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189-004
Safety Valve & Well Pressures Test Report Reviewed By: P.1. snpr '~ . Z ~~~ Comm Pad: MGS_XTO_C_PLATF InspDt: 2/22/2008 °~Inspected by John Crisp Interval InspNo svsJCr080225134306 Related Insp: Field Name MIDDLE GROUND SHOAL Operator XTO ENERGY INC Operator Rep Barney Phillips Reason 90-Day `~ Sre: Inspector Well Data Pilots SSV SSSV Shutln Dt Well Type `Well Pressures Gas Lit Waiver Comments Well Permit Separ Set UP Test Test Pest DateSl O[1,WAG,GINJ, Inner Outer Tubing Number Number PSI PS[ Trip Code Code Code GAS,CYCLE, SI PSI PSI PS[ Yes/No Ycs/No C12 23 ~ 1900200 C 13 23 1880990 C13A 23 1901060 -_ _L -- 68 68 68 -- -- - 37 37 37 ~ 37 0 ~ ----~--- - P P - P P P -- -- P P P - -- 1-O[L 1-OIL - 1-OIL - --- -. -- --- - - -- - - - ~ -- - ---- -- - ------- _ ~-- - -_ 1 -- - --_ - - -----~ - -- - - -- _- -- - - - ----~ i C21 23 ; 1890870 68 0 + P 1-OIL I t - - ----- SSSV f W/ -~ C2l 26 1890040 C21A 23 1910440 ~ ~68 j 68 ~ 0 , O T-- -- P P P P -- --- ~ _ i-O[L - OIL I - _~ ---- _ _ _-- _ _ _- ou[ or L work ~- _ _ - -- - - ----- --~ --- C22-26RD ' 1760650 ' C22A-26LN ~ 2041820 C31-26KD 2041400 I- 68 - 68 68 - A 0 i _ 0~_ 0 ~ P P P ~ - P P P -- - - - - - - i-OIL -- l-OIL l OIL -.__' -- ___ t- i --- I t - --- - ~ ----~ --~ - __- - --.--~ ------ _ __ C32-23LW ------- ! 2020340 r---- - C42-23 I 1780240 --- 68 -- i 68 -- 0 -. _ 0 -- , --- P - P -- - -- - - - - ---1-OIL --- - - -- ~ - - - --~ --.~ - - _ -- - ----- - - ! 043-14 ---I-- 1881320 ~ 68 _ ~ 0 ~- -- P P P ~P 1-OIL 1-OIL i ~ ~ --- + .-.-_1 ~ _-_~ ~ -------------I t=omments Pilot numbers listed on wells 012-23 & 013-23 are fur the pilots on the separators. Individual wells are not equiped with pilots on this platform. ~~~'' MAR ~. 9 208 Performance ;/ ~ Wells Components Failures Failure Rate ~ / 12 25 0 i -______- __ i • • Tuesday, February 26, 2008 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, T8N, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C2]-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC RECEIVED 41aska Oil & Gas Con~. ComAj/~jI Anchora~ ~ PLATFORM' "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 centered 541.65 ft. North and 1596.41 ft. West of the SE Corner of Sec. 23, TSN, R13W, SM. CONDUCTOR WELL LEG 2 DISTANCE FROM SE CORNER NORTH WEST 1 C23-23 547.10 1599.00 2 'C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 CONDUCTOR LEG 3 9 10 11 12 13 14 15 16 LEG 4 CONDUCTOR 25 26 27 28 29 30 31 32 Centered 618 65 ft. North and 1549.76 ft. West of the SE Corner of Sec. 23, TSN, R13W, SM. DISTANCE FROM SE CORNER WELL NORTH WEST C22-23 623.65 1552.66 C24A-14 624.15 1548.36 C43-14 622.65 1544.76 C41-26 618.25 1543.86 C21-23 613.85 1546.26 C21-26 612 . 65 1550.46 C24A-23 614.85 1554.26 C13-23 619. ].5 1555.66 Centered 582.42 ft. North and 1489.90 ft. West of the SE Corner of Sec. 23, TSN, R13W, SM. Centered 505.41 ft. North and 1536.56 of the SE Corner of Sec. 23, TSN, R13W, WELL DISTANCE FROM SE CORNER NORTH WEST C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 DISTANCE FROM ~CENTER OF LEG N/S E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -0.40 5.90 -4.80 3.50 -6.00 -O.70 -3.80 -4.50 0.50 -5.90 ft. West SM. DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 '[CC'"' BLUFF r,~ 41J. ij4 LO~.~T ION COOK ' · .- October 19, 1989 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF WELL COMPLETION OR RECOMPLETION REPORT AND LOG FOR WELL C21-26 Enclosed, in duplicate, is the Well Completion or Recompletion Report and Log for Well C21-26. If you have any questions, please call Ms. Susan Brown-Maunder at (907) 276-2545. Very truly yours, W. F. Simpson Manager Regulatory Affairs WFS/SBBM/raf Enclosures SBBK/aogcc. 101989 RECEIVED OCT 2 0 lgSg Alaska Oil & Gas Cons. Commission Anchorage , - ~ STATE OF ALASKA · ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [-~ 2. Name of Operator 7. Permit Number Shell Western E&P Inc. 89-04 3. Address 601 West Fifth Avenue, Suite 810 8. APl Number Anchorage.- Alaska 99501 50- 4. Location of well at surface 9. Unit or Lease Name Platform "C", Leg 2, Conductor 14 Hiddle Ground Shoal .... At Top Producing Interval 10. Well Number 930' FNL and 1395' FWL Sec 26, T8N, R13W C21-26 At Total Depth 11. Field and Pool 930' FNL and 1860' FWL Sec 26, T8N, R13W 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 105' KBI ADL 18756 "G" Pool 121 Date Spudded4/5/89 13. Date T.D. Reacheds/8/89 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns7/16/89 75' feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11,485' 10,133' 11,403' 10,089' YES K-I NO []I 11403 feet MD N/A 22. Type Electric or Other Logs Run DITE, SP, GR, ANS, LOT, FMS, SHOT, EFT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# (-55, BTC 1305' 17-1/2" 350sx"G"+10% Gel, 200sx"G ,120 sx"G" TOP JOB 9-5/8" 43.5-47# ~-80/L-80 1205' 9314' 12-1/4" 370sx"G"+1.5% Gel ,200Sx"G 7" 29# .-80 8695 ' 9554 ' 8-1/2" 1100s x"G"+Addi ti yes 32# .-80 9554' 9592' 8-1/2" 35# .-80 9592 11485' 8-1/2" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) SEE ATTACHED DETAIL SHEET 2-7/8 6.5#N-80 10.329' 10,365' Mod. , 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11145' - 11267' :racture treated w/15600 Z0/40 Carbo-Lite 10964' - 11109' -'racture treated with 93,000 lbs 20/40 ISP 27. PRODUCTION TEST .... , Date First Production I Method of Operation (Flowing. gas lift, etc.) 7/1/89I Gas Lift Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZEIGAS-OIL RATIO 7/7/89 12 TEST PERIOD I~ 68.5 9.5 18.5 128I 139 Flow Tubing Casing Pressure CALCUI~ATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 100 725 24-HOUR RAT~: I~ 137 19 37 35 28. CdR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A _ ._ R[CEIVED OCT 2 0 1999 Naska O/j & Gas Cons~ Comm/ssion Anchorage Form 10-407 Rev. 7-1-80 SBBK/wcr.082989/1 CONTINUED ON REVERSE SIDE Submit in duplica~ 29. '30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. N/A RECE'I'VED OCT 2 (> Alaska OiJ & ~as Cons. 31. LIST OF ATTACHMENTS ~ncn0rage Dei3y Report of 0per'ations~ Completion Equipment Detail Sheet: 32. I h,?reby certify that the foregoing is true and correct to the best of my knowledge igned ~ _ _ ,,~.- _ ~ Title Div. Op Manager Date 10/19/89 · ~,~ \t,I ! \V INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on -all types of lands and leases in Alaska. Item 1- Classification. of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ..... SBBK/wer.082989/2 2 3 4 5 7 8 9 10 11 12 13 14 15 16 17 18 19 2O COMPLETION EQUIPMENT DETAIL SHEET MGS C21-26 8/17/89 NO. ITEM TBG SLM TVD. MD. PSI OR 1. OTIS SAFETY VALVE 2. GAS LIFT MANDREL #1 3. GAS LIFT MANDREL #2 4. GAS LIFT MANDREL #3 5. GAS LIFT MANDREL #4 6. GAS LIFT MANDREL #5 7. GAS LIFT MANDREL #6 8. GAS LIFT MANDREL #7 9. GAS LIFT MANDREL #8 10. GAS LIFT MANDREL #9 11. GAS LIFT MANDREL #10 12. GAS LIFT MANDREL #11 13. GAS LIFT MANDREL #12 14. OTIS "XD" SLIDING SLEEVE 15. BAKER "G" LOCATOR W/ SEAL UNIT 16. BAKER "DB" PACKER ID = 3.25" W/ 15' SBE & X-OVER 17. 14' 2-7/8" EUE PUP 18. 2-7/8" OTIS "XN" NIPPLE 19. 8' 2-7/8" EUE PUP 20. OTIS RE-ENTRY GUIDE/SHEAR OUT SUB 338 338 1692 1703 960 12 3171 3245 955 12 4390 4694 1020 16 5295 5762 1015 16 6072 6711 1010 16 6487 7252 1005 16 6984 7861 1000 16 7476 8378 995 16 7984 8895 990 16 8469 9380 980 16 8972 9894 975 16 9330 10283 820 16 9371 10329 9401 10363 9403 10365(10355'DIL) 9427 10394 9436 10404(10394'DIL) CASING 13 3/8", 54.5#, K-55, BTC @ 1305' w/550 sx 9 5/8", 43.5-47#, N-80/L-80 @ 9314' 7" 29#, L-80, 8695-9554' 32#, L-80, 9554-9592' ....... 35#, L-80,.9592,11485' PBTD = 11403'(LANDING COLLAR), TOPS OF FLAGJOINTS @ 10406, 10503, 10950'(DP) TD = 11485' TUBI_NG' 2-7/8", 6.5#, N-80, MOD PERFORATED ZONE · INTERVAL (DIL DEPTHS) HC-HD HE-HF HI-HK HK-HN HN-HR HR-HZ 10444-10474 ATLAS 2-1/8" SILVERJET 4JSPF 10570-10638 ATLAS 2-1/8" SILVERJET 4JSPF 10709-10740 ATLAS 2-1/8" SILVERJET 4JSPF 10745-10918 ATLAS 4" CASING GUN 4JSPF 10964-11109 50 HOLES(CASING GUN) 11145-11267 50 HOLES(CASING GUN) RECEIVED OCT 2 0 Alaska Oil & flas Cons. Commissior) DAILY REPORT OF OPERATIONS C21-26 DATE 04/03/89 04/04/89 04/05/89 04/06/89 04/07/89 RECEIVED OCT 2 0 ]989 AJaska Oil .& Ga~ Cons, Commisslo~ Anchorage 04/08/89 DESCRIPTION C21-26- Clean Pits. Mix and condition spud mud. C21-26: Move rig on conductor #14, Leg 2. Rig up and prepare to spud; secure handrails and stairways. Set 20" drilling riser, nipple up 20" hydril, hook up mud and flow line. Flange up 10-3/4" diverter system. Prepare rig for spud. Function test 20" MSP 2000 hydril and 10" diverter system. Pick up bit #1, mud motor, Anadrill MWD & BHA. Service rig. Opera- tional test mud motor and MWD in hole. RIH, C/O conductor. Drill out fill and shoe from 286' to 375' with inlet water. Drill out shoe @ 2300 hrs, 04/04/89. Switch to gel spud mud. Orient tool face wi th single shot Gyro. Drill wi th mud motor and single shot Gyro. Drill with mud motor and single shot gyro survey 17.5" hole from 375' to 550'. Work on #1 mud pump. Finish repairs to #1 mud pump's shear relief valve. Drilling survey to 1145' with bit #1. Drilling survey to 1300' with bit #1. SLM out of hole, lay down mud motor. TIH with stabilized clean out assembly. Circulate and condition for casing. Ran Gyro @ 1284'. Rig down Gyro-Data and Dia-Log. POH with clean out assembly. Rig and ran 33 jts of 13.375" 54.5#, K-55 BT&C R-3 casing 1304.87' "On Hook". Baker plain guide shoe @ 1300' (KB) Baker Float Collar @ 1257'. Installed HOWCO cent's @ 10', 40' 80' 120' 200' ' , , , and 360 above shoe. Bottom 6 jts are Baker-locked. Tested annular/Diverter system on shoe jt. OK. Checked float collar. OK. Fill each jt as ran. Rig up HOWCO cmt headlines. Circulate and condition for cmt. Test lines to 3000#. OK. Drop bottom plug. Pumped 50 bbls of fresh water ahead of 350 SX of class "G" cmt + 10% gel + 2% CaC12 + .25% CFR-3 + 11.5 gallons water/sx to yield 2.08 cu. ft/sx. Tailed with 200 sx class "G" + 1% CaC12 + .4% CFR-3. Dropped top plug. Displaced with 195 bbls mud with rig pumps @ 8-10 bpm rate. Bump plug. Float held. CIP @ 0400 hrs 04/07/89. WOC. Tear out HOWCO equipment. Nippling down diverter lines. WOC. Finish nipple down diverter system, 20" annular preventer/riser. Did a 120 sx "G" cmt top job, cmt to surface from 70' below well room floor. Made final cut/dress top of 13.375" casing weld on "WF" head. Test to 800 psi for 15 minutes. OK. SBBK/082489 - 1 - DATE 04/09/89 04/10/89 04/11/89 04/12/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION Nipple up BOPE. Begin testing BOPE. NOTE: Mr. Mike Minder of AOGCC declined to witness testing of BOPE. Was notified 1005 hrs on 04/07/89. NOTE: there are 4 gussetts welded between the casing and cond just below the well head room floor to center up and stabilize the casing. They are welded only to the conductor, not to the casing. Finish testing BOPE. Installed wear ring. Make up BHA, TIH. Tagged up @ 1255'. Circulate out thick mud. Pressure test casing to 1500 psi for 30 minutes. OK. Drill top/bottom plugs, float collar, 43' of hard cmt and shoe. Made 4' of hole below shoe. Did leak off test with 9.2 ppg mud in hole. Leak off occurred @ 220 psi. EMW of 12.5 ppg. Drilling survey to 1855' with bit #2. AC turbine went down. Production had to have AC/DC drilling engine. Then #5 drilling engine went down with blown air hose. Got #5 going in 1/2 hrs time. Made 3' of hole and #1 mud pump discharge header flange washed out an API ring. Pulled to shoe, repaired mud line, TIH. Drilling survey with Anadrill to 2375'. Drilling/Survey with Anadrill to 2871' with bit #2. Check for flow, none. POH, picked up 11.70' lead collar to increase building belly to 57.06' blade to blade. Changed out near bit stab sleeve TIH to shoe @ 1300'. Cut drilling line 100'. Finished turning in hole to 2871'. No fill. Drilling/survey with Anadrill to 3114' with bit #3. Pump pressure began slow drop. Surface equipment checked out OK. POH 13 stds and double WET. Found a dime size hole in the slip area of DP. Laid down bad jt of DP. TIH. Drlg/survey with Anadrill from 3114' to 3355' with Bit #3. Drilling/survey with Anadrill to 3411' with bit #3. Check for flow, none. POH. Laid down the 2 11' lead