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Home My WebLink About187-089Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. _~ <~ r~_ 0 ~-- Well History File Identifier RESCAN DIGITAL DATA [:3 Color items: n Diskettes, No. [3 Grayscale items: [] Other, No/Type [] Poor Quality Originals: [3 Other: TOTAL PAGES: ~'~/~' NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) n Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other /si Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ PAGES: (at the time of scanning) SCANNED BY; ~ BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI RESCANNEDBY; BEVERLY BR~ERYL MARIA LOWELL DATE: ¢// General Notes or Comments about this file:'~-~ ~. ' , lity Checked (done) RevlNOTScanned.w~d MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Memorandmn State of Alaska Oil and Gas Conservation Commission To: Re' Well File: (~ '~) -' ~'~~~i DATE Cancelled or Expired Permit Act'on EXAMPLE: Point McIntyre 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 multilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl 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. t-eve McMains ' ' ~Y,Z,,,3/- Statistical Technician September 3, 1987f J Mr. Roy D.~R? ..... , ' I~------ Environmentaz Engineer ~ Union Oil Company of' California P. O. Box 190247 Anchorage, Alaska 99502 Telecopy: (907) 276-7542 Re: Trading Bay Unit M-3 Union Oil Company of California Permit No. 87-89 Sur. Loc. 1039'FNL, 595'FILL, Sec. 33, T9N, R13W, SM Btmhole Loc. ll00'FNL, 500'FWL, Sec. 33, TgN, R13W, SM Dear Mr. Roberts: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Cha~ter~ton~ Chairman o f Alaska Oil and Gas Conservation Commission dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill }~. Lamoreaux Alaskan r. ct Production united States Marathon Oil Company RD. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 August 12, 1987 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Minder: Attached with this letter is the application for the Permit to Drill Well M-3 from the Steelhead Platform and the filing fee. Should you have any questions concerning the application, please contact me at 564-6316. Regards, Guy R. Whitlock Drilling Superintendent GRW/RLH/rs/DD5/147 Attachments RECEIVED A~G ~?l~l Alaska Oil & Gas Cons. Com~isSiO~ Anchorage :--, STATE OF ALASKA ALASKA' AND GAS CONSERVATION CC.. ~VllSSION PERMIT TO DRILL 20 AAC 25.005 E~I Development O~1 ? .~,..~. ~ la. Type of work Drill E~ Redrill lb. Type of well. Exploratory [] Stra.~igraphic Test [] .... Re-Entry [] Deepen Service [] 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 ~ 163' KB feet McArthur River 3. Address 6. Property Designation P. O. Box 190247, Anchorage~ AK 99519 ADL 18730 Middle Kenai Gas 4. Location of well at surface 1039 FNL, 595 l~g, 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) Sec. 33, T9N, R13W, SM. Steelhead Platform, Trading Bay Lea B- 2, ,Con~uc. tor..