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Home My WebLink About177-055 . . MGS FIELD WELLS CHANGE WELL STATUS FOR WELLS WITH LATERALS FEBRUARY 16, 2006 The following wells status was changed from SQZED to I-OIL. These wells had laterals drilled against them and production was assigned to all laterals in Cook Inlet when the wells were first drilled. Since then, AOGCC changed the policy about lateral wells and assigning production against lateral API numbers. This policy is like the lateral wells on the North Slope. Today I notice wells producing in the MGS field with a status not conducive to the well status and changed it to I-OIL. All the wells show oil production over the years. The status date reverted back to the date the well was completed as an oil well. The following wells were corrected: MGS A12-01 MGS A13-01 MGS A14-01 MGS A22-14 MGS A23-0 1R MGS A31-14 MGS A41-11 PERMIT 177-055 . PERMIT 166-015 PERMIT 167-079 PERMIT 185-068 PERMIT 187-093 PERMIT 177-031 PERMIT 185-174 \" -.;r ",It-';;"~~;; ìJ'i¡¡¡I~'\;;~"¡;¡"'- All production has been assigned back to the original well API number, no production is assigned to a lateral well API number. $1 ~:~ }1llt ~1M1<J¿J e 0 og escrlptlon ae o or H-13 11676950 GAS ENTRY SURVEY 06/20/07 1 C-41 11801077 LDL 06/19/07 1 A-30A 11661159 MEM PROD PROFILE 06/23/07 1 W-21A 11661140 MEM PROD PROFILE 04/21/07 1 E-21B 11661157 MEM PROD PROFILE 06/19/07 1 M-23 11626107 PRODUCTION PROFILE 06/23/07 1 01-21 11824330 PRODUCTION PROFILE 06/22/07 1 J-25A 11767130 MEM PROD PROFILE 06/18/07 1 Z-08A 11630483 GLS/PROD LOG 06/22/07 1 M-34 11824330 PRODUCTION PROFILE 06/22/07 1 02-30B 11594512 LDL 06/23/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 S-38 11801078 LDL 06/20/07 1 H-37A 11594506 PPROFIIPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFILE (REVISED) 06/13/07 1 Z-13A 11649962 MEM PROD PROF (REVISED) 04/21/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 USIT (CEMENT) 06/24/07 1 12-05 11676951 US IT (CORROSION) 06/24/07 1 B-15 11626097 US IT 06/14/07 1 G-24A 11628750 SCMT 02/05/07 1 Scblumbepgep RECEIVED Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth JUL 0 3 Z007 ¡~æka Oil & Gas Coos. Commission Anchorage WI! J b# L D . f D t 06/29/07 NO. 4324 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Prudhoe Bay BL CI CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 CCAJ.: NNED JUL 05 2007 900 E. Benson Blvd. ~- Anchorage, Alaska 99508 I-:¡~- ~S Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: TONY KNOWLES, GOVERNOR August 4. 1999 AI,ASKA OIL AND GAS CONSERVATION CO~IlSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA~99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 William Miller Cross Timbers Operating Company HC01 Box 485 Old Wik Road Kenai, AK 99611-9704 Dear Mr. Miller, Re: Administrative Abandonment Action Middle Ground Shoal Wells A33-11 Permit # 85-235 A22-14 Permit # 85-068 Al4-01 Permit # 67-079 Permit~ A31-11 Permit # 77-031 Al2-01 Al3-01 Permit # 66-015 A41-11 Permit # 85-174 This letter reflects the lateral well that replaced the original well by well number, permit number and APl number: A12-01LN (permit # 94-120, API# 50-733-10081-62) permit was approved 9/29/94. A13-01LN (permit # 94-105, API# 50-733-10079-61) permit was approved 8/05/94. A14-01LN (permit # 94-119, API# 50-733-20067-61) permit was approved 9/27/94. A22-14LS (permit # 94-071, API# 50-733-10085-62) permit was approved 5/13/94. A31-14LW (permit # 94-044, API# 50-733-20305-62) permit was approved 3/23/93. A33-11LS (permit # 93-180, API# 50-733-20383-61) permit was approved 11/30/93. A41-11LN (permit # 94-087, API# 50-733-20378-61) permit was approved 6/28/94. The replacement well incorporates a lateral with the existing well bore. The lateral along with the original hole will be used for production of hydrocarbons. A review of both well files indicates administrative abandonmem (SQZED, AOGCC stares) of the originating well bore is appropriate according to current AOGCC procedures for wells where additional permitted laterals are drilled from an existing well bore. Production will be reported to the original API wellbore (-00, -01 or etc) and not to the lateral API wellbore (-60, -61 or etc). 20 AAC 25.005(e) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, AOGCC databases require each conductor have only one permit number and API number. Administrative abandonmem of the original permit only eliminates duplication in the databases. Information for the original well and its replacemem will be maintained in their respective files umil plugged and abandoned according to 20 AAC 25.105. Please notify other cognizant personnel in your organization so that the well will be correctly identified on subsequent reports and applications submitted to the Commission. Chairman Memorandum State of Alaska Oil and Gas Conservation Commission To.' Well File: A33-11 Permit # 85-235 Al2-01 Permit # 77-055 Al3-01 Permit # 66-015 Al4-01 Permit # 67-079 August 04, 1999 A22-14 Permit # 85-068 A31-11 Permit # 77-031 A41-11 Permit # 85-174 Administrative Abandonment Action Middle Ground Shoal Wells This memo will remain at the front of the subject well file. The following lateral wells replaced the original wells listed above. This letter reflects the lateral well that replaced the original well by well number, permit number and api number: A12-01LN (permit # 94-120, API# 50-733-10081-62) permit was approved 9/29/94. A13-01LN (permit # 94-105, API# 50-733-10079-61) permit was approved 8/05/94. A14-01LN (permit # 94-119, API# 50-733-20067-61) permit was approved 9/27/94. A22-14LS (permit # 94-07i, API# 50-733-10085-62) permit was approved 5/13/94. A31-14LW (permit # 94-044, API# 50-733-20305-62) permit was approved 3/23/93. A33-1 ILS (permit # 93-180, API# 50-733-20383-61) permit was approved 11/30/93. A41-11LN (permit # 94-087, API# 50-733-20378-61) permit was approved 6/28/94. The replacement well incorporates a lateral with the existing well bore. The lateral along with the original hole will be used for production of hydrocarbons. A review of both well files indicates administrative abandonment (SQZED) of the originating well bore is appropriate according to current AOGCC procedures for wells where additional permitted laterals are drilled from an existing well bore. 20 AAC 25.005(e) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, AOGCC data bases require each conductor has only one permit number and API number. Administrative abandonment of the original permit only eliminates duplication in the databases. Information for the original well and its replacement will be maintained in their respective files. The operator has been notified of this action. new permit number, API number and well data. Statistical Technicia~~ J~//~4~L~ Reservoir Engineer ~, ,~~'~{~? Commissioner .