collars, picked up a 8.23' lead collar above bit. Drilling/survey with Anadrill to 4033' with bit #3RR. Check for flow, none. POH. Layed down 8.23' lead collar and 30' Monel DC picked up a 30' Monel DC with clamp-on stab installed. Blade to blade measurement is 9.0' between NB stab and the clamp-on stab. TIH. Drilling/Survey with Anadrill to 4175' with bit #4. Drilling survey with Anadrill to 4620' with bit #4. Check for fl ow, none. POH. Layed down Monel collar with clamp-on on it. Picked up Monel collar. SBBK/082489 - 2 - DATE 04/13/89 04/14/89 04/15/89 04/16/89 04/17/89 04/18/89 04/19/89 04/20/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION changed NB sleeve and sleeve just above MWD. TIH with bit #5. Drilling/Survey with Anadrill with bit #5. Drilling survey with Anadrill to 4995' with bit #5. Repair main air line to rig. (Hole in Hose.) Drilling and survey with Anadrill to 5484' with bit #5. Check for flow, none. POH for mud motor. Making up BHA. Make up bit #4RR assembly with mud motor and 1-1/2 d bent sub. Test Anadrill MWD and baker mud motor in hole. TIH. Orient mud motor. Drill and MWD survey 12.25" hole with mud motor to 5725'. Check for fl ow, pump pill, POH. Layed down BHA, L/D motor assembly, pick up drill assembly. RIH with bit #6 to 1000' Slip and cut 100' drill line RIH to 5477'. Ream run . motor interval to 5725'. Drill 12.25" hole and survey to 6176'. Drill and survey 12.25" hole to 6399'. Pull out of hole 10 stand short trip. Drill and survey 12.25" hole to 6706'. Drill and survey 12 25" hole to 6770' MWD survey, check flow, pump piil. POH, (test choke manifold and kelly while tripping @ 250/3000 psi). Retrieve wear bushing, install test plug, test annular preventer @ 250/2500 psi, test all rams, lines, valves @ 250/3000 psi. Retrieve test plug, install wear bushing. Make up bit #7, change lead collar, RIH to 6770'. Drill and survey 12.25" hole to 7037'. Drill and survey 12.25" hole to 7279'. Short trip 5 stands, RIH to 7279'. Drill and survey 12.25" hole to 7465'. Drill and survey 12.25" hole to 7478' MWD survey, check for flow, pump pill. POH with ~it #7. Lay down NB stab, L/D lead collar, change out jars, pick up XO stab, make up bit #8. RIH to 7478' (fill pipe @ 3772'). Drill and survey 12.25" hole to 7810'. Drill and survey 12.25" hole to 7902' Survey, check for flow, pump pill. POH with ~it #8, pick up NB stab, pick up lead collar, make up bit #9. RIH with bit #9 to casing shoe @ 1300'. Cut and slip 100' drill line, fill pipe. RIH to 7850'. Wash and SBBK/082489 - 3 - DATE 04/21/89 04/22/89 04/23/89 04/24/89 04/25/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION ream to 7902'. Drill and survey 12.25" hole to 8282'. Drill and survey to 8361' MWD survey, check flow, pump pill. POH with bit ~9, lay down Monel collar, lay down NB stab, change 2 stab sleeves, make up bit #10 (tight spot @ 8087'). RIH with bit #10 to 8281'. (fill pipe @ 4600'). Wash and ream to 8361'. Drill and survey 12.25" hole to 8548'. Drill and survey 12 25" hole to 8886'. MWD survey, check flow, pump piil. POH with bit #10, Lay down Lead Collar, Make up Monel drill collar, Make up NB stab, Make up bit #11, RIH. RIH to 8830'. Wash and ream to 8886'. Drill and survey 12.25" hole to 9092'. (Lost 200 psi pump psi.) Check for surface equipment washout, MWD survey. POH looking for washout; washout between lower MWD XO sub and lead collar. Test choke manifold @ 250/3000 psi while tripping. Retrieve wear ring, install BOPE test plug, Test BOPE: Test all rams lines and valves @ 250/3000 psi. Test annular preventer @ 250/2500 psi. Test kelly and associated valves and hoses @ 250/3000 psi. Test all safety valves and floor valves @ 250/3000 psi. Retrieve test plug, install wear ring. Make up bit #12, change out lead collar, change out NB stab sleeve, pick up MWD crossover, RIH to casing shoe. Cut and slip 100' drill line. RIH to 8675', hit tight spot, stuck pipe. Pick up kelly. Work pipe free, wash and ream tight hole to 8818'. RIH to 9062'. Wash down to 9092' Drill and survey 12.25" hole to 9343, MWD failed @ 9245'. POH 10 stands to 8413', RIH to 9343'. Circulate and condition mud for wireline logs. Check for flow, pump pill, POH for wireline. POH, SLM. Rig up Schlumberger wireline, RIH with DIL/GR, log to casing shoe, POH, rig down Schlumberger. Lay down Monel BHA, pick up steel drillcollars, make up bit #12RR. RIH with bit #RR12, fill pipe @ 4600', RIH to 9299'. Clean out fill to 9314' Circulate and condition mud for casing job. ~heck for flow, pump pill, POH with bit #12RR, lay down BHA. Change blind rams to 9-5/8" casing rams. Retrieve wear bushing, install test plug, test bonnet seal on blind ram gate @ 250/2500 psi. Retrieve test plug. Rig up weatherford casing handling tools, rig up to run 9-5/8" casing. SBBK/082489 - 4 - DATE 04/26/89 04/27/89 04/28/89 04/29/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION Pick up and RIH with various weights and grades of 9.625" casing to 8645', hit bridge, attempt to work thru, could not. Make up circ swedge, circulate and work thru bridge. Pick up and RIH with casing to 9299', hit bridge 15' off bottom, make up circ swedge, circulate and condition for cmt job, pre-treat for cmt contamination, attempt to wash casing to bottom, could not clean mud tanks, mix cmt water. Rig up HOWCO cmt lines. Pump 5 bbls fresh water ahead, test cmt lines @ 3000 psi, pump 95 bbls fresh water ahead. Mix and pump 370 sx "G" + 1.5% PHG + .2% CFR-3 + .15% HR7 mixed @ 14.2 ppg, followed by 200 sx "G" + .2% CFR-3 + .15% HR-7, mixed @ 15.8 ppg. Drop top plug, pump 5 bbls fresh water behind. Displace with 670 bbls 9.5 ppg mud, bump plug with 1000 psi, check floats, good returns during cmt job. Cmt in place @ 0215 hrs 04/26/89. Rig down cmt lines, rig down flow lines. Pick up BOP stack, hang 280,000# wt on "AW" slips. Cut and lay down 9-5/8" landing joint laid down cmt head, remove 28" drilling spool. Install DSA/AP spool. Nipple up. Test AW slips to 3000#. Failed. Lift AP spool and tighten slip cap screw. Test AW slips, NX bushing and API ring on AP spool @ 15 minutes. Test good. Lower drilling riser and BOP stack. Nipple up and change 9-5/8" rams to blinds. Test BOP: install test plug. Test all lines, rams and valves @ 250/5000# test annular preventer @ 250/3500#. Test kelly assembly, hoses and valves @ 250/5000#. All safety, floor and dart valves @ 250/5000#. Accumulator time test good. Run and set wear ring. Pick up bit #13 and BHA. Test MWD. RIH to 5200'. Fill pipe. Slip and cut 100' of drilling line. TIH and tag top cmt plug @ 9231'. Casing shoe calculated @ 9314'. C/O cmt and drill top/bottom plugs and float collar to 9248'. Test 9-5/8" casing @ 3000# for 30 minutes. Test good. Drill cmt and casing shoe to 9314' @ 0030 hrs 04/27/89. Drill and MWD survey 8.5" hole to 9350. Circulate and condition mud. Perform leak off test @ 9-5/8" shoe. 16.9# equivalent mud weight. Drill and MWD survey 8.5" hole. Mike Minder of AOGCC waived the witnessing of the BOP test. Drill and MWD survey 8.5" hole to 9615'. Drill and MWD survey 8.5" hole to 9858'. CBU, check for flow, pump pill. POH. Lay down 2 ea LC, MWD. Pick up bit #14, Iea MC & BHA. TIH with bit #14 assembly. Fill pipe @ 3000', 6000' and 9300'. SBBK/082489 - 5 - DATE 04/30/89 05/01/89 05/02/89 OCT 2 o 1989 A~aska OiJ & Gas Cons. Commission Anchorage 05/03/89 05/04/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION Drill and SS survey 8.5" hole to 9858' Encounter tight conditions at several coal seam iocations. Drop single shot survey. Drop survey, check for flow. POH to casing shoe. RIH with slickline and retrieve single shot survey. TIH to 9858' Drill with bit #14 to 10139'. Work loose from tight spots @ 9977' and 10025'. Check for flow, drop SS survey. POH to casing shoe. Work tight spot @ 9898'. RIH with slickline and retrieve survey, check for flow, pump pill, POH. Pick up bit #15. RIH to 4400' and fill pipe. TIH. TIH with bit #15 assembly. Stop and fill pipe @ 8000' and 10081'. Wash and ream 58' to bottom, to 10139'. Drill 8 5" hole to 10286'. Work tight coals as required. Check for flow, drop SS survey. Check for flow, POH to casing shoe. RIH with slickline to retrieve survey. Retrieve survey. Both shots bad. TIH to 10286' Drill 8.5" hole to 10439'. Check for flow, drop ~S survey. POH to 9-5/8" casing shoe to retrieve single shot survey and short trip. RIH with slickline to retrieve survey. Survey equipment failed. RIH to 10439' and circulate. Repair single shot instrument. RIH with survey barrel on slickline and survey. POH with survey. Survey good. Check for flow. Pump pill and POH. Work tight spot @ 9568'. Lay down EXT SUB, pick up Ijt HWDP and bit #15 BHA assembly. TIH with bit #16 assembly to shoe. Fill pipe @ 4600 ' and 8850'. Slip and cut drilling line. Change out switch for #28 mud pump assignment in DC panel. TIH to 10403'. Wash & ream tight hole to 10439'. Drill 8.5" hole with angle building assembly. RIH with SS survey on slickline. Drill 8.5" hole with bit #16 to 10546'. R~H with SS survey on slickline. Drill to 10607 . Check for flow, drop survey. POH for short trip to shoe and recover survey. Very tight @ 9548' TIH. Set down on bridge @ 9578'. Pick up keily, drill thru bridge. Wash and ream to 10607'. 27' of fill. Drill with bit #16 to 10676'. Drill with bit #16 assembly to 10686'. Check for flow. Drop SS survey. POH to 9-5/8" shoe. SLM. Retrieve SS survey. POH SLM, no correction. LD/BHA: Change out I jt HWDP (above NB stab). Pick up bit #17. Service rig. Test BOPE: Test all SBBK/082489 - 6 - DATE O5/O5/89 05/06/89 05/07/89 o5/o8/89 05/09/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION rams, valves, choke and kill line components to 250# and 5000#. Test annular preventer @ 250/3500#. Time test accumulator. OK. Change out jars. RIH. Tag bridge @ 9545', 9517', 10158', 10183', 10556', 10616' Pick up kelly @ each bridge, wash & ream as required. Drill 8.5" hole with bit #17 assembly to 10725'. Drill 8.5" hole with bit #17 assembly to 10851'. Drop and pump down single shot survey. POH to 9-5/8" casing shoe. Tight @ 10707'. Circulate while RIH with slickline and retrieve SS survey. No survey. TIH and tag bridge @ 9842'. Wash ~ ream to 9862'. TIH to 10851'. No fill. Drill 8.5 hole with bit #17 assembly to 10965' Drill 8.5" hole with bit #17 assembly to 11020'. Check for flow, drop SS survey, pump pill. POH to 9-5/8" casing shoe. Tight @ 10707' RIH with slickline and retrieve SS survey. ~OH. Make up bit #18 BHA. RIH to 9745' and tag bridge. Pick up kelly and ream to 9760' S/B kelly. RIH. Tight @ 10707' No fill on bottom @ 11020'. Drill 8.5" hole with bit #18 assembly to 11130'. Drill 8.5" hole with bit #18 assembly to 11187'. Check for flow, POH for short trip to 9-5/8" casing shoe. Tight spots @ 10953', 10920' and 10860'. RIH to bottom. No fill observed. Drill 8.5" hole to 11278' Drop SS survey. Check for flow. Pump pill, ~OH. Pick up bit #19. TIH. Fill pipe @ 4600' and 9200'. Slip and cut lO0'of drill!ng line. TIH. Pick up kelly and ream bridge @ 10044 . TIH . Wash and ream hole to 10163'. S/B kelly. TIH to 11278'. Found 4' of fill on bottom. Drill 8.5" hole with bit #19 assembly to 11485'. TD @ 0300 hrs 05/08/89. POH for short trip to shoe. Very tight with 4 stands coming off bottom. Short trip to 9-5/8" casing shoe. TIH to 11485'. Circulate and condition hole for logs. Check for flow, drop survey, pump pill. POH for logging. Tight @ 11154' - 11000'. Recover survey. Strap pipe coming out. No correction. Rig up Schlumberger. Run DITE log. Tagged bottom @ 11475'. Run LDT log. Could not get past 11000'. Log up to shoe, rig down Schlumberger. Rig up Dia-Log and run casing caliper log from 9260' to surface. RIH for hole clean out. SBBK/082489 - 7 - DATE 05/10/89 05/11/89 5/12/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION TIH with bit #19RR, to 11,485'. No tight spots or bridges. Circulate and condition for logs. Check for flow, pump pill. POH to log. Rig up Schlumberger. Run LDT/GR/AMS log. Run SHDT/AMS log. Rig down Schlumberger. Lay down non-mag components of BHA. Pick up steel BHA. TIH slow due to thick mud. Fill pipe @ 4500' and 9000'. Work on mud pumps. TIH