~ 5.. ~At tod of proaum~ve ~merva~ 8. Well number Number 4080' ~VI): 1100' FNL, 500' FWL, Sec. 33 ' 5940' · 100' FNL, 500' FWL, Sec. 33 M-3 B-2-165-724-1 At tota~d:ep~-h 9. Approximate spud date Amount 6245' TVI)' 1100' FNL, 500' FWL, Sec. 33 01 October 1987 $200,000 neCrest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 12. Distance to nearest 13¢e~ta~_c~, t~j.O to ;' 6245 ~o¢,~rty line feet SE at. 480' ]VJ]') feet: 5840 6245 ~ feet 16. To be completed for deviated wells st.raight, ]'tole 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth -- feet Maximum hole angle -- 0 Maximum surface 2376 ps~g At total depth (TVD)2660 ps~g 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) 26 20 91.5 X-5( 1~b-4C 075' 75 '15 '/bt) 750 ±4UU sx 17-1/2 13-3/8 61.0 K-55 Bu'Fr 2100' 75 75 i2175 2175 15t)O sx 12-1/4 10-3/4 55.5 N-86 BU'Ft' 501' 69 69 570 570 2300 sx 12-1/4 9-5/8 43.5 N-8£ BU'I"t' 3930' 570 570 4500 4500 12-1/4 9-b/8 47.U N-~L BU't"I' 1745' 4500 4500 6245 6245 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 . ~ Conductor Surface Intermediate *,. ,'.' Production ~ ~-.5 ~' ~ ~,~\ Liner l~~ %O~'~u ' Perforation depth: measured ~-,,~ true veCt~C~,al ~arathon Oil Compart¥--Sub-ogerator 20. Attachments Filing fee ~ PropertY plat ~ BOP Sketch E~ Diverter Sketch E~ Drilling program Drilling fluid program E~ 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 /~~./~g~~,¢ ?~-~-Title]g~viro~t~l ]~!~tgJ~ee~ Date 8/26/8' · ]3e~ts Commission Use Only Permit Number I APl number J Approval date J See cover letter 87-89 5o- 733-20392 09/03/87 for other requirements Conditions of approval Samples requ~e~d. [] Yes ~¢¢r~]'o Mud Icg required '~' Yes [] No (,'.i-,¢' Hydrogen sulfide measures [] Yes ~o Directional survey required [] Ye~'"¢o Required wo~/~forB~~~; E~ 5M; [] 1OM; ~ 15M D~e__..~,~~~~ Other: by order of Approved by~ ~ , , , Commissioner the commission. ,' Form 10-401 Rev.-'~t'2-1-85 Submit ca~ 24 3O ADL 17594 13 ADL 17602 DATUM: ALAIKA &TATT I~ANE COORt)INA'I~ IYIT,ll. ZONE 4 + KING SALMON + a-I · r--J' I~.iM. I~JM' DOLLY VAR:DEN TRADING BAY UNIT BOUNDARY ,,,. * -;,- .-1,~ -~' '+.' -4-, +~,, ADL 18729 18 -F ~).POII LIIIII ORdMlllL-- I · I--I1 ADL 18772 27 :34 ~ ADL 18730 + I 35 A,~as~a 0~ & Gas Cons. O. otnmissior) 15 MARATHON OIL COMPANY A lib l) · ~v TRADING BAY UNIT McARTHUR RIVER FIELD ICAL[..' 1', 1HO' At)TNONt GATE: AUG. 1lmm FILE IO.~__ STEELHEAD PLATFORM BOP Schematic WELL: M-~ FROM MUD PUMPS HYD. CHOKE ADJUSTABLE CHOKE CHOKE PRESS. SENSOR MANIFOLD i DRILLFLOOR 3' - 3' TO MUD SEPARATOR 3' TO DERRICK VENT TO SHALE SHAKER , ~W LINE ~ ~_ HYDRIL TYPE GK / ].....~3 5/8' X 5000 PSI · ~-~ ~===~ ska Oil & Gas. ns. c0mmiss ~o FLEXlP HOSE ' t:1 ~'t HYDRIL TYPE V 13 5/8' X 5000 PSI _.~ 13 5/8' -5000 PSI RISER J ~'~ 13 3/8' - 5000 PSI I I i 30' DRIVE PiPE f ~ ~20' CONDUCTOR j ~,J 13 3/8' SURFACE CASING STEELHEAD PLATFORM DIVERTER SYSTEM SPECIFICATIONS 1. Riser = 30" OD, rated to 500 psi. 2. BOP = 30" Hydril Annular, rated to 500 psi. 3. Block valve = 10", 300 psi, full opening ball valve w/hydraulic actuator.* 4. Diverter line = 250 mm nominal schedule 40. ID = 9.80", OD = 10.53". 5. Direction ~lves = 10", 300 psi, full opening ball valves w/hydraulic actuators. * Block valve is hydraulically manifolded to annular BOP such that block valve will automatically open when annular BOP is closed. ++ Direction valves hydraulically manifolded together such that one valve is always open. NOTE: Ail turns in line are targeted. GRW/RLH/rs/DD5 / 3 STEELHEAD PLATFORM DIVERTER SYSTEM OPERATIONAL PROCEDURE TO CLOSE ANNULAR BOP Push "close" button on diverter system BOP control panel. Diverter block valve will automatically open. TO CHANGE DIRECTION OF VENT