~~~~~,..__ All future correspondence with the AOGCC should reflect the Statistical Technician ~~ Petroleum Geologist o- 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation COmmission TO: David John, DATE: Chairman.>-~ December 19, 1994 THRU: FILE NO: Blair Wondzell, P. !. Supervisor~/~ FROM: SUBJECT: John Spaulding, ,~.~.~"q Petroleum Inspector AV3LLSBD.doc BOP Test Shell "A" Shell Western E&P Middle Ground Shoals PTD 77-55 Monday December 19, 1994: I witnessed the BOP test on Shell platform rig "A", operated by Inlet Drilling Alaska Inc. The AOGCC BOP tes.t report is attached for reference. The test was conducted by George Brewster Inlet Driiling's toolpusher, he and his crew did an excellent job of testing. Inlet Drilling along with Shell Western E&P have developed a BOP test procedure. Inlet Drilling has also developed a gas detection test and calibration form that is utilized on a weekly basis. The gas detection form coincides with the AOGCC gas detection policy. Both of these items are very good tools and help provide consistency between crews. Both Shell and Inlet Drilling should be commended for their efforts, i have included a copy of each procedure with this report for review. Summary:. I witnessed the successful BOP test on Shell Rig "A" operated by Inlet Drilling, 0 failures, 5 hours. Attachment: av311sbd STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Inlet Ddlli ,n~ )Alaska Inc. Rig No. "A" PTD # Operator: Shell Western E&P Rep.: Well Name: A12-01 LN Rig Rep.: Casing Size: 5.5" Set ~ 11,915' Location: Sec. Test: Initial Weekly X Other DATE: Dec. 19,1994 77-55 Rig Ph.# 776-5756 R. Seilz G. Brewster 11 T. 8N R. 13W Meridian Seward Test Well Sign OK Drl. Rig OK MISC. INSPECTIONS: Location Gen.: OK Housekeeping: ~ OK (Gen) Reserve Pit N/A Pressure 250/3000 250 / 5000 I 250/5000 1 250 / 5000 I 250 / 50OO 250 t 5000 250 / 5000 250/5000 BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1' Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves 1 Check Valve 1 P/F P P P ,p P P P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan. 1 1 1 I ,,, Pressure 25O / 5O0O 250/5000 250/5000 250/5000 P/F P P ,p P ¥1UD SYSTEM: Visual Alarm Trip. Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors OK OK , CHOKE MANIFOLD: No. Valves 13 ~ No. Flanges 33r Manual Chokes 1 Hydraulic Chokes I Test Pressure 25015000 250/5000 Functioned Functioned P/F ACCUMULATOR ~SYSTEM: System Pressure Pressure After Closure 200 psi Attained After' Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2950 ! P 2350 P minutes 19 sec. -- minutes 55 sec. YES Remote:' YES 4 AVERAGE 265O Psig. Number of Failures 0 Test Time 5 Hours Number'of valves tested 22.. Repair or Replacement.of Failed Equipment will be made within NA days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax-No. 