to condition hole for RFT log. Fill pipe @ 9200', TIH to 11485'. Circulate and condition mud. Check for flow, pump pill, POH for logging. Rig up Schlumberger. Run RFT/GR/AMS log. POH WL. RD same. Test BOPE: Test all rams, valves, choke and kill line components to 250/5000#. Test annular preventer to 250/3500#. Time/function test accumulator. Test kelly and all floor valves to 250/5000#. All tested OK. RIH with bit #19RR. Fill pipe @ 4500' and 9290'. Slip and cut 100' drilling line. TIH to 11400'. Hit bridge. Pick up kelly, ream /wash bridge. TIH to 11485'. Circulate and condition mud for running 7" liner. Check for flow. Pump pill, POH to run liner. Drift drill pipe on trip. Hole appears to be in good shape coming off bottom. No tight spots. POH, drift drill pipe. Pick up and run 72 its various weights and grades 7" liner. Make up brown "shorty" liner hanger with tie back receptacle and drill pipe setting tool, RIH with liner on drill pipe to 11485' Break circulation, circulate and condition mud ~or cmt job, reciprocate liner while circulating and conditioning (up weight = 365M, down weight = 150M), clean mud tanks, mix cmt mix water. Drop ball to set liner hanger, circulate same down, pressure up to 2400 psi. Set liner hanger @ 8695', shear out ball with 3000 psi, rotate pipe to disengage from liner, pick up to verify loss of liner weight, set down 20M on running tool for cmt job. Rig up HOWCO cmt lines, pump 50 bbls fresh water + 1% NaC1 ahead, test lines @ 5000 psi, mix and pump 1100 sx "G" cmt + .2% CFR-3 + .5% HALAD-344, + .1% LWL + 1% NaC1, mixed @ 15.8 ppg, followed by 10 bbls fresh water + 1% NaC1. Displace with 241 bbls 11.8 ppg mud. Bump plug with 1800 psi, cmt in place @ 0245 hrs 5/12/89. Rig down HOWCO cmt lines, L/D baker cmt manifold and head, POH 20 stands to 6835' Reverse circulate 2 drillpipe volumes. Hoid 300 psi on annulus, wait on cmt. SBBK/082489 - 8 - DATE 05/13/89 05/14/89 05/15/89 05/16/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION Hold 300 psi on casing, wait on cmt. POH, lay down Baker drill pipe setting tool. Lay down 3 Monel drill collars, lay down 4 each stabilizers, lay down brown cmt head and manifold. RIH with bit #19RR, 9-5/8" casing scraper, tag liner top @ 8682' (no cmt), POH I stand. Test liner lap to 3500 psi for 30 minutes. (Test OK.) Circulate bottoms up (no cmt). POH with bit and scraper. Make up HOWCO RTTS, and inflow test assembly. RIH with test assembly to 4364', fill pipe with 11.8 ppg mud, RIH to 8580'. Set RTTS @ 8580', open hydra spring bypass, test liner lap with estimated 2000 psi inflow test. Shut in test tool for pressure build up from inflow test. Equalize well and reverse circulate. POH, retrieve HOWCO recorder charts. Lay down 51 joints 5" drill pipe, lay down 38 joints HWDP, lay down jars. Evaluate pressure recorder charts. (Slight buildup.) Rig up to pick up 3.5" drill pipe. Make up 6 each 4-3/4" drill collars, 7" casing scraper, bit #20, RIH pick up 120 joints 3.5" drill pipe. RIH with 5" drill pipe to 8604'. Slip and cut 100' drill line. RIH to 11285', tag cmt. Clean out cmt to landing collar @ 11403'. Circulate bottoms up. Pump pill, POH. Nipple down flow line and bell nipple, nipple up 13-5/8" x 7" casing wireline lubricator adapter spool. Rig up Atlas wireline lubricator, test same to 2500 psi. RIH with Atlas CBL/CCL/GR, tool stopped @ 10950', attempt to work past could not, log with 1500 psi on casing to 8850'. Bleed off pressure, POH with wireline, rig down Atlas wireline. Rig up Dia-Log, make up Gyro-Data tools. RIH with Gyro-Data survey, survey from 11300' to surface, rig down Dia-Log. N/D lubricator and adapter, nipple up drill nipple and flow line. Make up bit #2ORR, 7" scraper, RIH to 11403' for clean out trip. Circulate high Visc sweep. Close pipe rams, pressure up casing @ 4000 psi for thirty minutes. Test good. Pump pill, POH. POH with bit #20 and casing scraper. Flange up to annular preventer with Atlas wireline lubricator. Rig up Atlas wireline, test lubricator @ 2500 psi. RIH with cable to 11000', could not get below 11000', POH, L/D gamma ray. RIH to 11370', pressure up casing to 1500 psi, run cable, POH. Release pressure, POH with logging tools, rig down Atlas, rig down flange and lubricator. Nipple up drill SBBK/082489 - 9 - DATE 05/17/89 05/18/89 05/19/89 05/20/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION nipple. RIH with bit and scraper. Rig up to lay down drillpipe. Lay down 276 its 5" drill pipe. Lay down 120 jts 3.5" drill pipe. Lay down drill collars and BHA. Retrieve wear bushing, install test plug, test BOPE: Test all rams @ 250/5000 psi, test choke manifold @ 250/5000 psi, test standpipe rotary hose @ 250/5000 psi, test kelly and valves @ 250/5000 psi, test annular preventer @ 250/3500 psi. Retrieve test plug, install wear bushing. Install wear bushing. Make up 5-7/8" bit, casing scraper, RIH pick up 3.5" fracture string to 11380', tag fill. Clean mud pits, circulate thru choke manifold, all lines, clean all suction lines. Fill mud pits with filtered injection water. Reverse circulate casing volume, open pipe rams, circulate 200 bbls, displace 11.6 ppg mud with filtered injection water. Mix nut plug pill. Reverse circulate, mix nut plug/polymer pill. Reverse 250 bbls filtered injection water, pump 80 bbls nut plug pill mixed with 1.5#/bbl XC Polymer and 50#/bbl coarse nut plug, followed by injection water, reverse circulate until turbidity meter indicated 35 ppm TSS. Reverse circulate, mix CaCl2, weight up system to 10.6 ppg, filter brine with 3 micron filters. Reverse circulate, mix CaC12, weight system up to 10.6 ppg.' POH with 3-1/2" fracture string, bit and scraper. Nipple down drilling nipple, flowline, nipple up Atlas wireline. Adapter flange and lubricator, rig up Atlas wireline, test lubricator. Rig up Atlas wireline. Test lubricator @ 2000 psi, RIH with GR/CCL tool, tool failed, POH, rehead tool. RIH with GR/CCL, log with GR/CCL, POH. Test lubricator @ 2000 psi, perforate as follow with 4" Atlas Jumbo Jet Casing Guns with 1 shot /1-1/2': 11145' - 11154' 11168'- 11202' 11204' - 11222' 11254' - 11267' Rig down Atlas wireline, N/D lubricator. Install drilling nipple and flow line. Make up HOWCO RTTS packer and tailpipe assembly, RIH with 3-1/2" fracture string to 9620', SLM and drift fracture string @ 2.81". Set RTTS @ 9620', fill annulus with completion fluid, space out for tool joint (3.5" drill pipe pup joint) below pipe rams, close rams, test tubing with 3500 psi on annulus, no pressure on SBBK/082489 - 10 - DATE 05/21/89 05/22/89 05/23/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION tubing. OK. Rig up and prepare for fracture treatment. Pumped 135 bbls nut plug pill to production, notify Operations Foreman and Onshore Operator to catch sample. Rig up Dowell treatment lines to rig floor, prepare for fracture treatment. Held safety briefing for all personnel on platform, discuss fracture treatment procedures and safety considerations. Detail emergency procedures. Start turbines, test lines @ 11500 psi, pressure up annulus @ 3500 psi. Acid ballout HR-HZ: Pump 5 bbl linear gel, 5 bbls 15% HC1, 38 bbls 15% HC1 with 75 balls, 5 bbls 15% HC1 without balls, flush with 142 bbls linear gel @ 5 bpm. Initial pressure 5400 psi, increase to 7740 psi after balls reached perfs, declined to 6600 psi. No ball action was observed. Surge three times to drop balls. Data fracture HR-HZ: Pump 140 bbls crosslink gel with adomite @ 20 bpm @ 8820 psi. Shut in for 10 minutes, ISIP-6907 psi. Pumped 135 bbls linear gel with adomite @ 20 bpm, final pressure 8550 psi. ISIP-6450 psi. Mix gel and evaluate data fracture, design fracture treatment. Start turbines, test lines @ 11000 psi. Fracture Treatment HR-HZ: Est. 20M # in formation; 43M # left in tubing. Shut well in for closure pressure, monitor pressure. Back flow well, bleed down tubing pressure, catch fluid in mud tanks, catch proppant in barrels at shale shaker. 200 bbls fracture fluid and 28 drums of proppant have been caught. Back flow well, bleed off tubing pressure, Shut well in for pressure buildup (1150 psi). Back flow well, bleed off tubing pressure. Shut well in for pressure buildup (1000 psi). Back flow well, bleed off tubing pressure. Shut well in for pressure buildup (830 psi). Back fl ow well. Back flow well, catch produced fluids in pits. Shut well in, pressure build up to 860 psi. Back flow well, catch produced fluids in pits. Shut in well, monitor pressure (1090 psi), clean proppant out of mud pits, filter fluid. Pump 353 bbls produced fluid to production. (Notify Operations Foreman and Onshore Operator time to catch sample.) Open Halliburton circulation valve, reverse circulate, kill well with 10.6 ppg brine. Build pit volume, monitor well, pump 104 bbls produced fluid to production. (Notify Operations Foreman and Onshore Operator time to catch sample.) Unseat RTTS, reverse circulate, check well for flow, well still i SBBK/082489 - 11 - DATE 05/24/89 05/25/89 05/26/89 05/27/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION flowing. Weight up brine to 10.7 ppg, circulate to kill well. Reverse circulate with 10.8 ppg brine. Check for fl ow. RIH, tag proppant @ 10430' Reverse circulate and condition Brine, chick for flow. POH, lay down RTTS, circulate valve and tail pipe assembly (test choke manifold @ 250/5000 psi while tripping). Retrieve wear bushing, install test plug, test BOPE: Test annular preventer La 250/3500 psi, test all lines @ 250/5000 psi, test safety valves upper and lower kelly valves @ 250/5000 psi. Test rotary hose and standpipe @ 250/5000 psi, retrieve test plug, install wear bushing. RIH with 3-1/2" fracture string and mule shoe, tag proppant @ 10430'. Wash and reverse circulate fracture proppant to 10917'. Wash and reverse sand to 11403'. Reverse circulate hole clean, clean pits, build volume, filter brine with 3 micron filters. POH to 10887'. Rig up HOWCO cmt lines, test lines @ 3000 psi. Mix and pump 65 sx 20/40 mesh sand, displace with 20 bbls 10.7 ppg brine, rig down HOWCO cmt lines. Reciprocate tubing, wait on sand to settle. RIH to 11403', no sand. Pump down tubing 4 bbls brine, reciprocate tubing, tag sand @ 11325'. POH to 10817', pump down tubing with brine. Wash down to and reverse out sand @ 11200'. Reverse circulate a HI-VIS HEC 50 bbl pill around. POH with mule shoe. Make up and run HOWCO retrievable bridge plug. SLM in hole, no corr. Rig up Dresser-Atlas. Ran GR/CCL. Got RBP on depth: 12' difference between DIL and tubing measurement. Tubing is longer. POH W/D-A, rig them down. Set bottom of RBP @ 11141', 4' above perfs @ 11145' per DIL. Rig up HOWCO lines. Test lines/casing against packer to 3000 psi. OK. Pumped 15 gals of carbolite sand for a plug on top of RBP, let settle. Tagged sand @ 11125' (DIL)' POH, layed down RBP running tools. Removed flow nipple, installed lubricator. Test to 2000#. OK. Rig Atlas. 1st RUN: PERF 11104 - 11109, 2 shots & 11094 - 11101, 3 shots 2nd RUN: PERF 11070 - 11090, 8 shots. 3rd RUN: PERF 11050 - 11070, 8 shots. 4th RUN: PERF 11030 - 11050, 8 shots. 5th RUN: PERF 11010 - 11030, 8 shots. SBBK/082489 - 12 - DATE 05/28/89 RECEIVED OCT 2 o ]989 Alaska Oil & Gas Cons. Commission Anchorage DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION 6th RUN: PERF 11001 - 11010, 3 shots & 10927 - 10997, 4 shots. 