUSLY OPENED WHEN THE ANNULAR PREVENTER IS CLOSED, StlEI_L WESTERN E&P INC. MIDDI_E GROUND SHOAL FIELD I 3' 5 KSI LINES 2. CltOSS 3' X 3' X 3' X 3' 5 KSI 3, CIIOSS 3" X 3' X 3' X 3' X 3' 5 KSI ,I. 3' 5 KSI GAI'E VALVE.. 5. AI),JlJSTABLE MANUAL CttOKE - 3' 5 KSI v IIEMOTE OPERATED CHOKE - 2-9/16' 10KSI tlYDRAULIG ADJUSTABLE ~/" 7. PflI::SSIJRE GAGE ,.., 8. 4' I. INES §. MIlD/GAS SEPAIIATOFI I0. 6' I.INE PLATFORM "A" CtlOKE MANI FOLD VENI'ED Al- CROW INLE' // (.~) I() Mill) I'11'; 2 C½FL~.~ , . WESTF, 7VFLL LOCATION ~LAT MIDDLE GROUND SHOAL FIELD A-PLATFORM COOK INLET, ALASKA WELt.: A13-A1 ~uTIOM HOLE LOCATION 5359 FSL 5200 FEL 501 108N R13W · ~SP ZONE 4 x = 2~3453 58 ¥=2492843 90 FARGET 3241 FSL 5152 FEL SEC 01 T08N R13W ASP ZON£ 4 X=265498 65 ¥=2492725.00 lOP OF HEMLOCK 1501 FSL 4682 FEL SEC O1 TO8N R13W ASP ZONE 4 x=255929 86 ¥~2490974 75 !' SEC O1 TOSN R13W -01Pu SEWARD MERIDIAN '-12G A-5~-11R \ \ A-13-t26 A-23-120 A-13-12RDG A-11-13R1C 42-146 A-34-t4R16 A-J4-14G / --~,~,-.,-,~;~""~"-~ Oil & COil,S, '~' ...."'~ -. baa ,OH Z A-34-i4R2Q GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for SHELL WESTERN EXPLORATION & PRODUCTION Well ......... : A-13A-01 (P3) Field ........ : MIDDLE GROUND SHOALS Computation..: MINIMUM CURVATURE Units ........ : FEET Surface Lat..: 60.79577485 N Surface Long.: 151.49527732 W Prepared ..... : 07/26/93 Section at...: 10.12 KB elevation.: 116.00 ft Magnetic Dcln: 24.000 E \ Scale Factor.: 0.99998 .) Convergence..: -1.30527767 LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 1621 FSL 326 FEL Sll T08N R13W SM 232891.57 2485837.17 Target ....... : 3241 FSL 5152 FEL S01 T08N R13W SM 233498.63 2492725.00 BHL .......... : 3359 FSL 5200 FEL S01 T08N R13W SM 233453.58 2492843.90 PROPOSED WELL PROFILE STATION IDENTIFICATION KB KOP BUILD 1.00/100 MEAS INCLN DIRECTION VERT-DEPTHS SECT RELATIVE-COORDINATES DEPTH ANGLE AZIMUTH BKB SUB-S DIST FROM-THE-WELLHEAD STATE-PLANE TOOL DL/ X Y FACE 100 0 0.00 0.00 0 -116 0 0.00 N 1000 0.00 10.12 1000 884 ~ 0.00 N 1100 1.00 10.12 1100 984 1 0.86 N 1200 2.00 10.12 1200 1084 3 3.44 N 1300 3.00 10.12 1300 1184 8 7.73 N 0.00 E 232891.57 2485837.17 0.00 0.00 E 232891.57 2485837.17 HS 0.C ~ 0.15 E 232891.74 2485838.03 HS 1.0~ 0.61 E 232892.26 2485840.59 HS 1.0~ 1.38 E 232893.13 2485844.87 HS 1. 1400 4.00 10.12 1400 1284 14 13.74 N 1500 5.00 10.12 1499 1383 22 21.46 N 1600 6.00 10.12 1599 1483 31 30.90 N 1700 7.00 10.12 1698 1582 43 42.04 N 1800 8.00 10.12 1797 1681 56 54.89 N 2.45 E 232894.33 2485850.85 HS 1.00 3.83 E 232895.89 2485858.54 HS 1.00 5.52 E 232897.79 2485867.93 HS 1.00 7.50 E 232900.03 2485879.03 HS 1.00 9.80 E 232902.62 2485891.82 HS 1.00 1900 9.00 10.12 1896 1780 71 69.44 N 2000 10.00 10.12 1995 1879 87 85.69 N 2100 11.00 10.12 2093 1977 105 103.63 N 2200 