276-7542 Inspector North 'Slope Pager NO, 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 II · REMARKS: Excellent test! !! Distribution: odg-Well File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO I I I Waived By: W~nessed By: John H. Spaulding FI.021L (Rev. 2/93) AV3LLSBD,XLS WELL SENSOR LOCATION ii' ~zc~ n_oo~ ~o~ TEST GAS - 2 1/2 % METHANE FLOW RATE - 2 LITERS PER MIN'. - 56% LEL +- 2% G~,TAR BIlL NIPPLE PITS WEST AUDIO AI~ TE~'T II il LOW AL~ SETTING WARNING jJ % LEL HIGH AI~ SETTING AUDIO AI~ fO% LEL TEST COMPLETED BY P=PASS F=FAIL CIRCLE ONE WARNING PPM ItlGIt ~ AUDIO ~ TEST COMPLETED BY * ONLY 50 PPM TEST IS REQUIRED UNLESS RECALIBRATING IS IN ORDER. * CHECK (CAL) ONLY IF HIGH/LOW CALIBRATION WAS NEEDED. FAIItHtES, REPAIRS.: AMOUNT/COUNT OF TEST GAS USED 20 PPMAMPOULES I 50 PPM AMPOULES 100 PPM AMPOULES 1/2 % MET~ il' I · il SWEPI DRILL FOREMAN- · &t60' .~ . · · BLOW '&' PREVENTERS & ASSOCIATED EQUIPMENT TEST PROCEDURES DURING TRIP OUT TO TEST, <DON'T FILL HOLE LAST FIVE STJ~IDS. OPEN WELLHEAD ANNULUS VALVE 'TO SLOP TANK AND DRAIN BOPS. CHANGE ELEVATORS TO 5" AND PICK UP (1) JT. OF 5" DRILL PIPE. MAKE UP JT. TO 3.5" DRILL PIPE TEST PUP. TIGHTEN WITH IRON ROUGHNECK. NEED 3.5" IF X 4.5" IF CROSS OVER. BACK OUT WEAR BUSHING LOCK DOWN PINS ON TUBING SPOOL. MAKE UP WEAR BUSHING RETRIEVING TOOL ON TEST JT. WITH CHAIN TONGS. RUN IN HOLE, SCREW INTO WEAR BUSHING, PULL OUT OF HOLE. REMOVE WEAR BUSHING FROM RETRIEVING TOOL. 6. BREAK OFF RETRIEVING TOOL/TEST PLUG, TURN OVER, AND MAKE UP ON TEST JT. WITH CHAIN TONGS. MAKE UP 4.5" IF FLOOR SAFETY VALVE ON BOTTOM OF TEST PLUG, TIGHTEN WITH RIG TONGS, AND CLOSE SAFETY VALVE. e 7. CHECK SEALS ON TEST PLUG. DOPE SEALS. RUN IN HOLE WITH TEST PLUG. SET PLUG IN TUBING SPOOL AND FILL STACK WITH WATER. · PICK UP 5" PUP JT. 8' LONG AND MAKE UP ON TOP OF 5" JT. OF DRILL PIPE. TIGHTEN WITH IRON ROUGHNECK. MAKE UP TOP DRIVE TO TOP OF 5" PUP JT. AND TIGHTEN USING PIPE HANDLER. CLOSE 5" PIPE RAMS? · TEST #1: 5" PIPE RAMS, 2 OUTER MOST CHOKE VALVES, 2" KILL LINE CHECK VALVE, 4" GATE VALVES~ON MUD PUMPS, AND 4.5" SAFETY VALVE ON BOTTOM OF TEST PLUG. 10. HOOK UP 1/2" TEST HOSE TO OUTLET ON CHOKE MANIFOLD. NOTE: SECURE SAFETY CHAINS ON EACH END OF HOSE. INSTALL PAPER CHART ON PRESSURE RECORDER. START RECORDER. 11. START TEST PUMP AND PRESSURE UP TO 250 PSI. SHUT DOWN PUMP. HOLD PRESSURE FOR 5 MIN. START TEST PUMP AND BRING PRESSURE UP TO 5000 PSI. HOLD PRESSURE FOR 5 MIN. BLEED PRESSURE. 12. TEST #2: 5" PIPE RAMS, OUTSIDE 2" KILL LINE CHECK VALVE, 4" STANDPIPE VALVE, NEXT (4) INSIDE 3" CHOKE MANIFOLD VALVES, AND FLOOR SAFETY VALVE. OPEN (2) OUTSIDE 3" CHOKE VALVES). REPEAT STEP.#ll. 13. TEST ~3: 5" PIPE RAMS, OUTSIDE 2" KILL LINE VALVE, UPPER INSIDE BOP VALVE, AND 4.5" IF FLOOR SAFETY VALVE. OPEN (4) OUTSIDE 3" CHOKE MANIFOLD VALVES AND REMOVE 1/2" NPT PLUG FROM TOP OF 2" CHECK VALVE. REPEAT STEP #11. BOP TEST PROCEDURES PAGE 2 14. TEST ~4: 5" PIPE RAMS, INSIDE 2" KILL LINE VALVE, LOWER INSIDE BOP VALVE, (3) 3" CHOKE MANIFOLD VALVES, AND 4.5" FLOOR SAFETY VALVE. OPEN (3) 3" OUTSI]~ CHOKE MANIFOLD VALVES. OP~ OUTSIDE KILL LINE VALVE.~ 3PEN UPPER INSIDE BOP VALVE. %_.