7th RUN: PERF 10984 - 10987, I shot & 10964-10976, 5 shots. Rig down Atlas wireline. Remove lubricator, nipple up flow nipple. Making up HOWCO RTTS. TIH with RTTS, set @ 10468' with 45K down wt on RTTS. EOT @ 10480' Spaced out W/DP pups with tool jt just under the pipe rams, (15.80', RT) test tubing with 3500 psi. OK. Casing to 3500 psi. OK. Rig up Dowell lines/head to acidize and fracture well. Work on Dowell hyd motor on blender. Test lines to 11500 psi. Pumped 5 bpm, 5 bbl pad, 5 bbl of 15% HC1 acid then 38 bbls HC1 acid with 75 balls, 5 bbls acid followed by 115 bbls of linear gel for a total fluid of 168 bbls. THP increased to a maximum of 8280 psi and broke back to 6047 psi after which pressure rose back to 6480 due to some ball action. ISIP: 5950 psi. Job considered successful. Mix gel water, prepare for frac treatment. Re-test lines to 11600 psi. Main prop frac: Decided to skip data frac. Assumed leak-off coefficient of 0.006 (same as HR-HZ) pumped frac @ 20 bpm at pressures from 8500 psi to 9300 psi THP. Pumped total slurry volume of 1087 bbls including 60,000# of 20-40 ISP (intermediate strength proppant). Job screened out as an estimated 40,000# was pumped into the formation and 20,000# EST was left in the casing/tubing. (Amounts will be reverified during clean out overall went very good.) Actual amounts pumped are: 700 bbls pad, 75 bbls with I ppg 100 mesh sand, 24 bbls pad, 42 bbls with 2 ppg 20-40 ISP, 84 bbls with 4 ppg 20-40 ISP, 120 bbls with 6 ppg 20-40 ISP and 77 bbls with 9 ppg 20-40 ISP and 48 bbls flush. Screened out 57 bbls short on flush. Total dirty volume was 1170 bbls. Total clean volume was 1103 bbls. Monitor tubing psi until it fell off to 3800 psi. Began back flowing well. 05/29/89 Back flow well; began when tubing psi had dropped to 3600 psi. Initial rate was 40 bbls hr of flush fluid. Average rate over 24 hr period is 9.4 bbl/hr Rate is 1.8 bbl/hr with 76% fracture fluids/water, 225 bbls total recovered fluids. 05/30/89 Back flow well. Total recovered fluid; 337 bbls. Cutting 50% oil/water the last hour. Open bypass/unseat RTTS packer. Reverse circulate until had 10.7 ppg RET's. POH and l ayed down HOWCO tools. (Test choke manifold on trip.) Did weekly BOPE SBBK/082489 - 13 - DAILY REPORT OF OPERATIONS (continued) C21-26 DATE DESCRIPTION test. Trip in hole with 3.5" mule shoe on EOT. Tagged sand @ 10479'. Rigging up to reverse out sand down to HOWCO RBP set @ 11153' (TBG). 05/31/89 Reverse out 18.5 drums of fracture sand to top of RBP @ 11!41'. Circulate clean. (Replaced and tested 3 FL gate valve on choke manifold.) Check for flow, none. POH with mule shoe. Make up HOWCO RBP retrieving tool and tripping in hole. 06/01/89 Trip in hole with RBP retrieving tool; work thru tight spot @ 10983'. (TBG measurements) RIH to 11110', tight hole, unable to work past it. NOTE: Casing drift is 5-7/8", retrieving tool is 5-3/4" OD. Reverse circulate bottoms up, had only clean returns. Check for flow, none. POH with HOWCO RBP retrieving tool, lay down same. Make up tri-state oil tools tapered mill, stab, bumper sub and jars. Trip in hole to 10981'. Mill tight hole to 10991'. Went free to 11110'. Mill tight hole to 11116', present depth and still milling. 06/02/89 Mill to 11121'. Went free to 11138'; stopped 3' above RBP as we didn't want to tag RBP with mill. Check for flow, none. POH, lay down Mill/stab. TIH with RBP pulling tool. Wash down over RBP stinger, reverse circulate clean. Unset RBP, circulate and condition. Check for flow, none. POH, layed down RBP/pulling tool/BS and jars. Make up 3.5" mule shoe on EOT. Tripping in hole to reverse out sand. (Top of sand was left @ 11200'.) 06/03/89 Finish TIH with mule shoe, tagged sand @ 11200'. Reverse out sand to 11403'. Reverse circulate a 80 bbl HFC sweep. Hole is clean. Recovered 5 drums of sand from this 203' interval from 1st fracture. Check for flow, none. POH with mule shoe. Pulled wear ring, nipple down flow nipple, nipple up 7" lubricator. Test lubricator to 2000 psi. OK. Rig up Atlas wireline to perforate. 1st RUN: 10913-10918, 20 shots. 10894-10906, 48 shots. 2nd RUN: 10870-10892, 88 shots. All 4" casing guns are loaded 4 JSPF, super omnikone, 34 GM with 90 degree phasing. 06/04/89 Finish perfing with 4" casing guns, loaded 4JSPF, super omnikone, 34 GM with 90 degree phasing. Had one misfire run, #5 1st time tried a wire was bad. 3rd RUN: 10860 - 10870, 40 shots. 10842 - 10857, 60 shots. 4th RUN: 10819 - 10839, 80 shots. SBBK/082489 - 14 - DAILY REPORT OF OPERATIONS (continued) C21-26 DATE DESCRIPTION 5th RUN: Misfired. RERUN: 10807 - 10819, 48 shots. 10796 - 10803, 21 shots. 6th RUN: 10765 - 10791, 104 shots 7th RUN: 10745 - 10765, 80 shots. (All perf measurements are per DIL.) Made gage ring (5.782") and junk basket run to 10475'. OK. No Junk RHC. Run packer assembly on Atlas wireline. DIL packer setting depth is 10362' and wireline entry guide @ 10405' DIL. Rig down Atlas. Remove 7" lubricator, nipple up flow nipple. Change pipe rams to 2-7/8" and test to 250 low and 5000 psi high. OK. Rig and ran completion string. (324 jts of 2-7/8" 6/5# N-80 8RD AB MOD was used 10108'.) Tubing packer depth is 10341.58', wireline entry guide @ 10384.70', "XN" nipple @ 10374. Otis "XD" sliding sleeve @ 10306' a total of 12 GLM at: 10260', 9870', 9357', 8873', 8356', 7840', 7232', 6691', 5742', 4670', 3219', 1681' Otis SSSV @ 276'. Mr. Lonnie Smith of AOGCC gave verbal approval to set SSSV above 300' 3 pups are below the tubing hanger, topmost is ~' then a 4' and a 10'. All GLM's have a 4' pup above and below them. Landing tubing. 06/05/89 Land tubing on locator @ 10341'. Test tubing to 2000 psi. OK. Shear out plug in entry guide with 2900 psi. Up wt. was 8OK, down wt was 65K. 1OK setting on locator when landed on tubing hanger. Run in lock down screws on tree. Rig up slickline, pulled dummy out of SSSV @ 276'. Attempted to run a 2-1/8" used perf gun out FOT, could not get past 9974'. POH, ran a 2.30" gage cutter with more wt bars to the "XN" nipple @ 10374'. POH, made dummy gun run out EOT to 10450; OK. Rig down slickline. Installed BPV, nipple down BOPE, installed variable rams in BOP. Pulled riser. Lowered tree, flanged up and tested tree and valves to 5000 psi. OK. Removed BPV. Tear out rig to skid to C43-14. Released rig @ 1800 hrs 06/04/89. 06/22/89 Accept rig from C24A-14 @ 2400 hrs 06/22/89. Skid rig from C24A-14 to C21-26. Rig up APRS wireline. Test lubricator @ 2000 psi. RIH with pulling tool, 1-3/4" jars, latch on to fish @ 4120', attempt to pull and jar "PXN" plug out of tubing, pull max 3800#, prematurely pull out of rope socket, POH with 5/16" wireline. Monitor well for pressure build up. R/D 5/16" packoff. 06/23/89 sB~K/082489 Rig up slickline. Fish APRS tools off of PXN plug. Pulled gas lift valve from the mandrel @ 3219' Rig down slickline. Build 100 bbls of 10.7 ppg Ca~l2 - 15 - DATE 06/24/89 06/25/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION fluid. Reverse circulate 54 bbls to production separator. Rig up Schlumberger. Test lubricator to 2000#. OK. RIH with 2.5" JDC pulling tool. Jar on fish @ 4128'. Moved fish up hole 15'. Stuck again then jars failed. Sheared down to release tools. POH. Line had stranded @ 292' Close rams, remove lubricator, cut out stranded wires. Rig down Schlumberger. Rig up slickline. Test lubricator to 2000#. OK. Pulled gas lift valve @ 1690'. Ran/installed dummy valves @ 1690' and 3219'. Pump down casing, maintaining 150 to 250 psi on back side, had tubing open to SFP. Had 10.3 ppg returns. (Pumped 50 bbls.) Rig down slickline unit. Rig up Schlumberger. Test lubricator to 2000#. OK. RIH with 2.5" JDL pulling tool/fishing assembly. Packoff began leaking. POH repaired packoff, retest lubricator. OK. RIH with fishing tool assembly. Latch onto fish @ 4113'. Jar on fish. POH. Wireline had pulled out of rope socket. Rig down Schlumberger. Rig up slickline unit. Test lubricator to 2000#. OK. RIH with OS and grapple. Did not latch onto fish. POH. Add wt bars. Check grapple. RIH tight spot @ 3701'. Worked thru it. Did not latch onto fish. POH. RIH with impression block. Showed some wire strands in top of rope socket were hanging over side of rope socket. Still had tight place @ 3701' Rig up Arctic recoil tubing CO's CTU. Fill with 10.6 ppg CaCl2. Test to 5000#. OK. RIH with wash tool, 1.5 bbl/min pump rate with HOWCO pump, wash to top of fish @ 4101'. Circulate bottoms up. Recovered 2 pieces of metal 3/8" square and 1/32" thick. Unable to identify as anything we may have lost in hole. POH, set aside CTU head. Rig up slickline, test lubricator to 2000#. OK. Fish and retrieved the lost Schlumberger fishing string of tools. Rig down slickline. Rig up CTU. Test to 5000#. OK. RIH to spot I bbl acid on fish. Mr. Blair Wondzell of AOGCC gave verbal approval to spot acid. Finished RIH with CTU. Spot I bbl acid on fish. POH with CTU. Make up 2.5" JDC pulling tool on BS/jars, weld on to coiled tubing, RIH. Latch onto fish @ 4101'. Jar/work on fish Pulled max of 3OK. After 50 cycles on coiled tubin~ attempted to shear down/off of fish. Unable to spot I bbl of acid 11.0 ppg around tools to eat up the aluminum shear pin in an attempt to get off of fish. Moved acid down hole with rig pumps in 1/10 bbl increments while bumping down/jarring up on fish at 15 minute SBBK/082489 - 16 - DATE 06/26/89 06/27/89 06/28/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION time intervals to maximize acids effects at shear pin. String came free. Pulling out with coiled tubing. Finished pulling out of hole with coiled tubing unit, the JDC tool skirt had broken, leaving two pieces of junk in the hole. (Pieces are 3/4" square by 3/16" thick.) Rig up and pump down tubing. Pressured up to 4000#, psi fell to "0", pressured up again to 2500#, psi fell off again, kept pumping @ 400 psi/2.8 bbl min with good returns up the annulus. Recovered 25 bbls of oil from annulus; returns going to production system. When had 10.6 ppg returns switched to pits. Dropped a carbide pill to calculate where circulation was at in the tubing annulus. Indications were well circulated at the "XD" sliding sleeve @ 10306'. Rig up slickline, test lubricator to 2000#. OK. RIH with 1'75" impression block. Tagged up @ 10361'. This indicates the PXN plug is in the XN nipple @ 10375'. POH. Tear out slickline unit. Installed 2 way BPV in tree. Nipple down tree, nipple up BOPE. Testing BOPE in preparation to pull tubing. Finish testing BOPE. Stab in LDG JT, back out lock down studs, pull tubing hanger free. Remove BPV and tubing hanger. Retagged packer to confirm location. Reverse circulate and condition for trip. Had nut plug in returns at BTMS up. POH with completion string; found a JT of tubing @ 3696' SLM, that had not been beveled on the tube end inside of the collar. This is the 3701' WLM spot that all tools "HIT" going in the hole and it was all beat up. Also found I of the 3/4" pieces of JDC tool skirt inside of #5 mandrel. The screen in the "XD" sliding sleeve had nut plug and scale in it. Changed rams to 3.5" and test OK. Make up MILL/BHA. Picking up 3.5" drill pipe. Cut drilling line 100'. Finished picking up 3.5" drill pipe. Tagged packer @ 10338' SLM (DP). Mill on packer. Fell thru, pushed to 10361 without resistance. Circulate and condition. Had small amount of gas/oil from bottom. Check for flow, none. POH, lay down milling shoe. Make up spear, TIH to packer. Picking up 3.5" DP as chased packer to 11358' spear depth. Set 20K on packer. Pulled up. Had drag indicating packer was caught. Pulled up to 10880' to be above perfs. Circulate and condition for trip. SBBK/082489 - 17 - DAILY REPORT OF OPERATIONS (continued) C21-26 DATE DESCRIPTION 06/29/89 06/30/89 Circulate and condition for trip. Reduced mud wt to 10.4 ppg. Check for flow, none. POH. Lay down fish; Baker model "DB" packer, 15' of seal bore, XO, 15' of 2-7/8" pups, "XN" nipple, 8' tubing pup and reentry sub. Also, inside was the string of wireline tools: "PXN" plug, X line running tool. Spanger jars. Hyd jars, stem and rope socket. Have not gotten them apart as yet to account for any "junk" binding them. Rig up Atlas wireline/lubricator. Test to 250 psi. OK. Make gage r~ng and junk basket run to 10550' Ran Baker model DB" packer with 15' of seal borel XO, 15' of 2-7/8" pups, "XN" Nipple, 8' pup, and wireline reentry guide with shear sub pinned for 3000#. Set top @ 10355' per DIL. Reentry guide @ 10398' per DIL. (WLM) RIH with 3.5" DP and laying down same. Finish laying down 3.5" DP and 9 - 4-3/4" DC's. Change pipe rams to 2-7/8" and test to 250 low and 5000 psi high. OK. Make up 15' of Baker seal assembly below locator, run 2-7/8" completion string. All measurements are tubing SLM: Baker locator @ 10365', Otis "XD" sliding sleeve @ 10329'. Total of 12, Production Tools of Alaska, GLM with center locations at: 10290', 9901', 9387', 8902', 8385', 7868', 7259', 6718', 5770', 4701', 3252', 1710', Otis SSSV @ 3356'. Spaced out with 6', 4', 4', and topmost is a 8' pup. "AP" spool to rotary table is 35.10', with locator on packer, test tubing to 1500 psi. OK. Pull up 30'. Rigged up to circulate down tubing then out the annulus of C21-26 into the tubing of C43-14 and out of the annulus to the production header. This will put 8.5 ppg FIW into C21-26 while putting the 10.4 ppg completion fluid into C43-14 in preparation of.pulling tubing on C43-14 and gas lifting C21-26. (Wireline OP, opened "XO" sliding sleeve in C43-14 yesterday.) Circulate and condition as stated above. NOTE: The tubing SLM is 10' deeper than the DIL/WLM measurements. IF: the packer is 10355; per DIL but 10365; per tubing SLM. 07/01/89 Finished circulating kill fluid from C21-26 into C43-14. Had 8.5 ppg around in C21-26. Pulled 3 stands, installed SSSV/control line. Run 3 stands. Land tubing with BPV installed. 