12.00 10.12 2191 2075 125 123.26 N 12.39 E 232905.54 2485906.31 HS 1.00 15.29 E 232908.81 2485922.49 HS 1.00 18.50 E 232912.42 2485940.35 HS 1.00 22.00 E 232916.37 2485959.89 HS 1.00 A-13A-01 (P3) 07/26/93 Page 2 PROPOSED WELL PROFILE STATION IDENTIFICATION MEAS DEPTH 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 46O0 4700 4800 4900 5000 5100 5200 5300 INCLN ANGLE 13.00 14.00 15.00 16.00 17.00 18.00 19.00 20.00 21.00 22.00 23.00 24.00 25.00 26.00 27.00 28.00 29.00 30.00 31.00 32.00 33.00 34.00 35.00 36.00 37.00 38.00 39.00 40.00 41.00 42.00 43.00 DIRECTION AZIMUTH VERT-DEPTHS SECT BKB SUB-S DIST 10.12 2289 2173 147 10.12 2386 2270 170 10.12 2483 2367 195 10.12 2579 2463 222 10.12 2675 2559 250 10.12 2771 2655 280 10.12 2865 2749 312 10.12 2960 2844 346 10.12 3053 2937 381 10.12 3146 3030 417 10.12 3239 3123 455 10.12 3330 3214 495 10.12 3421 3305 537 10.12 3512 3396 580 10.12 3601 3485 624 10.12 10.12 10.12 10.12 10.12 3690 3574 671 3778 3662 718 3865 3749 768 3951 3835 818 4036 3920 87~ , 10.12 4121 4005 924 10.12 4204 4088 980 10.12 4286 4170 1036 10.12 4368 4252 1094 10.12 4448 4332 1154 10.12 4527 4411 1215 10.12 4606 4490 1277 10.12 4683 4567 1340 10.12 4759 4643 1405 10.12 4834 4718 1472 10.12 4908 4792 1539 RELATIVE-COORDINATES FROM-THE-WELLHEAD 144.56 N 25.80 E 167.55 N 29.90 E 192.19 N 34.30 E 218.50 N 39.00 E 246.46 N 43.99 E 276.06 N 49.27 E 307.30 N 54.85 E 340.16 N 60.71 E 374.64 N 66.87 E 410.71 N 73.31 E 448.39 N 80.03 E 487.64 N 87.04 E 528.46 N 94.32 E 570.85 N 101.89 E 614.77 N 109.73 E 660.23 N 117.84 E 707.20 N 126.23 E 755.68 N 134.88 E 805.64 N 143.80 E 857.07 N 152.98 E 909.97 N 162.42 E 964.30 N 172.12 E 1020.06 N 182.07 E 1077.23 N 192.27 E 1135.78 N 202.72 E 1195.71 N 213.42 E 1256.99 N 224.36 E 1319.61 N 235.54 E 1383.54 N 246.95 E 1448.78 N 258.59 E 1515.28 N 270.46 E STATE-PLANE TOOL X Y FACE 232920.66 2485981.11 HS 232925.28 2486003.99 HS 232930.24 2486028.53 HS 232935.54 2486054.72 HS 232941.16 2486082.56 HS 232947.12 2486112.03 HS 232953.40 2486143.13 HS 232960.02 2486175.85 HS 232966.95 2486210.18 HS 232974.21 2486246.10 HS DL/ 100 1.00 1.00 1.00 1.00 1.00 1.0'0 1.0~ 1.00 233074.67 2486743.18 HS 1.0n 233085.61 2486797.28 HS 1.~ 233096.82 2486852.80 HS 1.00 233108.33 2486909.72 HS 1.00 233120.11 2486968.02 HS 1.00 233132.17 2487027.69 HS 1.00 233144.50 2487088.70 HS 1.00 233157.10 2487151.05 HS 1.00 233169.96 2487214.70 HS 1.00 233183.09 2487279.65 HS 1.00 233196.47 2487345.87 HS 1.00 233024.42 2486494.53 HS 1.00 233033.87 2486541.30 HS 1.00 233043.63 2486589.56 HS 1.00 233053.68 2486639.31 HS 1.00 233064.03 2486690.52 HS 1.0 232981.79 2486283.61 HS 1.00 232989.69 2486322.69 HS 1.00 232997.91 2486363.34 HS 1.00 233006.43 2486405.54 HS 1.00 233015.27 2486449.27 HS 1.00 A-13A-01 (P3) 07/26/93 Page 