~PEAT STEP #11. ~ 15. BREAK OFF TOP DRIVE. BREAK AND LAY DOWN 5" 8' PUP JT. MAKE UP 4.5" IF INSIDE BOP SAFETY VALVE AND TIGHTEN WITH IRON ROUGHNECK. INSTALL~i/2" NPT PLUG IN 2" CHECk.VALVE. 16. TEST ~5: 5" PIPE RAMS, INSIDE 2" KILL LINE VALVE, (3) INSIDE 3" CHOKE MANIFOLD VALVES, AND 4.5" IF INSIDE BOP SAFETY VALVE. REPEAT STEP #11. 17. TEST #6: HYDRIL ON 5" DRILL PIPE, INSIDE 2" KILL LINE VALVE, INSIDE 3" CHOKE MANIFOLD VALVES, 4.5" IF FLOOR SAFETY VALVE. REPEAT STEP #11. NOTE; PRESSURE TEST HYDRIL TO 250/3500 PSI. 18. MAKE SURE PERSONNEL STAND AWAY FROM ROTARY TABLE AREA. OPEN HYDRIL. BREAK AND LAY DOWN 4.5" INSIDE BOP VALVE. CLOSE ANNULUS VALVE ON TUBING SPOOL. BACK OUT 5" TEST JT FROM TEST PLUG. PULL JT. OUT OF STACK WITH AIR TUGGER. CLOSE BLIND RAMS. BREAK 3.5" TEST PUP JT. OFF BOTTOM OF 5" DRILL PIPE. LAY DOWN 5" DRILL PIPE WITH 4.5" X 3.5" XO ON BOTTOM. OPEN ANNULUS VALVE ON TUBING SPOOL. 19. TEST #7: BLIND RAMS, (3) INSIDE CHOKE MANIFOLD VALVES, INSIDE 2" KILL LINE VALVE, AND 4.5" IF SAFETY VALVE. REPEAT STEP ~11. 20. PICK UP 3.5" JT. DRILL PIPE WITH AIR TUGGER AND MAKE UP ON 3.5" TEST PUP JT. TIGHTEN WITH IRON ROUGHNECK. CLEAR PERSONNEL FROM ROTARY'AREA. OPEN BLIND RAMS. RUN TEST JT. IN STACK AND SCREW INTO TEST PLUG (CHAIN TONG TIGHT). MAKE UP 3.5" IF SIDE ENTRY SUB, 3.5" IF FLOOR SAFETY VALVE, AND 3.5" IF INSIDE BOP (TIGHTEN W/IRON ROUGHNECK). HOOK UP TEST HOSE TO SIDE ENTRY SUB. CLOSE PIPE RAMS. 21. TEST #8: 3.5" PIPE RAMS, 3.5" FLOOR SAFETY VALVE, HCR VALVE, INSIDE 2" KILL LINE VALVE, AND 4.5" FLOOR SAFETY VALVE. REPEAT STEP #11. 22. TEST #9: 3.5" PIPE RAMS, 3.5" IF INSIDE BOP VALVE, 3" CHOKE VALVE, INSIDE 2" KILL LINE VALVE, AND 4.5" FLOOR SAFETY VALVE. OPEN HCR VALVE AND 3.5" IF FLOOR SAFETY VALVE.. REPEAT STEP ~11. CLEAR ROTARY TABLE AREA OF PERSONNEL. OPEN PIPE RAMS. CLOSE HYDRIL. 23. TEST #10: HYDRIL ON 3.5" DRILL PIPE, 3.5" IF INSIDE BOP VALVE, 3" CHOKE LINE VALVE, INSIDE 2" KILL LINE VALVE, AND 4.5" IF FLOOR SAFETY VALVE. REPEAT STEP #11. NOTE; PRESSURE TEST TO 250/3500 PSI. 24. TESTING ACCUMULATOR PERFORMANCE: BOP TEST PROCEDURES PAGE 3 CLEAR PERSONNEL OF ROTARY TABLE AREA. OPEN HYDRIL AND RAMS. PULL TEST PLUG LOOSE AND PUMP ALL WATER OUT OF STACK TO SLOP WATER TANK. CLOSE 2" ANNULUS VALVE ON TUBING SPOOL. REMOVE TEST PLUG AND 4.5" FLOOR SAFETY VALVE FROM TEST PLUG. TURN OVER TEST PLUG AND MAKE UP ON TEST JT. MAKE UP WEAR RING ON TEST PLUG (HAND TIGHT) AND RUN IN TO TUBING SPOOL. SCREW IN (2)/"~CK DOWN ~INS ON TUBING SPOq ~ND BACK OUT TEST JT./RE~ EVING TOOL. . PULL TEST JT./RE~,£EVING TOOL FROM STACK. REMOVE RETRIEVING TOOL FROM TEST JT. LAY DOWN TEST JT. Il Ii Il SEP ~8 '9,4 0,4:38PM SNEPI HOU 713 54,4 3304 ^,,,.,r,,,n,,u .~n In ~nl... ~,..~L/:3#Ai~.Oi~ ~1_ F b-'TATEOF ALASKA ~u. ur.,,~,.~uj', /u--~'-"'v~ FOR [ ,SKA OIL AND GAS CONSERVATION COMMI~ IN .~ A'PPLI TION FOR SUNDRY AP VALS Ot~fa~ r, nu~ck~ __ Re.entel suspended wet~ ._.. Pmgg~ng __ Tm, exte~, _., ~n~ ._.. 5. DatUm elevation (DF or KB) ' T8N, R13W, TSN, R13W, S.M. Nter casi~ __ Rel:mk ~,ell .,,_ C:nmnge aDi:~'oved program .,._ ia~ tubing ,__. _ 2. Name o(O~ramr SHELL WESTERN E&P INC. -~.