3K down wt on locator as hanger landed in "AP" spool. Nipple down BOPE, nipple up tree. Test to 5000 psi. OK. Pulled BPV. Test tubing and packer seals to 2000 psi. OK. Sheared out plug in reentry guide with 3400 psi. Rig up slickline, pulled dummy valve from SBBK/082489 - 18- DATE 07/10/89 07/15/89 07/16/89 DAILY REPORT OF OPERATIONS (continued) C21-26 DESCRIPTION SSSV. Ran 2-1/8" dummy, shot PERF gun to 10400' and back with no problems. Rig down slickline. Tear out rig while wirelining. Rig released @ 1800 hrs 06/30/89. Move rig from C43-14, rig accepted on C21-26 @ 0600 hrs 07/09/89. Rig up Atlas wireline, pressure test lubricator @ 2000 psi. Perforate as follow with 2-1/8" Silver Jet Gun 4 JSPF. RUN #1 Misfire RUN #2 10740' - 10734', 10730' - 10719', 10714' - 10709' RUN #3 10638' - 10604' RUN #4 10604' - 10570' RUN #5 10474' - 10444' Rig down Atlas wireline. Release rig to C41-26 @ 2230 hrs 07/09/89. Accept rig from C41-26 @ 1700 hrs. Repair and replace gantry lines on 3900 crane. Rig up Atlas wireline, pressure test lubricator @ 3000 psi. RIH with GR/CCL/basket flow meter/pressure, tie in GR/CCL, flow well until stable. Log with Atlas wireline production log. Production log with HP temp/basket flow meter/GR/CCL. POH with wireline, rig down Atlas wireline. Release rig to C43-14 @ 1000 hrs 07/15/89. SBBK/082489 - 19 - May 25, 1989 Shell Western E&P Inc. ~ 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SURVEY REPORT MGS WELL Enclosed please find one copy of If there are any questions please 263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs C21-26 the Completed contact Susan Survey of MGS Well C21-26. Brown-Maunder at (907) WFS/SBBM/raf Enclosure ~AY ~ o ~ ~ Alaska Oil & C-,~s Con.~. Commis~io~ Anchorage SBBJ/052589 S~URVEY REPORT SHELL WESTERN EXPLORATION ~RODUCTION, INC. MIDDLE GROUND SHOAL, UNIT C-21-26 KENAI BOROUGH, ALASKA SHELL PLATFORM C MAY 16, 1989 RECEIVEP MAY ~ 0 I~89 Alaska Oil & ~as Con~. Commission Anclaorago Gyrodata Incorporated RO. Box 79389 Houston. Texas 77224 713. 461-3146 May 16, 1989 Mr. Randy Wagner Shell Western Exploration & Production 601 W. 5th St., Suite 810 Anchorage, Alaska 99501 Re: Middle Ground Shoal, Unit C-21-26 Kenai Borough, Alaska Dear Mr. Wagner: Enclosed please find one (1) original and six (6) copies of the completed survey of Unit C-21-26. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, G~y U~echt Vice President, Technical Services GWU / cv Enclosures Gyrodata Services, Inc. Houston, TX;Lafayette. LA New Orleans, LA Ventura. CA Aberdeen, U.K. Calgary, Alberta A 6yrodata Di~' ectional for Survey SHELL WESTERN EXPLORATION PRODUCTION INC. MIDDLE GROUND SHOAL UNIT E-21-26 KENAI BOROUGH, ALASKA l)Jte ku,l: 14-M5Y-~3 15:45:00 Job Number: AKO589G233 Surveyor: AD~tS Calculation Method: MINIMUM CURVATURE Survey Latitude: 60deg 45xnin 505ec N Bearings Corrected ldeg 16min 36sec EAST to Grid North Proposed Well Direction: S 58deg 39min 36sec W Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy rod a t a ii;l,lJ WESTERN EXPLORATION PRODUCTION INC. )LE GROUND SHOAL UNIT C-21-26 XI BOROUGtt, ALASKA D i 'r e c t i o n a 1 Survey Page I MI<AS I NCL BORE tlOLE I) EPTtt BEARING ft deg rain deg rain .0 0 0 100.0 20O .0 300.0 :~00.0 500.0 000.0 700.0 SOO .0 900.0 1000.0 1100.0 120O .0 130O. 0 140O. 0 15O0. I t,O 0. 17O0. 1500. 1'500.0 20O0.0 2100.0 2200.0 '23O0.0 240O .0 0 7 0 IS 0 15 0 24 I 36 ~ 27 513 617 6 4O 7 i4 819 8 36 847 913 :-~ 44 10 20 10 48 11 17 11 53 12 26 i3 5 13 36 14 22 14 57 DOG-LEG VERT VERT C L O S U R E SEVERITY DEPTH SECTION DISTANCE BEARING deg/100' ft ft ft deg min N 0 0 E .00 .0 .0 .0 N 0 0 E MEASURED DEPTHS REFERENCED TO PLAT. C RKB ELEV. 105 FT. MSL N 89 i0 W .12 100.0 .1 .1 N 89 10 W N 77 33 E .42 200.0 -.1 .1 N 39 48 E N 62 45 E .08 300.0 -.6 .6 N 66 19 l S 1S 51 W .66 400.0 -.6 .7 N 87 40 E N 54 2 E 1,95 500,0 -1,7 1,8 N 73 3 E S 5i 32 W 5,05 599,9 -,1 .7 S 40 59 E S 6]. 41 W 1.91 699.7 7.4 7.4 S 52 15 W S 40 56 W _.~ 3'~_, 799.~ 17,~ '~ 17.3 S 51 9 W S 26 33 W i.66 898.5 27.3 28.'2 S 44 15 W S 18 28 W 1,13 997.8 37,0 S 12 5h W 1,31 1.096,9 46,9 S 24 7 W 1,67 1195,8 58,1 S 26 23 W ,39 1294,6 70,7 S 25 35 W ,46 1393,4 83,8 39,6 S 37 43 W 52,4 S 32 7 W 66,7 S 29 11 W 81,8 S 28 27 W 97,4 S 28 3 W S 25 40 W ,51 1492,1 97,6 S 26 55 W ,64 1590,5 112,4 S 27 ]6 W ,46 1688,8 128,0 S 27 38 W ,49 1787,0 144,4 S 28 29 W ,62 1884.9 161,6 1i3,9 S 27 42 W 131,3 S 27 31W 149,6 S 27 28 W 168,7 S 27 28 W 188.8 S 27 32 W S 29 59 W .64 1982.7 180.0 S 31 25 W .72 2080.2 199.5 S 32 46 W .60 2177.5 220.1 S 33 3'2 W .79 2274.6 241.9 S 33 36 W .59 2~71.3 '2~4.8 209,9 S 27 42 W 231,9 S 27 59 W 254,9 S 28 22 W 279.0 S 28 47 W 304.2 S 29 10 W H O R I Z O N T A L C O O Iq D I N A T [~, ,S.~) feet .00 N .00 E .00 N .10 L' .06 N .05 E ,2/~ N .55 l: .03 N .67 E .51 N 1.69 .54 S ,47 4,56 S 5.89 10.85 S 13,48 20.18 S 19,66 31.35 S 24.25 W 44.37 S '27.85 W 58.2.3 S 32.52 W 71.90 S 3~.97 85.96 S 45.82 f..' "-, 100.81 S 52.94 W 116,42 S 60,66 W 132,74 S 69,01 W 14tt,73 S 77.83 W 167.44 S 67.28 W 185.81 S 97.56 W 204.78 S lOs.8z, W 224.32 S 121.09 W 244.54 S 134.30 W 265.63 S 1~8.')0 W A Gy r o d at a iLL WkS'I"ii. RN EXPI.,ORA'YION PRODUCTION iNC. )[.,E (;ROUND .SHOAL UNIT 6-21-26 ti BOROUGH., ALASKA Nun:t~e.c.- at<05;:,':JO23 J Directional Survey Page 2 >tEAS I NCL BORE HOLE DOG-LEG 'Dt! l:q' tl BEARING S EVERI TY fi: deg rain deg rain deg/100' 3000.0 19 50 S 38 57 W ~100.O 21 45 S 41 13 W 3200.0 23 45 S 42 33 W 33(10.() 26 6 S 42 56 W 3:,00.0 28 23 S 44 40 W ~!::0().0 29 z~3 S 45 35 W 3o00.0 30 35 S 45 50 W 3700.0 31 59 S 46 13 W 3::,00.0 33 5 S 46 19 W 3'J00.0 34 27 S 46 35 W 4000.0 35 8 S 46 41 W 4100.0 35 11 S 46 10 W 4200.0 35 19 S 46 12 W 4390.0 35 1i S 46 30 W 4400.0 34 41 S 46 29 W 4500.0 34 22 S 4~ 5 W 4600.0 33 45 S 46 i7 W 4700.0 33 19 S 47 9 W 4,$00.0 32 54 S 47 18 W 4900.0 33 6 S 46 32 W VERT VERT DEPTH SECTION fr ft .74 2467.8 288.8 .98 '2563.9 314.'2 .55 2659.6 340.8 .73 "2755.1 368.4 .73 2850.2 397.:] 1.54 2944.7 427.9 2.08 3038.2 461.6 2.06 3130.4 498.6 2.35 3221.I 539.2 2.42 3310.0 583.4 1.41 3397.4 630.6 .87 3483.9 679.5 1.42 3569.3 730.2 1.10 365:3.6 782.7 i.37 3736.S 837.0 .69 3818.9 89'2.9 .30 3900.7 949.1 .13 3982.3 1005.5 .22 4064.0 I061.9 .50 4146.0 1117.8 .38 4228.4 1173.2 .63 4311.2 1227.9 .64 4394.6 1281.9 .42 4478.3 1335.5 .46 4562.2 1388.8 CLOSURE i)ISTANCE BEARING ft deg rain 330.6 S 29 33 W 358.1 S 30 0 W 386.7 S 30 28 W 416.3 S 30 56 W 447.0 S 31 23 W 479.5 S 31 51W 514.6 S 32 25 W 552.8 S 33 5 W 594.4 S 33 ~6 W 639.5 S 34 29 W 6:57.3 S 35 14 W 736.7 S 35 56 W 787.9 S 36 36 W 841.0 S 37 13 W 895.8 S 37 47 W 952.3 S 38 19 W 1009.3 S 38 47 W 1066.6 S 39 11 W 1123.8 S 39 33 W 11~0.7 S 39 53 W 1237.0 S 40 10 W 12')2.8 S 40 26 W 1347.7 S 40 41 W 1402.0 S 40 57 W 1456.2 S 4i 10 W H O R I Z O N T A L C O O R D I N A T E S feet 297.!)6 S 163.02 310.14 S 179.00 333.28 S 196.0~, ]57.06 S 213.94 381.59 S 232.76 407.28 S 253.02 W 434.42 S '275.90 W 463.19 S 301.74 W 494.14 S 330.34 W 527.15 S 362.04 W 561.41 S 396.45 W 596.45 S 43'2.40 W 786.86 S 63'2.10 W 826.82 S 673.7-5 W 866.66 S 715.50 W 906.08 S 757.02 W 945.25 S 797,9:~ 984.03 S 83.$.40 1021.90 S 878.61 1059.01 S 918.71 1096.21 S 95S.49 A Gyrodata iI:l'. ~;l'i,$'i'l.,.liN ~_XPLORATION PI!~ODUCTION INC. )LE GROUND SHOAL UNIT C-2i-26 ~I BO[~OUGH, ALASKA Number: D i r e c t i o n a .1 Survey MEA$ INCL BORE HOLE DOG-LEG DEP?'H BEARING SEVERITY ft der min der min deR/100' 50()0.0 32 49 S 46 57 W 5100,0 3.3 $ S 47 43 W 5200,0 31 55 S 47 58 W 5300.0 32 23 S 47 34 W 5400.0 31 46 S 48 2 W 5500.0 31 4 S 50 31 W 5600.0 30 39 S 55 34. W 5700.0 30 13 S 59 52 W 5~0().0 30 33 S 63 13 W 5900.0 31 30 S 63 44 W ~000.0 32 20 S 64 30 W blO0.O 33 52 S 64 44 W ~2()0.0 34 56 S 65 1.5 W 6300,0 :36 23 S 65 36 W 64{~0.0 37 2 S 66 13 W 6500.0 37 15 S 67 4 W 6f;O0.O 3~ 8 S 67 51 W 6700,0 38 40 S 68 54 W 6,~00.0 39 43 S 69 19 W 6'~O0.0 3'iJ 47 S 69 4 W 7000,0 40 14 S 69 35 W 7100.O 40 3 S 70 37 W 7200,0 40 17 S 69 54 W 7~00,0 40 7 $ 71 46 W 7400,0 40 20 S 71 42 W VERT VERT DEPTH SECTION ft ft ,36 4646,1 1442,0 .53 4730,0 1495,4 1,22 4814,3 1548,2 .52 4899,0 i600,5 ,67 4983,7 1652,6 1,47 5069,0 1704,0 2,63 5154,9 1755,0 2,2'2 5241,1 i805,6 1,73 5327,4 1856,1 ,98 5413,1 1907,5 ,93 5498,0 1960,1 1,55 5581,8 2014,4 1,11 5664,3 2070,6 1,45 5745,5 2128,5 ,76 5825,7 2187,8 .56 5905.4 '2'247.6 1,00 5984.5 2308,0 .85 606'2,9 '2369,2 i,08 6140.4 2431,3 ,17 6217,3 '2494,2 .56 6293.9 2557.4 .70 6370.3 2620.6 .52 6446.7 2683.8 1.'21 65'23.1 2746.9 .22 65~9.5 2809.8 CLOSURE DISTANCE BEARING ft der min 15i0.3 S 41 22 W 1564.4 S 41 34 W i617.9 S 41 47 W 1670.8 S 41 58 W 17'23.7 S 42 9 W 1775.4 S 42 22 W 1625,8 S 42 39 W 1874,7 S 43 3 W 1922,7 S 43 32 W 1971,3 S 44 3 W 2021.0 S 44 34 W 2072.4 S 45 5 W 2125.6 S 45 36 W 2180.5 S 46 7 W 2236.8 S 46 38 W 2293.7 S 47 9 W 2351.1 S 47 40 W 2409.3 S 48 12 W 2468.4 S 48 43 W 2528.4 S 49 13 W 25~8.9 S 49 43 W 2649.4 S 50 12 W 2710.1 S 50 40 W 2770.8 S 51 8 W _.~31,3 S 51 35 W H O R I Z 0 N T A L ']~./ C O O RD I N A ~' E S feet i133.50 S 998,10 W 1170,38 S 1038,12 W 1206,46 S 1077,97 W 1242,24 S 1117.3.5 W 1277,91 S 1156,7"2 W 1311,92 S 1196.2I W 13h2,74 S 121t7,15 W 1369,79 S 1279.94 W 1393,88 S 1.324,39 W 1416,89 S 1370,5i W 1439.96 S 1418.07 1463.36 S 1467.40 1487.25 S 151~.61 1511.49 S 1571.63 1535,88 S 1626.13 1559,82 S i681.62 1674.08 5 1974.81 W 1696.03 S 2035.4) W 1717.8'2 S 2096.14 W 1739.01 S 2157.10 W 1759.26 S 2218.43 W A G y r o d a t a !I,L l<'Eb'l'[:.R[< EXPLORA~iION ?t:~ODU'CTION INC. )I.,E GgOUN~ SHOAL UNiT C-21-26 XI BOt~OUGH, ALASKA D i r e c t i o n a [ Survey Page 4 ME. AS I NCL BORE HOLE DOG-LEG I) Et:'7 tl BEARING S EVERI 'FY fr. deg ;ain deg rain deg/100' 7500.0 ;,0 16 S 71 29 iq 7600.0 35 37 S 7'2 4 W 7700.0 25 5a S 7~2 47 1,I 7.~00.0 25 2 S 73 57 W 7'~t)0.0 18 57 S 75 51. W ~000.0 17 25 S 77 14 W 8100.0 17 32 S 77 4,3 W 8200.0 17 32 S 79 9 W 8300.0 17 18 S 78 13 W :~400.0 16 10 S 80 41 W ,5500.O 13 48 S 81 25 W 8600.0 11 17 S 82 51 W 8700.0 6 31 N 79 20 W 8c~00.0 4 15 N 71 21 W 8':,00.0 2 43 N 43 48 I4 9500.0 6 42 '.'l .q3 1:; E '9!:.,O0.0 9 I N 5k 17 E 9700.0 11 52 N 59 13 E 9800.0 14 13 N 61 12 E ':~'-)()0.0 17 20 N 62 6 E VERT VERT DEPTH' SECTI ON ft ft .i6 6675.7 2872.8 4.67 6754.6 2932.7 5.65 6838.6 2985.3 4.97 6927.3 3029,9 6.12 7020.0 3065.9 1.60 7i15.0 3095.5 .19 7210.4 3i24.0 .43 7305.7 315'2.3 .36 7401.1 3180.4 1.33 7496.9 3207.3 2.38 7593.5 3231.2 2.53 7691.1 3251.'2 5.45 7789.9 326h.3 )7 .9 '~ 34 7889 4 3,,0 "2.27 7989.3 3273.¢ 1.24 8089.2 3273.8 1.10 81~9.0 3271.8 1.36 8288.9 3267.6 .97 8388.6 3261.5 i.14 8488.2 3253.7 1.52 8587.7 32~3.8 2.76 8686.8 3230.3 2.98 8785.1 3212.2 2.40 8882.5 3189.6 3.12 8978.7 3162.5 CLOSURE DISTANCE BEARING ft deg rain 2892.2 S 52 I W 2950.1 S 52 26 W 300i.0 S 52 47 W 30,-q4.3 S 53 5 W 3079.1 S 53 20 W 3107.5 S 53 34 W 3135.3 S 53 47 W 3162.7 S 54 1 ~ 3189.9 S 54 15 W 3216.0 S 54 28 W 3239.1 S 54 40 W 3258.4 S 54 50 W 3'271.0 S 55 0 W 3277.2 S 55 7 W 3279.8 S 55 13 W 3279.5 S 55 17 W 3277.2 S 55 22 W 3272.9 S 55 26 W 3'266.5 S 55 2~ W 3258.5 S 55 32 W 3248.4 S 55 35 W 323~.9 S 55 36 W 3216.8 S 55 36 W .]194.3 S 55 34 W 3167.3 S 55 3i W H 0 R I Z 0 N T A L C O O R D I N A 'i' Ii S feet 1779.69 S 2279.~0 W 1798.93 S 2338.17 W 1815.30 S 2389.76 W 1828.55 S 2433.95 W 1838.37 S 2470.05 W 1845.65 S 2500.42 1852.16 S 2529.73 1858.20 S 2559.23 1864.07 S 2588.57 1869.36 S 2616.56 1873.39 S 2642.39 1876.39 S 2663.S~ 1876.56 S 2679.1S 1874 31 S ~5~8 3 1871.40 S 209].50 1867 6:3 S '2695 ~_ 1862.89 S 26u6.25 1857.19 S 2694.83 1850.69 S 2691.66 1843.78 S 2686.72 1.?,36.09 S 2679.76 ~.