Push appropriate button on diverter system control panel. If west venting is desired, push "west". If east vent is desired, push "east". The hydrualically actuated valves are connected such that opening of one valve closes the other valve. Therefore, it is not possible to close both direction valves. ACTUATION OF BOP EQUIPMENT The BOP equipment on the Steelhead can be actuated form the main control panel on the rig floor or from two remote panels which are located on the bottom level at the southwest and northwest corners where the Whittaker Emergency Escape craft are located. Also, a monitoring panel is located in the drilling foreman's office. GRW/RLH / rs/DD 5 / 3 DI~?"'iRTER SYSTEM SCHEM~'"~TIC ANNULAR BOP DIVE--ERn ~ SPOOL I0' DIVERTER LINE BLOCK VALVE -' DIRECTION VALVES 153' 9' ANNULAR SCHEMATIC BOTTOM OF FLOW NIPPLE FLOW NIPPLE SLIP JOINT T 59-5/8' 29 1/2' HYDRIL ~"'500 PSI BOP I t ~~ DIVERTER SPOOL ~ 13 2-7/8' ,] N DIVERTER LINE I RISER SPOOL 110' 9' PIPE RACK FLOOR RISER spOOL 88' 10' OUTLET WELLROOM FLOOR JACKET TOP STARTING HUB . CONDUCTOR EXTENSION 30' ANNULAR SCHEMATIC 153' 9' 132' 9' BOTTOM OF FLOW NIPPLE 59-5/8' S DIVERTER LINE TOP OF ,4 t0 ~ PIPE RACK ~ FLOW NIPPLE ~SLIP JOINT __ !9 1/2' HYDRIL 500 PSI BOP ~.~.-- DIVERTER SPOOL · N DIVERTER LINE RISER SPOOL 110' 9' PIPE RACK FLOOR 88' 10' OUTLET WELLROOM FLOOR 67' JACKET T~P RISER SPOOL STARTING HUB ~ CONDUCTOR EXTENSION - -- STEELHEAD PLATFORM OPERATIONAL PROCEDURE FOR LOST CIRCULATION Should lost circulation occur during the drilling of the 26" hole from 0 to ± 800' TVD returns will be taken at the 88' level above MLLW rather than at the rig floor at 162' level above MLLW. There is a 10" outlet on the 30" riser at the platform's 88' level for returns to go overboard if lost circulation does occur. The valve on this outlet will be manned continuously during drilling and circulating operations. Personnel at this location will be responsible for opening and closing the valve and monitoring drilling fluid returns. GRW /RLH / r s/DD 5 / 3 .( A A 1__ I,D '"'lID. I ....z~ i, i ¥.~ oo J~ i~!.~-,..,. I(~(I 'Il Ill. -- [:llll I I' II1.1 PIT /I(X) II Ill.'""-.-. I-ill(')' £ l I~ AIIE Il , I~l ' Ira: ~ll'l~'l."--.... C [lll'fl I F H~i.' .... i~1 /--' I00 VII:^I'IIITII-Tll;II fl \ I.IIJO ui,, / I'lll.ll! ,. TJIIJS.~ I=1 "l' 1'fills S MARATHON OIL COMPANY WELL PROGRAM WELL: Steelhead Platform Well M-3 Field: McArthur River AFE: 8310-7 COORDINATES Surface: 1039' FNL, 595' FWL Sec 33, T9N, R13W, S.M. Leg B-2, Conductor No. 5 Top of Objective: "C" Sands at 4080' TVD: 1100' FNL, 500' FWL, Sec 33, T9N, R13W, S.M. D-16 at 5940' TVD: 1100' FNL, 500' FWL, Sec 33, T9N, R13W, SM. KB Elevation: 163' MLLW Ground Elevation: MLLW Total Depth: 6,245 TVD 6,245 MD Avg. Angle: Straight Course:-- hole GEOLOGICAL PROGRAM Mud loggers on location from 1-5~v' TVD to TD. Estimated Fm Top C-4 C-5 C-6 D-16 MD TVD 4080' 4080' 4130' 4130' 4150' 4150' 5940' 5940' Sub-Sea -3917 Potentially Productive Yes -3967 Yes -3987 Yes -5777 Yes Estimated Total Depth 6245' 6245' -6082 Coring Program: Full Barrel Cores: A-3 Sand, 50' MD; B-3 Sand, 95' MD; C-4 sand, 15' MD; D-6 sand, 40' MD. (200' total core) DST Program: None Logging Program: Not logged Conductor Surface: Not logged Intermediate: DIL/SFL/GR/SP FDC/CNL LSS/GR/SP FMT (25-50 sets) & SW