~k~re~ P..O. ,BOX, 576. (WICK 5237 ) " HOUSTON, TX 77001--0576 _ 4~Loomtione~we~atsu,~moe PLATF A, LEG 1, COND 1 1632' FSL, 437' FEL SI[, Al lop o! ptoduolive inte~v',d 13,296' N & ]044' 'ti of SE' Corner $'].4, At etieclive Uepth 116 KB leel 7. Unit o~ Property n~ne H[DDLE ~ROUNrJ SHOAL 8, Well number A12-O1 ~ __ g, Permil numler 7 7. _r-,~R ......... 10, APl number 50- 733-10081-01 , , 11. FielcttPool MGS "G" POOL , ~t[p~,~l,~ iq, & 1329' E of SE Corner SL,4., TSN, R13W, $.M. .. 12, Present well C4:~n~ition summery T~I ~epth; measur~ 11,97 0 I~t Plugs (~sured) true~! 8474 f~t Efl~fi~ ~e~th: measure~ l 1 ~ 89 5 leer Junk (measured) ~,ue ~ 8414 ~t Cemented 2500 SX 400 S× z6o sx 11,768' - 8313' Casing Length Size Sffuctural C.~umor 33 O' 20" S,udace 1642' 13-3/8" Intmmedlate 1 O, 508' 7- 5/8" Production 1668' 5-1/2" Liner Pedoration depth', measured ~ O, ~9~ ~ - 7167' true vertical 14. Estimated date lot eommen~ng ~ialion "- 9/30/94 -16. I! proposel was v~;l~i~ aporov~ ..... Oil .__. Name el approver Cate apl~'OVed Se~¢e --i Z I hereby certify ',hat the !oregoing i,~ true and ~::~"r~eu'l lo IbC lest O! my knowledge. ' I -~ - -- __ .7' FOROOMMI$$1ON U~£ ONLY ¢ondilions gl approval: Notify Oommisaion so represenl~tive mag wilness · Plug integrity .,1L, BOP Test _,_ Localion cleararH:e ~ MeChanical lnlegrity Te~ ~ Subsequenl form required 10,_/./c5 7 RIGINAL Measured depth True vertical depth 330' 330' 1642' 1642' Approved lay order gl the Commission Form 10-403 Rev O6/15/88 10,$08' T~337 ' ,,?oREEEIV£IF474' SEP 2 8 1994 ktaska 0il & Gas Cons. Commission Anch0ra~ls EUE 8RD~ ~8,164' EUE 8RD @ ,164-11,230' RUE 8RD ~ 11,2'25' 10,,~55' - GUIB UNI'PKR VII ~ 1067] 10,580' ~UIB UNI-PKR VIi 1092 .,. Q~_ Suspended ~ .,,. ~ · ............ Original Signed David W. Johnstor commingle, D_.ate 9/23/ .... SUBMIT IN TRIPLI~.TE - 43 - Approved Copy Returned 5~-' ~1 '94 04:39PH SNEPI HOU ?i3 544 3304 (- P. 3,'3 MIDDLE GROUND SHOAL WELL A12-01 ABANDONMENT OF RESERVOIR ZONE Plan Abandon the "G" Pool by setting a gement retainer above the zone and squeez£ng cement down the tubing. Procedure 1. Move rig over conductor 1, leg I and rig up. 2. Use wireline to cut the tubing at 10,140t MD-KB. Circulate brine and kill the well. 3. Nipple up BOP's. 4. Pull the tubing and lay down. 5. Clean out with a bi= and scraper to 9,500' MD-KB. 6. Set a cement retainer @ 9,480' MD-KB on wireline. 7. GIH with a stinger and bullhead 200 sacks of cement below retainer and into the tubing. 9. 10. POOH and' pressure test casing, to 2,000 psi. GIH with a whipstook and set @ cement retainer top. Kickoff @ 9,480t MD-KB. Shell Western E&P Inc. O 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, TSN, RI3W) 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 C21-23. 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\06 ! 190. DOC REC. EIVED Alaska Oil& Gas Cons. Comn~[~l1 i MIDDLE GROUND SHOAL P1 atform "A" WELL/CONDUCTOR LOCATIONS Leg i - Center of Leg i @ 1627'N & 435'W from SE corner of Sec.11, T8N, R13W, S.M. . A 12-01 I 1632'N '& 437'W from SE corner A 11-01 2 1632'N & 432'W " " " A 43-11 3 1630'N & 430'W " " " A 34-11 4 1625'N & 430'W " " " A 34-14 RD 5 1622'N & 433'W " " " A 22-14 6 1622'N & 437'W " " " A 12A-01 7 1625'N & 440'W " " " A 13-01 8 1630'N & 440'W " " " Leg 2 - Center of Leg 2 @ 1681'N & 372'W from SE corner of Sec. 11, T8N, R13W, S.M. A 42-11 9 1685'N & 