3 PROPOSED WELL PROFILE STATION IDENTIFICATION END OF 1.00 BUILD END OF HOLD TOP HEMLOCK TARGET TD MEAS DEPTH 5400 5500 5581 10470 10470 10500 10600 10700 10800 10900 11000 11100 11200 11300 11400 11500 11584 12720 12870 INCLN ANGLE 44.00 45.00 45.81 45.81 45.81 46.01 46.73 47.54 48.44 49.42 50.48 51.61 52.82 54.08 55.40 56.77 57.96 57.96 57.96 DIRECTION VERT- DEPTHS SECT AZIMUTH BKB SUB-S DIST 10.12 4980 4864 1608 10.12 5051 4935 1678 10.12 5108 4992 1736 10.12 8516 8400 5242 10.12 8516 8400 5242 9.11 8537 8421 5263 5.80 8606 8490 5335 2.58 8674 8558 5408 359.44 8741 8625 5482 356.39 8807 8691 5555 353.43 8871 8755 5629 350.57 8934 8818 5703 347.79 8995 8879 5777 345.10 9055 8939 5850 342.51 9112 8996 5924 339.99 9168 9052 5996 337.94 9213 9097 6057 337.94 9816 9700 6872 337.94 9896 9780 6979 RELATIVE-COORDINATES FROM-THE-WELLHEAD 1583.05 N 282.56 E 1652.05 N 294.87 E 1708.98 N 305.03 E 5160.00 N 921.00 E 5160.00 N 921.00 E 5181.23 N 924.60 E 5252.98 N 933.98 E 5326.06 N 939.32 E 5400.33 N 940.61 E 5475.65 N 937.85 E 5551.88 N 931.05 E 5628.87 N 920.21 E 5706.48 N 905.36 E 5784.56 N 886.52 E 5862.95 N 863.74 E 5941.52 N 837.05 E 6007.39 N 811.71 E 6900.00 N 450.00 E 7017.85 N 402.24 E STATE-PLANE TOOL X Y FACE 233210.11 2487413.34 HS 233223.99 2487482.04 HS 233235.45 2487538.73 233929.86 2490974.75 75L 233929.86 2490974.75 75L 233933.94 2490995.89 74L 233944.95 2491067.41 72L 233951.96 2491140.34 70L 233954.94 2491214.57 68L 233953.90 2491289.93 66L DL/ 100 1.00 1.00 1.00 0.00 0.00 · 2, ) 2.50 2.5 2.50 2.50 233948.83 2491366.29 64L 2.50 233939.75 2491443.51 62L 2.50 233926.67 2491521.44 60L 2.50 233909.62 2491599.92 59L 2.50 233888.63 2491678.81 57L 2.50 233863.74 2491757.97 233839.91 2491824.39 233498.63 2492725.00 233453.58 2492843.90 56L 2.50 2.50 0.00 0.00 SHELL WESTEdN EXPLORAT I ON ~- PRODUCT I ON A-13A-O~ (P3) VERTICAL SECTION VIEW ISection at: ~0.~2 ITVO Scale.: 1 inch = 1200 feet IOeo Scale.: ~ inch = 1200 feet Sreat Land £jrectJonaJ OrillJng Marker Identification MD BKB SECTN INCLN A~ KB 0 0 0 O. O0 B] KOP BUILD ~.00/100 1000 1000 0 0.00 C) END OF 1 O0 BUILD 558~ 5108 1736 45 81 . . O) END OF HOLD ~0470 8516 5242 45.8~ E) TOP HEMLOCK 10470 85~6 5242 45.81 F) TARGET 12720 9816 6872 57.96 G) TO 12870 9896 6979 57.96 ~ j I i ~ , . , . , 0 600 1200 1800 _2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Section Oeparture (GLOO (c)92 A13AO1EIJ~l,49 9:og AM t) I SHELL WESTE¼N EXPLORATION &- PRODUCTION ,ar'kerA, KB ,dentiftcat. ion MO0,,,,So ,, A- 13A-0 J. (P3) ~ ~o~, ~u,,_o ~.oo/,oo ,ooo o o C) ENO OF J.O0 [BUILD 558' '1709 305 PLAN VIEW OI END OF HOLD ~0470 5'160 92'1 E] TOP HEMLOCK ~0470 5~6o 92~ CLOSURE · 7029 feet at Azimuth 3.28 F) TARGET '12720 6900 450 G) TO '12870 70~8 402 OECLINATION.: 24.000 E SCALE ....... : ~ inch = 1200 feet DRAWN ....... :07/27/93 Srea~ Land D~rec~ona] DrJ]]~ng 7200-- ! ! ! I I i i TI - 8HL " ' [ ~' '1;,870 1'40 j9896 TVD ,I I 3:'59 FSL 5200 FEL SO' RO8N R'13W ! ! i A!;P 7(')NE ,:J X=2334:i3.SR 6600-- ~ Yi?4qPR4R 6000- - ! i ~ 5400--- [ . . I ! ~ ~ B TOP HEN.OCK i I I · I I / 1501 FSL 4682 FI _ SO1 fO8N R13W SM . · [ ! ASP 7flNF 4 x=2: "4q2q RR ! Y=2.4qf)q".4 75 4800--- ' [ i / :t0470 MD 85'16 VD , / ~2oo-- i ' 3600- - , J I : ~ooo-- ~ i ! /I I I ~"'- ~, ' i!, r :i8oo-- i i ! llc j .,"~laska Oi, & (:las (Jons. , ! i F I - ,--..,, u ,~2oo i ~ i // S~RFACE LCCATTON I i [ -' ! 162'1FSL 326 FEL S'11 fO8N RiBW SMI ' ' / ASP Z_ON_E zl X=2~3~289]..57 Y=~485837. '1~ ! i ! I A PLATFOD.I LEG,~ CONBtJ6-TeR-/~24 "2 600- - i ~ : v' 600 I I i I I [ '1 4200 3600 3000 2400 ~800 1200 600 0 600 ~.200 ~.800 2400 3000 3600 4200 <- 'NEST : EAST -> . . (GLOD (c}92 At3AO18 81.49 9: lO AN j) MIDDLE GROUND SHOAL DRILLING PROGNOSIS WELL: A13A-01 LOCATION: Platform A, Leg 3, Conductor 24 OBJECTIVE: Hemlock FIELD: Middle Ground Shoal KB: 1 16' EVALUATION GEOLOGY LOGS DIL BH¢ GR DIL BHO GR DIL BHC GR FM$ I MUD FORMATION LOGGER TOPS Mudlogger 378' 3216' · HO 7666' · HZ 851 6' · HC 9985' · WELL DEPTH (MD) 378' 3,275' 9,251' 1 O, 470' HOLE SIZE CASING 24" DIRECTIONAL MUD PROGRAM 17-1/2' 13-3/8' KOP @ lO00' Seawater generic Mud #2 9. O ppg BUILD TO 46 deg @ 1 deg/100' N1 OW dir 12-1/4' Seawater generic Mud #2 9.5 ppg 9-5/8' 8-1/F 7-5/8' Seawater generic Mud #2 w/PHPA 9,8 ppg 6-3/4" Build to Seawater 58 deg generic & turn Mud #2 to N22W w/PHPA 9.8 ppg > i!",,?"~ ~I~ , '. ~!.. DRILLING PROGRAM MIDDLE GROUND SHOAL WELL A13A-01 1. Rig up over leg 3, conductor 24. Nipple up diverter system. 2. Clean out 24" casing and drill 17 1/2" hole to 1,000'. 3.- Kick well off in 17 1/2" hole and build angle at 1 degree per 1000' in 10 degree azimuth direction to 3,275'MD, 3,216' TVD. · Set 13 3/8" casing and cement to surface. Nipple up BOP stack. Test all connections, valves and rams to 3,000 psi. Test annular preventer to 2,500 psi. Test all kelly, standpipe, and emergency valves to 3,000 psi. Test casing to 1,500 psi. All tests performed in accordance with AOGCC regulations. 5. Drill out 10' and perform pressure integrity test. · Drill out with 12 1/4" bit and continue build at 1 degree per 1000' to 46 degree angle. Hold angle and drill to 9,251'MD, 7,666'TVD. 7. Run wireline logs. (Gamma ray, induction) 8. Set 9 5/8" protective string and cement. · Nipple up BOP stack. Test all connections, valves and rams to 3,000 psi. Test annular preventer to 2,500 psi. Test all kelly, standpipe and emergency valves to 3,000 psi. Test casing to 1,500 psi. All tests performed in accordance with AOGCC regulations. 