Cores (25-50 shots) Liner: N/A Well Program Page 2 DRILLING PROGRAM Conductor: Drill 26" hole to 750' MD. Run & Cement 20" casing. Surface: Drill 17-1/2" hole to 2175' MD. Run & Cement 13-3/8" casing. Intermediate: Drill 12-1/4" hole to 6,245' MD. or Production Run & cement 9-5/8" casing with 500' 10-3/4" casing on top. Provides adequate clearance for dual 3-1/2" SCSSV's. Liner: N/A DIRECTIONAL PROGRAM Drill vertical hole to 6245' MD. CASING PROGRAM Size Conductor Hole WOC Set At Wt~ Footage Grade Thrd Size Time Cement 20" 750' 91.5 675' Surface 13-3/8" 2175' 61.0 2100' Intermediate 10-3/4" 9-5/8" 9-5/8" Liner N/A From To (TVD) 0' 750' 750' 2175' 2175' 6245' X-56 RL-4C 26" 12 hrs 1400 sx K-55 Butt 17-1/2" 12 hrs 1500 sx 570' 55.5 501' N-80 Butt 4500' 43.5 3930' N-80 Butt 6245' 47.0 1745' N-80 Butt 12-1/4" 12 hrs 2300 sx 12-1/4" 12 hrs 12-1/4" 12 hrs MUD PROGRAM ~,lJ~a~ ~ / [i:~i~/ Alaska 0ii & 6as gons. tommlssi, o~ Wt. Vis. W.L. ph .Type Mud 8.'~-8.8 100-150 NC 8.0 Fresh water low solids non-dispersed 8.6-9.0 40-80 30-12 8.0-8.5 Fresh water low solids non-dispersed 9.0-9.5 40-60 12-8 8.0-8.5 Water base co-pol~er Remarks: None COMPLETION PROGRAM Run 9-5/8" csg to TD w/ 500' of 10-3/4" csg as top section. Cement with 2300 sx of Class "G" cement. Clean out 9-5/8" casing. Make scraper run. Test casing to 2500 psi. Displace hole w/ completion fluid. Run Gyro & CBL. RIH w/ tbg conveyed perf guns & perf the D-16 sand. Set a 9-5/8" packer w/ plug above D-i6 zone. Tbg convey perf the C-4, C-5, C-6 sands. Retrieve the 9-5/8" packer plug. Run dual 3-1/2" completion string w/ dual packer above the "C" sand zones. Unload & test well. 400 - 300 - 200 - 100 - m 100 _ 200 _ 300 _ 400 _ 300 200 "-,-- 100 0 lOb~ 200 I I I I j., 58OO 6OO0 620O 6400 B2-5 800 1000 Well No: M-3 eropoeLd STRAIGHT HOLE TD = 6245 md +/- 1200 600 6800 1400 i I 1600 I 2OO 300 200 100 0 100 300 I I 300 _ 400 _ 300 _ 2OO _ 100 _0 _ 100 _ 20O 300 _ 400 Well M-3 Planned Well Course Interference Check An interference program was run to determine if any Steelhead or Grayling wells come within a proximity radius of 500 feet to Steelhead's Well M-3 planned course. The three wells that fall into this category are as follows: Closest M-3 Well Distance Direction Measured Depth M-1 10.44' N30°35'E 480' M-2 9.59' S57°03E 480' G23-RD 177.52' N84°44'W 6,245' GRW/RLH/r s/DD5/3 18 , W.TRADING BAY-1 K-1I, 30 + TRADING BAY UNI1 BUUNUAi-(¥ O-IlDPN 4~M4ARTM ti,III' 11,114' 14t1N' + ' K.t4 · ,, 15 22 27 W,.IOR ILAND UNIT-'4 , 13 ~KA STA~E PU~NE COORDINATE 8YITE~, ZONE 4 11.itl' 32 5 ~-,4ADPN + · + ~-14#D '~O-lenO 14,i48' ..eft' , KUSTATAN'IA 17 ........... 19 20 + NJEDOUIT IT.-1 11AI1' Alaska 3 r' + I I I I I +1 I;_ I' IRE[EIVED I I I I I I (~il & Gas Cons.£ommissio[~ Anchorage 10 r- ............. 16 _~_ i +- I ! I I I I I I I I + LEGEND 0 WELL LOCATION .e~INJEGll) OIL WELL · GL WELL ~,~INJECTED OAS WEt& · .~ GAS WB.L '4p' &D&NOONgD OIL "F O,L D.OW :~ .,,,..ONEO O^E ~ DRY HOLE [] P'~ATFORI MARATHON OIL COMPANY TRADING BAY UNIT McARTHUR RIVER FIELD SCALE: 1'. 