~ IS27.26 S 266'~.40 W 1&17.42 S 2054.20 ~,) 1806,23 S 2634.60 W 1793.34 S 2010.60 W A G y r o q a t a W~S'i-ERN EXPLORA?ION P[IODUCTION INC. (;ROUND SHOAL UNIT C-2t-26 BOROUGH. AL, ASEA be~'" AK05SBG233 DSrec t iona 1 Survey r,i 1:..:'\.5 IhCI, BORE HOLE DOG-LEG Dii }"T}t BEA[I i NG S EVE[ti TY fr. deg rain deg rain deg/100' 10000.0 19 57 N 63 32 E 10100.0 23 11 N 64 46 E 102C, 0.0 25 47 N 65 45 E 10300.0 28 27 N 66 17 E 104()0.O 30 38 N 67 8 E 10500.0 32 39 N 68 11 E 10600.0 36 7 N 68 37 E 10700.0 40 36 N 67 27 E 10900.0 50 3') N 68 14 E 11000.0 55 &5 N 67 28 E 11'1(.~0.0 59 5 N 67 19 E 11200.0 !59 3.5 g 6,5 48 E 11300.0 58 56 N 70 2.] E 11326.0 5S 5~ N 70 16 E VERT VERT DEPTH SECTION ft ft "'2.66 9073.5 3130.6 :.I.27 9166.4 3094.0 2.63 9257.4. 3052.8 2,68 9:346.4 3007.6 2.22 9433.4 2958.8 2.09 95i8.6 2907.0 3.47 9601,i 2851.4 4.54 9679.5 2790.I 5.19 9752.3 2722.6 4.88 9819.0 2649.0 5.13 9878.8 2570.0 3.34 9932.7 2486.7 1.40 9983.6 2401.8 1.53 10034.7 2317.4 PROJECTED DEPTH .37 10048.1 2295.6 CLOSURE DISTANCE, BEARING f t deg rain 3135.6 S 55 26 W 3099.2 S 55 20 W 3058.4 S 55 12 W :]0t3 7 S 55 "~ W 2965.4 S 54 51 W 2914.3 S 54 37 W 2859.5 S 54 2I W 2799.2 S 54 3 W 2732.8 S 53 43 W 2660.6 S 53 19 W 2583.2 S 52 52 W 2501.7 S 52 23 W 2419.0 S 51 50 W 2337.3 S 51 11 W 2.'t16.2 S 51 0 W HORIZONTAL COORDINATES feet. 1778 "~' .,J S 258~ ")1 W 1762.75 S 2549,11 W 1745.42 S 2511.46 W 1726.8'3 S 2469.81 iq 1707.41 S 2424.51 W /687.48 S 2375.99 1666.70 S 2323.4,.9 1643.47 S 22{:~5.96 1617.47 S 2202.61 14 158'3.61 S 2133.52 W 1559.42 S 2059,38 W 1527.03 S 19SI.61 W 1494.88 S 1901.,50 W 1464.90 S lS21.23 W 1457.40 S 1800.26 Finul Station Closure: 2316.2 feet South 51 deg 0 min 29 sec West CHART NO lC,. 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";-7 h'l ...... --~ ~'~ ............. .-----. -:--~;-~'r':' -"-~-i-~'; ~ '- :': "~----~-:"'i -':-~-?"~:...~ ....: '- !'.~' ,-r'-+' ?-:'-~--:--~--' ....; :-~-~-'- -~-~ .... SCHLUMBERGER WELL SERVICES 500 w. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY LOCATION ATTENTION · AK OIL & GAS CONSERVATION · 3001 PORCUPINE DR. · JOHN BOYLE COMMISSION X COMPUTING CENTER PRINT CENTER WELL NAME SERVICES ' · C.41-26 SEE ENCLOSED CH DISTRIBUTION SHEET NO, OF BOXES: ONE JOB NO. ADD'L TAPES · -- ENVELOPE WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME ' SERVICES · WELL NAME ' SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · NO. OF BOXES: JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · WELL NAME · SERVICE JOB NO. ?., ,.~ \ .~!~J ADD'L TAPES · j. DATE DEL VERED.~ RECEIVED BY: . SCHLUMBERGER WELL SERVICES 500 w. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COM PA NY LOCATION ATTENTION ~TATE UF ALASKA OIL & GAS CONSERVATIOi~ SOO1 PORCUPINE · gO?~i~ BUYLE COMHISSION COMPUTING CENTER PRINT CENTER WELL NAME SERVICES ' NO. OF BOXES' JOB NO. · ADD'L TAPES · SEE EJ~CLC biS!-R~BUT]ON SHE El' ON E WELL NAME ' SERVICES ' NO. OF BOXES: JOB NO. ' ADD'L TAPES ' WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: NO. OF BOXES: JOB NO. ' ADD'L TAPES -. ./ Anchorage / RECEIVED BY: WELL ,.DATA R~,LEASE RECORD ( BASED ON TWO YEAR - ONE MONTH CONFIDENTIAL PERIOD.) INCLUSIVE DATES: fm ~//I I~' to ~/~{~1 RELEASED ON: E ..... i i I I I I I I I I PEP~IIT NO. WELL NAME ~' NO OF nOGS ~GNETiC TAPES ' ! ~. ~ NO OF LOGS ~GNETIC T~PES RE~RKS .... ~o or ~o~s m~c ~s ' ...... REd. KS RE~RKS ' ~o o~ ~00s ~~c"~e~s ............. ' ,, , , RE~RKS ~o o~ ~o~s ~~c' ~S ......... RE~d(S RE RETAIN THIS SECTION FOR YOUR RECORDS C21-26 & C43-14 {SHELL} PLS i PRINTS 13 NEG. ]~ SEPIA CCL i PRINTS D NEG. ]~ SEPIA PRINTS NEG. SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA I~ I~J~. i'd 1~ I r I~ PRINTS NEG. ~~ PRINTS NEG. "' '""_ _ , ~ PRINTS NEG. ' ~_. PRINTS NEG. .._[¥___, PRINTS NEG. ATTENTION SIGNED DATE 19~ RE RETAIN THIS SECTION FOR YOUR RECORDS " MGS C2t-26~ (SHELL LOG) Anchora.(le ABOVE RECEIVED FROM ATTENTION ACBL/V/S' 1 PRINTS 0 NEG. PRINTS NEG. 1"3 I' ~' r ! % ~ r ~ PRINTS NEG. ~ I- ~1',~ V~ ~ PRINTS NEG. ("~~~-~//~~ ~ PRINTS NEG. ~ ~ll'l~ ~ ~ 79~,(~-'~ PRINTS NEG. ~ ...... PRINTS NEG. Alaska 0ii & Gas ~uris. uu,,,,~ssmfl PRINTS NEG. · DRESSER ATLAS ~;OHN BOYLE SIGNED ~ ' DATE SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA 19__ :SCHLUMBERGER WELL SERVICE8 DIVISION OF ~CHI.,UMB[R~I;Ilml TI:CHNOI. D~y CORIIONATION HOUSTON. T[XAS 771ZS 1-217~ J u n e 2. 1 9 8 9 SCHLUM,E,Qe, W"LL S~,V~C~S 500 W. International Airport Rd. Anchorage, Alaska 99518 ATTN: Print Room Inc. Shell Western E&P, P.O. Box 527 Houston, TX 77001 Attention: Log .Fi les, WCK 4147 Gentlemen: LDT/CNL,F LOG-~J,RESITIVITY-~),2" TVD PHASOR DIL, EnclOsed are 1 B L prints of the 2" & 5" PHASOR DIL (RUNS 1 & 2),SHDT,RFT on: Company Shell Western E&P., Inc. , We~ £ "Q) ~ ~l ~ ,, ' Field Middle-Ground ShOal Additional prints are being sent to: 1 B L nrints Shellr Western E&P, Inc. 601 W. Fifth Ave., Suite 810 Anchoraqe...A.K. 99501 ATTN: Hank Van. Schelt County Kenal State A1 aska prints 1 B L prints Shell Western E&P. Inc, p.o, )lox 527 HoUston. TX 77001 ATTN- C.C. Williams WCK 1134 1 BL nrints She1.1' Western E&P, Inc. Platform "A" or "C" C/O Shell Kenai Office 130 Tradino Bay Ave.~ Suite. Kenai~ AK 99611 1I R F o l~d~ed--S~p.~a A~'Oil &' Gas ~~ati6~Commission 300_1 Porcupine Dr.. )~. Anc~hora!)e, AK 99501 ~ A T__T N :'"'-~d~..~.~ 0 y 1 e / The film is . returned tO, Shel 1 (Houston-Log Files) We appreciate the privilege of serving you. ~nrints prints prints Receiv.ed by- Very SGHLU NasV~ Oit & Gas Cons. Commission WELL SERVmCE~(knch°rage Marc Gunther I)il?lll¢? Id &#AGIII ? Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 April 3, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. Enclosed, in triplicate, is the Application for Sundry Approval to change, the approved program on Middle Ground Shoal Well No. C21-26. SWEPI anticipates needing approval by April 10, 1989. If you have any questions, please call Ms. Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/raf Enclosures RECEIVED APR u ~, tB~.q Naska.0il & Gas Cons. Commiss!01t SBB I/aogcc. 040389 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Operation shutdown I Re-enter suspended well i Alter casing i Repair well __ Plugging __ Time extension ! Stimulate I Change approved program ~ Pull tubing I Variance __ Perforate I Other 2. Name of Operator Shell Western E&P Inc. 3. Adc~.r(~CSwest Fifth Ave., Suite 810, Anchorage, AK 5. Type of Well: Development X___ Exploratory ~ Stratigraphic __ 99501 Service I 4. Location of well at surface At top of productive interval At effective depth At total depth Platform "C", Leg 2, Conductor 14 930' FNL and 1395' FWL Sec. 26, TSN, R13W 930' FNL and 1860' FWL Sec. 26, TSN, R13W 6. Datum elevation (DF or KB) 105' KB 7. Unit ~m~ dP~l(:;jPeer~Yr onuan~e Shoa 1 8. Well number C21-26 9. Permit number 89-04 10. APl number 50-- 733-20406 11. Field/Pool "6" Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Size Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth True vertical depth SEE ATTACHED (We are changing Casing Setting depth from 8294' to 9235'.) RECEIVED 13. Attachments Description summary of proposal iX Detailed operations program __ BOP sketch 14. Estimated date for commencing operation April 10, 1989 16. If proposal was verbally approved Oil I Name of approver Date approve(; Service ,bt 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Z:,4~ M,c,,,,~/~o/,, Title Division Operations Manager FOR COMMISSION USE ONLY 15. Status of well classification as: To be drilled Date April 3, 1989 IApproval No. ¢. Gas ~ Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ /__~,~ 009¥ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Commissioner Form 1 Rev / /. SUBMIT IN TRIPLICATE ALASKA DIVISION DRILLING PROGNOSIS 3/30/89 WELL: C21-26 LOCATION: PLATFORM "C", LEG 2, CONDUCTOR 14 OBJECTIVE: HEMLOCK EVALUATION GEOLOGY SWEPI INTEREST: 66.67'% AFE NO: 268091 FIELD: MGS EST. ELEVATION: 105' (mean Iow Iow tide: 73'~ DRILLING CORES LU WELL CASING ELEC. MUD SIGNIFICANT DEPTH AND SURVEYS LOGGER FORMATIONS TVD MD CE~/IENT 0 HOLE DEV. HOLE AND DIR. MUD SIZE CONTROL PROGRAM 24' Conductor 370' 13-3/8' Surface 1197' Casing FG 7400' GD 8335' ;9-5/8' Protective 8335' Casing GN 87O0' HC 9355' HZ 10035' 7' Prod~ Liner 101 I'l'nl 8294' 9235' 9235j 9614' 10350' 11205' 11385' T 17-1 f2' 12-1/4' C21-26 Page 27 C21-26 CASING DESIGN Casing Design Criteria Frac Gradient Pressure Gradient Max Collapse Pressure Max Burst Pressure Size 13-3/8" 9-5/8" 11 Depth 0-1197' TVD O- 1201' MD 0-4000' TVD 0-4235' MD 4000- 8335' TVD 4235- 9235' MD 8039- 9055' TVD 8935-10000' MD 9055-10177' TVD 10000-11385' MD Weight 54.5# 43.5# 47# 26# 32# 13-3/8" .57 .47 564 psi (Full~.evacuation) 1,160 psi (1/3 BHP @ 9-5/8" csg pt) 9-5/8" .60 .47 3,893 psi (Full evacuation) 3,600 psi (injection pressure) 7" (Liner). .76 .57 10,000 psi (pressure from frac jobs) 3,600 psi (injection pressure) ACTUAL DESIGN CONDITION Grade/ Tension # Collapse Burst Coupling Wt in Mud PSI PSI Casing Rating/Design Factors Tension(m) Col lapse Burst K-55 BTC L-80 LTC L-80 LTC L-80 LTC P-110 LTC 56,000 564 1160 323,000 1868 3600 147,000 3893 3600 17,000 5169 3600 - 19,000 10000 3600 853/10+ 1134/2.01 2820/2.43 825/2.55' 3336/1.79 6744/1.8~ 905/6.16 4926/1.27 6678/1.86 519/10+ 5470/1.06 7182/2.00 897/10+ 10911/1.09 12112/3.36 RRW/121688a February 9, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Shell Western E&P Inc. $01 West Fifth Avenue. Suite 810 SUBJECT' RESPONSE TO QUESTIONS ON THE APPLICATION FOR PERMIT TO DRILL (APD) MIDDLE GROUND SHOAL WELL C21-26 In a recent telephone conversation between M. Minder (your office) and S. Brown-Maunder (our office) the APD for C21-26 was discussed. Questions concerning the remote control on the choke manifold and the possibility of Tyonek production were raised. The answers to the questions are provided be 1 ow: le The choke manifold on the rig floor on Platform C is being modified to comply with the requirement to have a remote control panel as a backup to the manual control. A revised schematic drawing is attached. e In response to your inquiry concerning the possibility of occurrence of hydrocarbon zones in the Tyonek above the proposed intermediate casing point: after careful evaluation of the logs from nearby wells, it has been confirmed that there is no possibility of hydrocarbon bearing zones being encountered above the "E" Pool in this well nor in this part of the Middle Ground Shoal Field. The top of the "E" Pool is expected at a measured depth of approximately 9644 feet. Intermediate casing depth is expected to be between 8300 feet and 9600 feet measured depth. Thus, the shallow, non-productive zones will be isolated from any potentially hydrocarbon-bearing ones. We hope this resolves all outstanding questions on the above referenced APD. If you wish to discuss this matter further, please contact Susan Brown-Maunder at (907) 263-9613. Very t_ruly yours, Division Operations Manager Alaska Division MLW/SBBM/raf Enclosure SBB 1/020989 RECEIVED FEB 1 u ~il ~ Gas Cons, SHELL WESTERN E&P INC. MIDDLE GROUND SHOAL FIELD PLATFORM 'C' CHOKE MANIFOLD 1. 3' 5 KSI LINES 2. CROSS 3' X 3' X 3' X 3' 5 KSI 3. CROSS 3' X 3' X 3' X 3' X 3' 5 KSI 4. 3' 5 KSI GATE VALVE 5, ADJUSTABLE MANUAL CHOKE - 3' 5 KS! 6. ADJUSTABLE MANUAL CHOKE - 3' 5 KSI 8. 9. 