10. Test casing to 2,500 psi and drill out with 8 1/2" hole. Drill 10' and perform pressure integrity test. 11. Directionally drill 8 1/2" hole to 10,470'MD, 8,516'TVD. 12. Run wireline logs. (Gamma ray, induction) 13. Run 7 5/8" liner and cement. 14. Test liner to 2,500 psi and drill out with 6 3/4" hole. Drill 10' and perform pressure integrity test. 16. Directionally drill 6 3/4" hole to N22W direction and 58 degree hole angle. Drill to TD at 13,000'MD, 9,965'TVD. 17. Run wireline logs. (Gamma ray, induction) 18. Run and cement 5" liner· Proceed with cased hole completion. RECOMMENDED MUD PROGRAM WELL A13A-01 17 1/2" Hole Interval Mud type Mud weight 12 1/4" Hole Interval Mud type Mud weight 1/2" Hole Interval Mud type Mud weight 3/4" Hole Interval Mud type Mud weight 0 - 3,275'MD Seawater generic mud #2 9.0 ppg 3,275'MD - 10,470'MD Seawater generic mud #2 9.5 ppg 9,251'MD - 10,470'MD Seawater generic mud #2 9.8 ppg 10,470'MD - 13,000'MD Seawater generic mud #2 9.8 ppg CASING AND CEMENT PROGRAM A13A-01 · . · o . . · Be Run 13 3/8" from surface to 3,275~ MD. Casing design specifications and criteria are attached. Cement surface casing using 20% excess of gauge hole volume from TD to conductor shoe. Use 2,775' of lead cement and 500' of tail cement. The lead will be Premium Cement + 2% calcium chloride + 10% gel + dispersant + water (12.9 ppg, 10.43 gps, 1.95 cf/sack). The tail will be Premium Cement + 2% calcium chloride + dispersant + water (15.8 ppg, 5.0 gps, 1.15 cfs). Perform top job within shoe of conductor. Approximate volumes' lead of 1350 sacks tail of 420 sacks Run 9 5/8" from surface to 9,251~ MD. Casing design specification and criteria are attached. Cement to 2,500' above the 9 5/8" shoe using 30% excess of caliper. Use 1,000~ of lead cement followed by 1,500~ of tail cement. The lead will be Premium Cement + 10% gel + dispersant + retarder + water (12.9 ppg, 10.43 gps, 1.95 cfs). The tail will be Premium Cement + fluid loss + retarder + dispersant + water (15.8 ppg, 5.0 gps, 1.15 cfs). Approximate volumes- lead of 210 sacks tail of 560 sacks Run 7 5/8" liner from 400~ above the 9 5/8" shoe (8,851~) to 10,470~ MD. Casing design and specification criteria are attached. Cement with 30% excess of caliper hole volume and 300~ of excess cement on top of liner. Cement will be either of the two following slurries- 1) Cement (Trinity light wate) + fluid loss + retarder + dispersant + water (13.2 ppg, 6.6 gps, 1.32 cfs). 2) Slag + drilling mud + soda ash + caustic + spersene (14.5 ppg) Approximate volumes- cement 240 sacks or slag 17,000# The slurry choice will be dependent on EPA approval of the use of slag in cement i ng. Run 5" liner from 400~ above the 7 5/8" shoe (10,070~) to 13,000~ MD. Casing design specification and criteria are attached. Cement with 30% excess of caliper hole volume and 300~ of excess cement on top of liner. Cement will be either of the two following~r§l~.u~].