1000' AU'r PRESSURE DETERMINATION C-4,5,6 and D-16 GAS RESERVOIRS The maximum pressure to be encountered while'drilling Well M-3 is expected to occur in the D-16 reservoir. In the D-16 reservoir, targeted for production, a maximum pressure of 2660 psi at 5777' SS is predicted based upon FMT pressure points recored in Well M-1 on 02 July 1987. In the secondary production, the C-4, C-5, & C-6 reservoirs, a pressure of 1500 psi at 3917' SS is predicted based upon the above FMT run. The maximum surface pressure calculated for the D-16 zone sand is 2376 psi. This pressure was calculated using the following formula: Ratio = 1 - (.018 X TVD) 1,000 Ratio = 1 - (.018 X 5940) 1,000 = 0.893 Maximum Surface pressure = Ratio X Formation Pressure = 0.893 X 2660 = 2376 psi LIST OF SOLIDS CONTROL EQUIPMENT 2 each - Brandt Dual Tandem Shale Shakers 1 each - Brandt Desander 1 each - Brandt Mud Cleaner 1 each - Swaco Centrifuge 1 each - Swaco Degasser A Totco E-mud system has been designed into the driller's console. Each of the six active pits are equipped with probes which actuate both visual and audio alarms at the driller's console. A monitored trip tank is located in the substructure of the rig to accurately gauge fluid volumes required to fill the hole on trips. GRW/RHL/rs/DD5 / 3 _) Loc (2. zcn~ 8) (3) Ad~zL~ ~ q--~-~2 (9'~ ]_3) (10 and (4) Ca~ .,~.d'."~<. '/-~ (14 rmru 22) "'(~ ~ 28)" (6) OIlqER ,, 31)" Con, any 1. Is ~ pe:mit fee a~nched .......................................... 2..tS ~11 to be located in a da_~ined pool ............................. 2~ Is w~ll located proper distance fr~n prope_~-y line .................. 4. Is well located p~ d~.~r~nce from or_her w~lls .................... 5. IS sufficient undadicated acreage available in r_his pool ............ 6. Is ~ ~o be daviated and is wellbore plat incl~d ................ 7. Is operator ~he only affected pa_~ ................................. 8 Can permit be approved before f~een-~ wait Lease & Well No. YES NO -- 9. Does operator bay· a bond in force .................................. v~ 10 Is a conservamton order needad ..... 11 Is aJ~i~ ~rauive appr. oval-ne·dad 12. ~ ~ l~e m~ ~~~e ..................................... lB. ~ ~~~ a~~ , 14. Is conductor s~-img provided ........................................ ~f~ 3~. WLll surface casing protect: fresh wacer zones ....................... .~ ,,, 16. Is enough c~=nt used to circulate on conduduor and surface ......... ~ 17. Will c-re=ut tie in surface and intermediate or production strings ... ~ 18. Will c~u cover all known productive horizmns ..................... ~ · 19. Will all casing give adequate safe~y im collapse, tension and burst..~ ' ........ 20. Is ~ well to be kicked off frcm an existing w~!lbore ............ : ~ 2_3 Is a dive_~er system requi~ed - ~ 24. Is r. ha d~!'~ng fluid program scb~t:ic and list of eq~t adequaue~Z 25. Are necessary diagr~m~ and descriptions of diverzer and BOPE ar~.ched./f~, 26. Does BOPE have suf~i~ presm~re ra~g - Test to ~.,oOo pszg .. /f.~, , 27. Does the choke mrna*old comply w/API RP-53 ~y 84) .................. ~¢¢ 28. Is =he presence of ~S. gas probable ................................. , ~ For exploratory and S~rat~hic wells: ~ 29. Are data presented on potential ove_rpress~re zones? .,' ............... ,, 30. Are seismic anslysis data presen:e~ on stmllo~ gas zones ,..., ....... ~-~,,i 31. If an offshore loc., az· ~ results of seabed condi~ns presented ..... i, i,, 11, i ~ol~y: En~erir~: rev: 01/28/87 ~.011 POOL CLASS STATUS AREA NO. SHORE ¢.~,,~;:'~:~ O-~v l_..~q,~i ~,,,~ ~=~6 c,~'"i