10. NOTE: THIS CHOKE WILL BE REPLACED BY A 2-9/16' 10 KS! HYDRAULIC REMOTE OPERATED CHOKE BEFORE DRILLING OUT OF THE SURFACE CASING OF C21-26. PRESSURE GAGE 4' LINES MUD/GAS SEPARATOR 6' LINE INL TO MUD PITS VENTED AT TO MUD PITS January 27, 1989 Telecopy, (907)276-7542 Mx. M. L. Woodson Division Operations M~nager Shell Wes~e~ E&P inc. 601 W, Fifth Avenue, Suite 810 Anchorage, Alaska 99501-2257 Re, Middle Ground Shoal C21-26 Shell Weste~ E&P Inc. Permit No. 89-04 Sur. Loc. 6t8.65'FSL, 1549.76'FEL, Sec. 23, T8N, R13W, SM. Bt~ole Loc. 930'F~L, 1860'FWL, Sec. 26, T8N, R13W, SM. # Dear Mr. Woodson: F~nclosed is the approved application for permit to drill the above referenced well. Se permit to drill does not exempt you from obtaining additional Pdemits required by law from other governmental agencies, and ocs not authorize conducti~ drilling operations until all other required pe~itting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to co~ncing installation of the blowout prevenCion equipment so t~t a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Mere 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. Very t~ly yo~s~ Chairman of ~ Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COMMISSION dlf ~closure ~ cc: Department of Fish & Game, Habitat Section w/o encl. ;Department of ~vironmental Conservation w/o encl. M~. Bill H. Lamoreaux Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 January 4, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: SUBMISSION OF AN APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOAL C21-26 Enclosed, in triplicate, is the Application for Permit to Drill the upcoming Middle Ground Shoal well C21-26. The surface location is Platform C, Leg 2, Conductor 14. Drilling operations are expected to commence January 15, 1989, and continue for two and one-half months. In the unlikely event that H2S is encountered, we intend to comply with the 20 AAC 25.065 and follow the "Recommended Practices for Conducting Oil and Gas Production Operations Involving Hydrogen Sulfide". The proposed well path is within "close" proximity of existing wells C31-26, C22-26RD and C34-23. In order to prevent possible intersections with other wells, we have calculated collision cones for existing wells within close proximity of the proposed well and will shut in and bleed down any well in which the collision cone is penetrated. The collision cone is defined as the maximum radius of uncertainty for the survey instruments used on the wells in question. Please note that the two closest producers are C24A-23 and C22-26RD which are at distances of 1300' and 1450' respectively. This well, C21-26 is the first producer in the governmental quarter section. The current well plan calls for a TVD of 10,178', but SWEPI would like to maintain the~flexibility to drill to a maximum prognosed TVD of 10,500'. If you have any questions concerning this application, please call Ms. Susan Brown-Maunder at (907)263-9613. Very truly yours, M. L. Woodson Division Operations Manager Alaska Division MLW/SBBM/af Enclosures SBBI/aogcc.010489 RECEtVED .0il & Gas Cons. /"'"' STATE OF ALASKA -"~ ALASKA 0;_'AND GAS CONSERVATION CG .... , ISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill ~ Redrill lb. Type of"well. Exploratory I-i Stratigraphic Test r-! D~velopment Oil Re-Entry [] Deepen~1 Service [] Developement Gas [] Single Zone E] Multiple. Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Shell Western E&P Inc. 105tKB feet I.. . Htddle Ground Shoal 3. Address 6. Property Designation 601 West Fifth Ave,, Suite 810, Anchorage, AK 99501 ^DL 18756 "G" Pool '4. Location of well at surface Platform "C", 'Leg"2, Con- 7. Unit or property Name 11. Type Bond (see 20 AAC 2S.025) duotor 1~. Hiddle Ground Shoal At top of productive interval 8. Well nurpber ' Number 11C136503 930'FNL and 1395' FWL Sec.26, TeNs R13W C21--26' Statewtde INA-Shell 008~ At total depth 9. App~x{_rnat~e spud date Amount $100,000 930' FNL and 1860' FWL Sec. 26, TeN, R13W ~lel~l~..-eS', 1989 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD,nd TVD) property line 1395t FWL feet C22-26RD 1300' feet 37~6 11,~37'HD/10,178'TVD feet wells' To be complet~lsfor deviated ~.0 17. Anticipated21~sSure (see 20 ~c 25.035 (eX2)) .5812 Kickoff depth feet Maximum hole angle o Maximum surface pslg At total c~epth (TVD) I:)slg -~8, Casing program ' . . Setting Depth.. " size Specifications Top Bottom Quantity of cement H?!.e. C?_si.n_g__ ._We_ight Grade Coupling Length MD TVD MD TVD ..-(inc!.u..d.e stage data) 12-1/M' 9"5/8' ~3.5 L-80 LTC ~308" 0 " 0 q308' ~000' 560sx 'G" + additives q7 L-80 LTC q008' ~308~ ~000' 8316' 7~00' , , , 8-1/2" 7" 26 L-80 LTC 2085' 8016' 7106' 10101' 9108' 1235sx 'G' + additives 32 P-110 LTC 133~' 10101' 9108' 11~37' 10178' 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 RECeiVED Intermediate Production Perforation depth: measured A~aska 0il & Gas Cons. C0mrnissi0~ true vertical Anchorage : '20. Attachments Filinjg fee 1~ Property plat~ BOP Sketch ¢ Diverter Sketch'¢ Orilii'ng program J~ ' Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21,1 hereby certify that the foregoing is true and correct to the best of my knowledge I ~Signed. . ~/. Title Division Operations Meneqer ~t1~/89 Commission Use Only Permit NUmber J APl number ! App~),aJ ~_ ate_ J See cover letter ~ ~ - d ~ , 50- ?~.5 - .2.. ~ ~ ~ ~ 0 :[ / 2 7 / 8 9 for other requirements Conditions of apProval Samples required [] Yes ~ No Mud log required [] Yes 'Er No Hydrogen sulfide measures ~ Yes [] No Directional survey required j~ Yes [] No Required working pre~s~pre fo/,/BO~2M; ~ 31Vi, if ~ 5M; [] 10M; [] 15M by order of DRILLING PROGRAM MIDDLE GROUND SHOAL C21-26 1. Rig up. 2. Drill out 24" casing shoe with 17-1/2" bit. Continue drilling to 375'. 3. Kick off at 375' and directionally drill to 1204' MD using 17-1/2" bit. 4 Run and cement 13-3/8" 54 5# K-55 BTC casing 5. Nipple up BOP stack. Test all connections, valves, and rams to 3000 psi. Test annular preventer to 2500 psi. Test all kelly, stand pipe, and emergency valves to 3000 psi. Test casing to 1500 psi. All tests performed in accordance with AOGCC regulations. 6. Drill out 10' and perform leak off test. 7. Directionally drill 12-1/4" hole to 9-5/8" casing point. Run wirel ine logs. 8. Run and cement 9-5/8", 43.5 and 47#, L-80, LTC casing. 9. Nipple up BOP stack. Test all connections, valves, rams, kelly, standpipe and emergency valves to 5000 psi. Test annular preventer to 3500 psi. Test casing to 3000 psi. All tests performed in accordance with AOGCC regulations. 10. Drill out 10' and perform leak off test 11. Directionally drill 8-1/2" hole to TD. Run wireline logs and casing caliper log. 12. Run and cement 7", 26#, L-80 and 32#, P-110, LTC liner. 13. Proceed with cased hole completion prognosis. RRW/121688 Oil & O~as Cons. Commission Anchorage Interval: Mud Type: Recommended Properti es: RECOMMENDED MUD PROGRAM C21-26 17-1/2" HOLE 0- 1,204' Spud Mud (water and gel). Generic mud #2 * Weight = 8.5 to 9.0 ppg * Funnel Viscosity = 40 to 50 sec/qt * Plastic Viscosity = 5 to 10 cp * Yield Point = 10 to 20 lb/lO0 sq ft * Fluid Loss = no control * pH = 9.0 to 9.5 Page 2 Interval: Mud Type: Recommended Properties: 12-1/4" HOLE 1,204' to 8,316' Water and gel. Disperse only if required. Generic mud #2. * Weight = 8.9 to 9.5 ppg (maintain minimum MW of 8.9 ppg in case of pressure from C 41-23 casing leak) * Funnel Viscosity = 36 to 42 sec/qt * Plastic Viscosity = 5 to 12 cp * Yield Point = 10 to 15 lb/lO0 sq ft *API Fluid Loss = 20 cc * pH = 8.5 to 9.5 * MBT = 15 to 25 Interval: Mud Type: Recommended Properties: 8-1/2" HOLE 8,316' to 11,437' Saltwater dispersed lignosulfonate mud (1% NaC1). Generic mud #2. * Weight: 9.3 to 9.8 ppg, or as required to combat waterfl ood pressure * Salinity = 1% NaCl * Funnel Viscosity = 40 to 45 sec/qt * Plastic Viscosity: 15-20 cp * Yield Point: 10-20 lb/lO0 sq ft *API Fluid Loss: 10 cc; 5 cc by HC * HTHP FL at 150°: less than 20 cc; 10 cc by HC * pH: 9.5 to 10.5 * MBT: 15 to 25 RRW/121688 PLATFORM 'C' SOLIDS CONTROL 1/11/88 OPERATING MODE DRILLING UNWEIGHTED MUD' DRILLING WEIGHTED MUD TRIPPING BUILD SLUG GATES CLOSED D, E, G D, E,G E, F, C, G C, D, F MUD FLOW ROUTING 1-2-3-4-5 1-2-3-4-5 4-5-2-3 1-2-3-4 SOLIDS EQUIP, IN USE SS, 4' SS SS, 4' COMMENTS MAY WANT TO OPERATE 4' 4' TURNED OFF w/WEIGHTED MUD DERRICK FLO-LINE © NOTE: All ec r TRW R~ I~RANDT I I I I SLUG PIT/ SAND TRAP Legend TOP EQUALIZATION BOTTOM EQUALIZATION AGITATOR ualtzers (:except from pit 1 to 2~ are riser type and can be used for either top or bottom equalization. Page 4 CASING AND CEMENTING PROGRAM C21-26 1. Run 13-3/8", 54.5#, K-55, BTC from 1,204' to surface. Casing design criteria are attached. 2. Cement to surface using 20% excess on gaged hole volume from TD to conductor shoe. Lead with 240 sx Class "G" + 10% gel + 2% CaC12 + defoamer and friction reducer as required (12.8 ppg, 10.8 gal/sk, 1.94 cf/sk) followed by 200 sx Class "G" + 2% CaC12 + defoamer and friction reducer as required (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). Perform top job within shoe of conductor. 3. Run 9-5/8", 43.5 and 47#, L-80, LTC from TD to surface. See attached casing design criteria. 4. Cement to 7,316' MD (1000 ft above shoe) using 30% excess on caliper (preferably 4 arm caliper). Lead with an estimated 360 sx (based on a 15" hole) Class "G" + 4% gel + additives for rheologies (14.2 ppg, 7.6 gal/sk, 1.52 cf/sk, 2,000+ psi ultimate compressive strength) followed by 200 sx Class "G" + additives for rheologies (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). 5. Run 7", 26 and 32#, L-80 and P-110, LTC from 11,437' to 8,016'. See attached casing design criteria. 6. Cement liner with Class "G" + 1% NaCl + retarder + defoamer + fluid loss agent for WL less than 100 cc @ 150°F as required (15.6 ppg, 5.2 gal/sk, 1.18 cf/sk). Total thickening time between 3-1/2 and 5 hours brought up to temperature in 57 minutes. An estimated 1235 sx of cement will be required (based on 47% excess on a 10" hole and 300' above liner top). RRW/121688 Page 5 C21-26 CASING DESIGN Casing Design Criteria Frac Gradient Pressure Gradient Max Collapse Pressure 'ax Burst Pressure 13-3/8" .57 .47 701 psi (Full evacuation) 1183 psi (1/3 BHP @ 9-5/8"csg pt) 9-5/8" .60 .47 3550 psi (Full evacuation) 3600 psi (injection pressure) 7" (Liner) .76 .57 10000 psi (pressure from frac 3600 psi (injection pressure) treatment) ACTUAL DESIGN CONDITION Size Depth 13-3/8" 0-1500' MD 0-1507' TVD -5/8" 0-4000' MD 0-4300' TVD Grade/ Tension # Collapse Weight Coupling Wt in Mud PSI 54.5# K-55 BTC 43.5# L-80 LTC 4000- 7600' MD 47 # L-80 4300-9525' TVD LTC 7" 7395-8320' MD 9225-10578' TVD 26# L-80 LTC 8320-9473' MD 32# P-110 10578-12093' TVD LTC Burst PSI 70,000 701 1183 294,000 1868 3600 118,000 3550 3600 19,000 4750 3600 Casing Rating/Design Factors Tension(m) Collapse Burst 853/12.2 1135/1.62 2716/2.30 825/2.81 3434/1.84 6672/1.85 905/7.67 4179/1.18 6699/1.86 519/27.4 5443/1.15 7209/2. O0 -13,000 10000 3600 N/A 10876/1.09 12140/3.37 RRW/121688 Page 6 ATTACHMENT C21-26 The maximum pressure gradient is expected to be .571 psi/ft. Maximum BHP is expected to be .571 x 10,178 = 5,812 psi. The shallowest depth at which abnormal waterflood pressures could be encountered is 8700 TVD in the GN sand. Maximum surface pressure is expected to be 2,148 psi, assuming a full column of .360 psi/ft oil. The well will be drilled in compliance with the Alaska Oil & Gas Conservation Commission's regulations issued April 2, 1986. 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 open and tagged with instructions concerning proper procedures for closing a valve in the event that the preventer is closed. RRW/121688 '%WEPI INTEREST: 66.67% WELL: C21-26 ALASKA DIVISION DRILLING PROGNOSIS i2/19/88 AFE NO: LOCATION: PLATFORM 'C", LEG 2, CONDUCTOR 14 OBJECTIVE: HEMLOCK EVALUATION GEOLOGY FIELD: MGS EST, ELEVATION: 105' (mean Iow Iow tide: 73') DRILLING CORES UJ 0 - 0 ELEC. MUD SURVEYS LOGGER SIGNIFICANT FORMATIONS WELL CASING HOLE DEV, DEPTH AND HOLE AND DIR. MUD TVD MD 13E/MEN'I[' SIZE CONTROL PROGRAM 24" Conductor 370' 13-3/8' Surface .1200, Casing __.. 'FG , 7400' ~ " 9-5/8 Protective7400' .c q HZ 10035' ~ 7' Prod_ liner 10178' T 17- /2' 204' ~1~ g , ., ~.o ~m~, x · o :~ zo 0 8316' ~ o 8316' 9644' T ~o4o~ ~ 11257' ~=~= .~ ~E~om 11437' ~ ~" , MAGNETIC .DECUNATION: ~: ....... * ' /' i ,it i ~ ' : . . ! ...... , t , i .......... ,:.:.C21~26,..:!, ' : " . SCAt[: .... ll_.-..,l~Juu.: ~. 1 .... ~EOr 8; CO~DU¢IOR ~ i . . . i ; · t i i · i I I . · ' : ~" · · · ' .... ; '' :'' : ';i' : ; ',1 s.o 5 o3. I,I:: :., :. I:I: ,,: I ,'I, ,. :.., J: .::,,,, /it:::.!i:-:.Am, mvlrW':.- l. . i · - ~. , t..~ .... , ~.8~ i ~!.,~ :~::~ ...... .... GRID CORRECTION .