~:~.!, ~ ........ 1) Cement (Trinity light wate) + fluid loss + retarder + dispersant + water (13.2 ppg, 6.6 gps, 1.32 cfs). 2) Slag + drilling mud + soda ash + caustic + spersene (14.5 ppg) Approximate volumes' cement 380 sacks or sl ag 27,000# The slurry choice will be dependent on EPA approval of the use of slag in cementing. A13A-01 CASING DESIGN Casing Design Criteria 13-3/8" 9-5/8" 7-5/8" 5mI Fracture gradient @ shoe Pressure gradient (maximum @ any future time in field) Collapse criteria Maximum burst pressure Projected mud weight Size 0.6 psi/ft 0.45 psi/ft Full evacuation 500 psi (surface pressure with 9.0 ppg and leakoff @ shoe) 9.0 ppg Grade/ Coupling 0.8 psi/ft 0.45 psi/ft @ 7000 TVD 0.57 psi/ft @ 7660 TVD Full evacuation 3,500 psi (injection pressure) 9.5 ppg ACTUAL DESIGN CONDITION Bouyed Collapse Tension (psi) (#) 0.8 psi/ft 0.62 psi/ft Full evacuation 3,500 psi (injection pressure) 9.8 ppg Burst (psi) 0.8 psi/ft 0.62 psi/ft Full evacuation 5,000 psi (acid job) 9.8 ppg Casing Rating/Design Factors Tension Co[lapse Burst (kips) (psi) (psi) 13-3/8" 0 - 2,518' MD 0 - 2,500 TVD 2,518' - 3,275' MD 2,500' - 3,216' TVD 9-5/8" 0 - 8,304' MD 0 - 7,000' TVD 8,304' - 9,251' MD 7,000' - 7,660' TVO 7-5/8" 8,851' - 10,470' MD 7,382' - 8,516' TVD 5" 10,070' - 13,000' MD 8,238' ' 9,965' TVD 54.5 61.0 43.5 47.0 29.7 18.0 K-55 BTC K-55 BTC L-80 LTC L-80 LTC P-110 FL4S P-110 LTC 155,000 1,125 500 37,600 1,447 5OO 286,900 3,150 3,500 26,500 4,366 3,500 28,600 5,280 3,500 26,400 6,180 5,000 853/5.50 1130/1.00 2950/5.90 962/+10 1540/1.06 3090/6.18 813/2.83 3810/1.21 7090/2.03 893/+10 4750/1.09 6870/1.96 600/+10 5340/1.01 9470/2.71 380/+10 13450/2.18 13940/2.79 MAJO4\CASDESN.WP5 MISCELLANEOUS The maximum expected pressure ~radient is 0.57 psi/ft. Maximum BHP is expected to be 5,700 psi. Maximum surface pressure is expected to be 2,100 psi assuming a full column of 0.36 psi/ft oil. The well will be drilled in compliance with the Alaska Oil & Gas Conservation Commission's regulations. The proposed well path will pass in the vicinity of several active producers and injectors. In order to prevent possible intersectins with these wells, collision cones of uncertainty will be calculated for each well based on the survey instruments used to survey each. Should the actual wellpath intersect any of these collision cones, the affected wells will be shut in and bled down. Single shot gyros will be taken while drilling the surface hole immediately below the platform and MWD surveys will be taken while drilling intermediate hole. As noted in the drawing of the diverter, both 10" mechanical valves will be kept in an open position until the preventer is