374'W from SE corner A 44-02 10 1685'N & 370'W " " " A 42-14 11 1683'N & 368'W " " " A 41A-11 12 1678'N & 368'W " " " A 11-12 13 1675'N & 371'W " " " A 11-13 RD 14 1675'N & 375'W " " " A 31-14 15 1678'N & 378'W " " " A 44-11 16 1683'N & 378'W " " " Leg 3 - Center of Leg 3 @ 1620'N & 321'W from SE corner of Sec. 11, T8N, R13W, S.M. Leg 4 - Center of Leg 4 @ 1566'N & 383'W from SE corner of Sec.11, T8N, R13W, S.M. A 33-11 25 A 14-01 26 1571 A 12-12 27 1568 A 24-01 28 1564 A 13-12 29 1561 A 33-14 30 1561 A 41-11 31 1559 A 23-01 32 1571'N & 385'W from SE corner N & 381'W " " " N & 378 ' W " " " N & 378'W " " " N & 381'W " " " N & 385'W " " " N & 388'W " 1569 N & 388'W ~\k~sl(~ Oil & Gas Cons. commission Anchora~ SBBC/mgs A I Tglq S.M. I I I ! ADL 18754 ~ .: - LAT. ~ PLATFORm! LOC~TIO t ,' ' ¥ · 2,4e$,840 ·. ' 1623.5' ,,, .,, , ,~ ...... ? ; · 21 33 34 35 36 31 32 EEEIV, t D. --. · ~Jasi~a ~il & Gas con.s. ( ~mmission P R O D U C I N 0 P L :,T F O ~ M ...... T 8 N S.M. _ , Ancliorag~ SHELL MIDDLE GROUND SJ-.IOAL ,j, T.~7:N S.M., 2 , PLATFORM "A ,--,, COOK INLET. ALA,.,,,A j- 4000 eooo ~2oo0 APPLIC&TION BY SHELL OIL CO. .... :_.z-'--,--~ ........ "--- ' LOS ANG[LES, CALIFORNIA : SCALE IN FEET .- I0 T. 8 N., R.13 W., S.M. II I 14 I0 LEG NO. I LEG NO. PL X = 232,7B:5 X= 232,84'6 Y = 2,485,84.5 Y = 2,4'85,897 16 2 7' I'1 !~ 435' W FROM THE SE COR. OF SEC. II,TSN, RI;SW, SM. LEG NO. C 00/?DINA T£S X= 232,896 Y = 2,485,835 LEG NO. 4 PUBLIC LAND 1681' N a 37Z' W FROM THE SE COR. OF SEC. II, T8N, RISW, SM. DE$ Ct?'I P T./ON 1620'N 'a 321' W FROM THE SE COR. OF SEC. Ii, TSN, RI3W, SM. X = 2 32,833 Y = ?.,485,783 1566'N a 383'W FROM THE SE COR. OF SEC. ll, TSN,RI3W, S.M. GEODETIC COOl?DINA TES LAT.- 60°47'44.839'' LAT.-60047'45.368" LAT.-60°47'44.7G8'' LAT.- 60047'44.244" LONG.- 151° 29'45. 112'', LONG.-151°29' 43.942" LONG.-151°29' 42.'899'' LONG.-151° 29' 4 4.154" ~':=::~:~~.~"~e".-2~'~.~ -F....~.F--~--~ =- . - .a~,~,'z, - - '~.- - ' - - ' : - ·~ .'-¢g,~ . . - _ .': Ci[~P'AVr'N I;'! H.A.D. ~I ~.,~J :! .,:,:: I SCALE I::,~ I000' , -- .~ .._ ~.. --,,.-... - ,~.c,,.~ ~.Y ~.,,.,--. u ELLOIL Z- Ii ,,,,~ ,.,~.~ ,~., ,~,~ i! I! 41 0- 2 t - - _ -~ .-_. -_ ;, -'Lm~._. = . _ - - -'- - ; : - - -' -~-"~ - . -- - - - -' ~1 . LOCATIO~u OF Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 October 26, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: SUBJECT: SUBMISSION OF REPORT OF SUNDRY WELL OPERATIONS FOR MIDDLE GROUND SHOAL WELL A12-01 Enclosed in duplicate, is the Report of Sundry Well Operations for Middle Ground Shoal producer A12-01. The stimulation was performed on October 7, 1987. If you have any questions, please contact Susan Brown at (907) 263-9613. Very truly yours, Wayne F. Simpson Manager Regulatory Affairs WFS/SBB/kma RECEIVED OCT 2 ,,,'~' i,':!i~i'~ ? A!ask~ 0il & Gas Cons. Commission Anchorage SBBG/roswo.1026 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~i¢ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P I nc. 116' Feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 7. Well number A 12-01 4. Location of well at surface Platform "A", Leg 1, Conductor 1, 1632'N & 437'W of SE c~rner o( 5cc. 11. T8N. R13W, S.N. t top of productive interval At effective depth At total depth 8. Approval number 7-761 9. APl number 50-- 733-10081-01 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Structural Conductor Surface 1,642 ' Intermediate Production 10,508' Liner 1,678' Perforation depth: measured 10,292-11,768' true vertical Size Cemented 13-3/8", 53.5# 2500 sx 7'5/8",. 