-: 1.3~,,(I : ' ' NET MAGNETIC suRVEY CdRRECTION :-,' :; .......... !'''''''''l'' .... '": ' : '~::; UPPER YERTIC:.AL · , i ET ~1' 3 RIENTI 'ARGET.' ~2 LOWER VERTICAL ~ECTION 100'X 600' '' :NTED NO°W -'' ..... ..... .' , ~ ..... · . . ~ : . . , · . . . : . . . , ....... ..... : : . ! . . SECTION : ~ ..... ~UTH~. 9010.~ : : **. .::...ii i:'{ · i : i : t ' .1 : . I , . t CHANGE SECTION . i · . · : . .i..iii ; .OWER .AT'AT 761'5' r ~ ' ..... '<Op '7615' TVD'--~ ' · ' ~ i 11000' i : j mv ~ A SECT ON [FEET) ,~. . ~ .... .... :ID il.:; .:.:~i. . T ARGE1 ~1! '! ~355' TVD ' "ii: ii' .44-4.4..4 0178' TVD 14~?' MD ' · , · ' I . : . I · . . ' i. ~ . . ~ ; , I : . . , i '1000 . ;2000.: il:: :1000.. ;.: : :. ' : :: ]; lVER'nCAL SECTION (FEET]i. ~.:..:: l~:i:ii:~!!t,~.,,!.j..t .... ~!'t'' ~: MGS C21-26 17-1/2' HOLE 2000'PSI STACK TOP OF KELLY BUSHINI ~i TOP OF DERRICK FLOOR ~ II I I II I I I I ...... ' ' ' ' To~' .,,bY' BOT OF ROT SEAM DRILL NIPPLE FLOW LINE FILL UP LINE ,, [ / ANNULAR !., PREVENTER _ ! . vl 2000PSI J~J l f/'-20' 2000PSIFLANOE -p ~'"',/' r-TO BE CONNECTED SO THAT VALVE IS ' ' ;~ r [ OPEN WHEN THE ANNULAR PREVENTER ~ ~ ./ IS CLOSED. BOTH 10" MECHANICAL VALVES WILL BE IN AN OPEN POSITION. UPON CLOSINO THE ANNULAR PREVENTER THE PROPER DIVERTER UNE IS SELECTED. I III I MAIN DECK' 20' ~000 PSI RISER WELLHEAD ROOM FLOOR II I I [ II I 9/10187 ;" /""'~' MGS C21-26 '/-"~' · 12-1/4' HOLE 3000 PS1 IOF O1' KELLY BtlBHING --- ,, allll i i I II II I I I I I ~1~-' ~.4o' ...... TO,¢' ~ [~[.i~lg,~,, .... rLoon I I I I II1 I I II I II I I I I II II I II i · l B611 OF R'bIARY BEAM i DRILL NIPPLE FLOW LINE ;ILL UP LINE ......... , , , · ~I PREVENTER r,J ., I ..... TOP OF 8UBBASE · ,, ~ , ~ ~ ~1 FLANGE ,~, , ,. ii MAIN DECK . ~000 ~ PSI ~ RISER , ~ ' ' L j 13-5/8' 5000 PSI FLANGE ~ ~ILL, ~ ~POOL~ i~ iii i I i]1 i i I I 9/10/87 13-3/~ SOW X 1 3000PSI 'WF'HOUSING N.T.S. NOTE: DIMENSIONS INCLUDE 1/2" GAP BETWEEN FLANGES ~ .MGS C21-26 ,"-K. 8- 1/2" HOLE 5000 PSI ~ rACK TOP OF KELLY BUSHING _ A 1.40' I DRILL ' ~ NIPPLE FLOW LINE FILL UP LI ,, , ,, ,, i , , . ANGE I L. _J15-518' 5000 T~ ·' ' " .... ~/r ~ V ~;;~ I;a /'~ r. - ~//~.,,,~.~,~,~~ h P"~.~;~[K~ ~',~ // ' // // / / / 13-5/8' 5000~SI FLANGE ,, ,,, /////// , ///////, MAIN DECK ~ 5000 ~ RISER ~ --'~~~ ~-~ 13'5/8' 5000 PSI FLANGE ~ ~ DSA .......... I I b ~CASING~~ m e ~ I ~HEAD ~ I ~ ~ooo~ I ~ ~ W~.~O.OOM ~00. ~ 'w~' ~ ii ii Bii i i i ~ ~ 9/10/87 13-3/8' SOW X 13-5/8' 3000 PSI HOUSING N.T.S. NOTE: DIMENSIONS INCLUDE 1/2' GAP BETWEEN FLANGES STACK REQUIREMENTS , ,,, , Min. Min. It.m I.D. Nominal FIo~tine Fill up Line 2" Drifting Nipple Annu'lar preventer' · Two single or one dual hydrualicall¥ operated rams Drilling sDool with 2" and 3'° min. outlets Gate Valve 3 1/8" Gate Valve Power Operated ' 3-1/8" Line to choke manifold 3" ..... Gate Valve 2.1/16" Check Valve 2.1/16.° Casing Spool Valves Gate 1-13/16" Compound Pressure Gau~le connector Control D'lug or,v,,alva 1-13/16" ,, ,, Kill line to rig mud pumD manifold 2" 2" X 2" X 2" cross ,, ~)TE: AddltlonM a~eciflcetton$ for Air/Get Sewlce ere given in Shell Well Control Manuel, Al~pendix 6.18. A rotltlne head shill be I)rovl(lecl on AIr/(~ll Service DRAWING & CHECK LIST 104A SHELL CLASS 5M SURFACE INSTALLATIONS NORMAL AIR/GAS' FOR AIR/GAS DRILLINO CONFIGURATION A ANNULAR PREVENTER BLIND RAM PIPE RAM OPTIONAL 2, Wear flange or bore I~rotector 9 Gate valve !0 Line to roadside connection 2" 21 Rotating blowout preventer , ,, 22 Gate Valve power operated 6" , WELL LOCATION /.--,,, PLAT MIDDLE GROUND COOK INLET, SHOAL FIELD ALASKA WELL." C21-26 C21-26 LEASE NO,: ADLI875ro 5280 FT. C~3-~ PROPOSED LOCATION AT TOP OF OBJECTIVE: 950 FT. FROM N LINE AND 1595 FT.. FROM W SECTION 26, T 8 N, R 15 PROPOSED LOCATION AT W AoSoPo T 0 TAL DEP TH; 950 FT. FROM N LINE AND 1860 FT. FROM W LINE LINE , SECTION 26,, T 8 N, R 15 W A.S.P. .... SHELl. MINIMUM REQUIREMENTS (4) .... . _ NO. \ (i;~:h! NOMINAL RA (IKh) N~INA[ RATING NWlNA[ RATIN~ 1 Li~m~ 3" 3. 3" 5.~ ~' , 10,~ 2 Cr~ ~'x~'x3"x2'' 3. 5.~ Cr~ 3"x~'x3"x3" 10.~ ,, ii - 6 Gate V.lv~ 3 1/8" 3.~ 3 1/~" 5.~ 3 1 ~" 10.~ / .... Cfc~ ~' x3..x3..x3.. 10.~ 8 Line 3.~ 3" 5~ 10.~ 9 ~nual Adju~ble Ch~e 1" 3.~ 1"' 5.~ 2" / ~ 10.~ 10 M~ual Adju~le Choke(3) 2" 3.~ 2" 5.~ 2" / ~ 10.~ Remots reading st,~pipe 3.~ 5.~ / ~ 10.~ 12 compound pressure geuge./ '( 13 Line 2" 3.~ 2" 5.~ 14 T~ 3"x~'x2" . .~ 5.~ 16 Lin~ 4"1~ 4" 1 .~ 4" 2.~ -- 17 T~ 3"x3"x3" 3.3.~ 2.~ 10.~ 18 Cr~ 2"x2"x2"x2"::~3. 2.~ 10.~ Cm~ 3"x3"x3"x3" ~ V,I~ Gate ~ 1 13/16" 5.~ ' 10.~ P~ug .. ~ (2) (1) Only one required in Class 3M. (2) Gate valvas only shell be used for Class tOM. (3) Remote operated hydraulic choke Mquired on Class rOM for drill/nE. (4) Requirements ere for new man/folds. Existing men/folds rely continue to hM a workinE pressura of the mMl~Yold Mcttoc. downltveem of the first valve beyond the choke through the last valve in any run of not leJ~ then 25~; of the working pressure of the choke, pro,/ding they em conmicuoud¥ m~rked "CAUTION.LOW PRESSURE VAL VE.DO NOT CLOSE AGAINST WELL PRESSURE." (S) Items no. 14 and 2 can be combined es 5 way croat EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS 1. All connections in choke mm/fold shell be welded, studded, flanged or C~neron clamp of comparable rating. 2. All flanges shall be APl 68 or 6BX and ring gaskets shall be APl RX or BX. 3. All lines shNII be securely anchored. 4. Chokes shali"be equipped with tunl~lten carbide wets and needlel, .~d replacements she[!, be availM~le. 5. Choke manifold pressure and standpipe pressure gauges 1ha!I. be lye/labia et the choke man/told to es~ist in regulating chokes. Aa an Ilternate with automatic chokes, a choke manifold pressure gauge sh~ll be located on the rig floor in con/unction with the st~xlpipe pre, ute gauge. 6. Line 1rom drilling spool to choke manifold should be as straight es pMsible. Lines downstream from chokes shall make turns by large bends o~ 90° bendl using bull plugged tees. 7. Discharge lines from chokes, choke bypl~s and from top of gal leparator should bent I~ far I~ price/cai from the well. 8. Additional specifications for Sour Service and Air/Gas Service ere given in Shell Well Control Manual. Appendix 6.17 and ,~ppendtx 6.18. MINIMUM CHOKE MANIFOLD DRAWING NO. 202B SHELL CLAS,I~ SURFACE INSTALLATION NORMAL RESERVE PIT OR ATMOSPHERE (MARINE) MUD TANK MUO TANk' RESERVE PIT BEYOND SUBSTRUCTURE 'SHEL. MINIMUM A JXILIARY EQUIPMENT REQUIREMENTS Master control with Hydril pressure .re.~lulatin~l v.alve. 4 unit remote control ' HYdraulic BOP operating unit. ,r, ee I~l'c~w fo'r detail. · Kelly cocks ~ Upper I~] Lower Pressure Rating 5,000,mi' · Kelly saver sub with protector rubber. · Inside BOP, surface type, for each size drill pipe. · Full .openin9 ball valve for each size drill pipe in use. · Labelled crossover subs for each different connection in drill string. OPTIONAL AUXILIARY EQUIPMENT * Circulating head for each size drill pipe in use with steel pipe and Chiksan joints to reach stand pipe connection. · Inside BOP - Drop or downhole type. Cup or plug type BOP tester with spare seals. SHELL MINIMUM HYDRAULIC OPERATING UNIT SPECIFICATIONS Accumulator volume - must deliver 1.5 times the volume to make position change on all hydraul-ically operated units and retain 1200 psi (200 psi. a,bove precharge) without pumps. Pump capacity to obtain 200 psi above accumulator precharge pressure in two {2) minutes or less, while closing annular preventer and opening choke line valve. See Section 4.31. , , ,, Power for pumps - 2 sources required - Air-Electric or All Air (rig air plus separate air tank) - :2 pumps re.q.uired. Lines from operating unit to BOP units 5,000 psi Minimum Yield E) Seamless steel lines .90" minimum I.D. ~) Seamless steel lines with Chiksan joints. E) Hose per Section 4.32 ..Operating unit fluids: Hydraulic oil or soluble oil. All controls shall be clearly marked to show unit operated. Blind Ram control to have easily removed latch or guard. Sufficient bottled nitrogen or other back-up storage system to equal accumulator capacity, manifolded to by-pass accumulator and close BOP directly. Alarm, or visual indicator to show.when accumulator is shut off from preventers. SHELL MINIMUM MUD SYSTEM REQUIREMENTS Pump stroke counters each p.ump: , , Degasser. Pit volume recorder with alarm. Flow line monitor. OPTIONAL MUD SYSTEM EQUIPMENT Trip tank (with 6th man) Flow line gas separator. MISCELLANEOUS EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS . 7. 10. Any miselignment of rig should be corrected to avoid undue wear of casing. ........ ,.~ .k.it ~,~ k~r. ~n or elm, ed. not in neutral positon. 1. All connections shall be welded, studded, flanged or Cameron clamp of comparable retina. 2. All flanges !ha, l] be APl 6B or 6BX and ring gaskets shell be APl steel RX or BX. Do not re-use BX rings. Always use new rings below lower most preventer when flanges ere parted. Drilling spools slmll be forged or forged end welded. Pipe spools not m:ceptable. BOP/tm:k .lh~, !1 be braced to subbese or suitable support by turnbuckled lines or rods. (No rigid connections. ) All gate valves shell be equipped with handwheels. Rams should have manually operated screw locking extensions (extended beyond subbase) ready for use. For I~nd rigs the master control station end operating unit shell be located et ground level · minimum of 50' from the well. The remote station is to be located near the driller's position. Inoperative condition of the remote unit is not to interfere with operation of the master control unit. For platform and tmrga rigs the m~ster control station end operating unit may be on the rig floor with the remote station located so that is I:)rotKted from the well arm end accessible from e logical evacuation route. Hydraulic lines may be high pressure hose provided they m#t the require- manta in Section 4.32 in the Shell Well Control Manual. Housing end heating should be providecl for accumulator, blowout preventers, choke manifold where conditions warrant. Contractor .she? make no connection to casino head side outlets except by orders of Shell. One spare ~et of rem blocks for the drill pipe in use s, hall be kept on rigs. ,, · (Io and 13) (14 cJaru 2.2.) (2) so Z ' (23 r. artx 28) o . . (29 :b:u 31) .~: 08/II/88 i. Is :he pe.--m/: fee ac:ached .......................................... ~- in a defined pool ............................. ~s=~Ca from pro~er~ Tdne .................. L 4~=~ca fr~m .=her =e~ .................... f ~dadicaca~ acreage av~abla ~ =h~ pool ............ ~d fs ~e~bore pla: ~c!udad ............... acta p~ ................................ before f~:ae:~ay - ~ ...................... NO 9. Does operator have a bond ia force .................................. ~ 10. Is a coz~erva=ion order needed ...................................... ~' · Il. Is adminis=ra=~ve approvai needed ................................... ll. Is :he lease umber approp=ia=e ..................................... ~-- 13. Does the ne!! have a m~ia. ue name a~d =u=~er ........................ : ~ , 14 Is couduc:or st.--lng provided ' sa~e as ~ ~der~o~ sourc~ of dr~,~ ~=ar ..................... 16. ~ enough c~= used =o c!rc~a=e on conduc=or ~d ~aca ......... 17. ~ c~: Cie ~ su~ac~ ~d ~:e~ed~=e or produc:~on s=~gs ... I8. ~ c~enc cover ~ ~~ pr. duc=lye hor~ons ..................... 19. ~ ~1 c~g give adequate s~a~ ~ co,apse, tension ~d burs=. 10. ~ ~s ~e~ =o be ~c~d off from ~ ~s=~E we~5ora ............. 21. Is ,id we~bora ab~do~en=, procedure ~c!uded on i~403 ............ . 21. ~ adequate =e~bore separation-proposed ............................ E/a-M/ ,, / ,,m 23. Is a diver:er s?'s~:am required ....................................... //~ 24. Is :he dr~--l!/~ fluid pro~ sche~ic ~d ~= of eq~en~ adequa~a ~,,, ~. ~a necessa~ d~r~ ~d d~c~Lpc!ons of ~ive~er ~d-B0~E a::ached. ~.. 27. Does :he ~o~ ~old c ~ ~-53 ..... ' Z~. ~ ~e pr~a~ca o~ ~Z~ ~ proha~la ................................. __ '~o= ~iora:o~' ~ Sc=a:i~ap~c ~e~: 19. ~e ~a~a pres~:e~ on po:an:~ ~e~rasa:a zones~. ................. 30. ~e sei~c ~7sts data pr,san:ad on sha~ Eas zones ............ 3I. ~ ~ offshore Ioc., ~a ~e~ ras~:s of seabed condi:ions Bresen=ed , lllll II I I Ill I 1111 Il o__ - ii i in · I i iiin I ii II I I u i inl · I n I i ,1