closed. The mechanical valves will be wired full open and tagged with instructions concerning proper procedures for closing a valve in the event the preventer is closed. Shell Western E&P Inc. An affiliate of Shell Oil Company 601 West Fifth Avenue Suite 800 Anchorage AK 99501 JULY 30, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' SUBMISSION OF THE APPLICATION FOR SHOAL WELL NO. A13A-01 PERMIT TO DRILL MIDDLE GROUND Enclosed is the Application for Permit to Drill well A13A-01, Middle Ground Shoal. The surface location is Platform "A", Leg 3, Conductor 24. Well A13A-01 will be drilled to the North West into the West flank of the anticline. Note that A13A-01 will be the fifth producer in the governmental quarter section. SWEPI requests a variance by way of Administrative Approval (Rule 6), from Rule 1 of Conservation Order #44. We are currently scheduling operations to begin on A13A-01 by September 10, 1993. Drilling operations are expected to continue for 2.5 months. If you have any questions regarding this report, please contact Jeff Wahleithner at (713) 544-3344. Yours truly, R. G~ Manager Alaska Operations RGB/JPW/maj Enclosures MAJO4\A13AO 1P. WP5 d U L 3, 0 199;5 Alaska Oil & Gas Cons. Commission Anchorage ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE T'2 thru [10 & 13] 12. ~/~ 13. (4) ,Cas& ~ g 14. [14 thru 22] 15. [23 thru 28] ' (5) BOPE (6) Other ~_~C~ ru~~ [29 th [32] Company ~'~// Lease & Well YES 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 ............................ _ ...... (7) Contact (8) Add] geology:_ engineerin9' ...... TAB 5~ rev 6/93 jo/6.011 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s adm i n i st rat ive approval needed .................................... Is 1 ease nL~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided .......................... ~.~.~.~.~.~.~-, .. · Wil 1 surface casing protect al 1 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 ...... Wil 1 cement cover al 1 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 ............. s,'," /4 6_; NO - ' ' ~EMARKS I Is adequate wellbore separation proposed ............................. ~ Is a d iverter system requi~ed ........... ....................... Is drilling fluid progral~ schematic ~'iist of equipment adequate ~ , Are necessary diagrams & descriptions of diverter g BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~6=~oO psi& ..... 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... Name and phone n~nber of contact to supply weekly progress data ...... l/ Add i t i ona 1 requ i rements ............................................. Add i t i ona 1 INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE , , remarks' UM MERIDIAN' SM'>~ WELL TYPE' E x p / ~e~v))( Red ri l 1 Inj Rev 0 --4 "r'Z