33.7 & 29#, N'80 5'1/2",17#, N-80 11 intervals Tubino (size, grade and measured depth) 2-7/8", 6.5#, N-80 EUE, 8rd to 10,164' 2-3/8", 4.7#, N-80 EUE, 8rd 10,264' to 11,230' Packers and SSSV (type, and me~sured dept,)t~J;Q_ ,~ -~ Packers at 10,155 , 10,580 , 10,677 , 1.0,923 , 11,230' Measured depth True Vertical depth 1,642' 10,508' 10,302-11,980 ' Gas Cons. c0mmiss) m Anchorage 12. Stimulation or cement squeeze summary Acid Washed tubing W/CTU and 1000 gal of 15% HCl. Circulated out acid W/115.5 bbl of diesel. Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 37 0 186 650 125 Shut in due to stuck wireline tool. 14. Attachments Daily Report of Well Operations XE] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~~1~ Form 10-40;4'R~ev. 1'~-1-85 - SBBG/r oswo. 1026. a TitleProduction Superintendent Date Submit in Duplicat~~ DAILY JOB SUMMARY DATE: WELL NO: OPERATION: 10/07/87 A12-01 STIMULATE BY ACID WASH OF TUBING Acid washed tubing with coiled tubing unit and 1000 gal of 15% HC1. Circulated out acid with I15.5 bbl of diesel and well production fluid. NOTE: Following this job, wireline work was attempted and the tool was stuck. SBBG/1026 A(,~A STATE OFALASKA O~I'' AL OIL AND GAS CONSERVATION C 'MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) She11 Western E&P I nc, 116' feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4..Lo.cation,~J, w~ll at surface 7. V~el~ 2n.~ber ~'latrorm 'a , Leg 'I, Con~luctor 1, 1632'N & 437'W of SE - corner of Sec. 11, T8N, R13W, S.M. At top of productive interval At effective depth At total depth 8. Permit number 77-55 9. APl number 50_733-10081-01 10. Pool · "G" Pool 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Structural Conductor Surface 1,642' Intermediate Production 10,508' Liner 1,678' Perforation depth: measured 10,292-11,768' true vertical Size Cemented 13-3/8", 53.5# 2500 sx 7-5/8", 33.7 & 29#, N-80 5-1/2", 17#, N-80 11 intervals 1,642' 10,508' 10,302-11,980' Tu 'n jze g d a I~.¢/~, 6.1~$, eN_~ ~nl~,s,~rr~dtdoel~t0h,)164, 2-3/8", /+.7#, N-80 EUE, 8rd 10,264' to 11,230' Packer. s and SSSV (type and measured depth) packers at 10,155', 10,580', 10,677', 10,923', 11,230' Measured depth True Vertical depth RECEIVE1) Alas~:a Oil & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal I~X Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation OCTOBER 18, 1987. 14. If proposal was verbally approved Name of appro~'~) Date approved 15. I hereby~/~r~..~J;~t t/~ forego~,,~ is true and correct to the best of my knowledge Signed /r////~...~,~/~~ Title Production Superintendent Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test ,Fl Location clearanceI Approved by No. by order of Commissioner the commission Date ~" =orm 10-403 Rev 124-85 SBBF/asa. 1015 Submit in triplicately._ Page 3 PROGNOSIS A12-01 OPERATION- Acid treatment to loosen wireline tools currently stuck downhole. TUBING' See attached completion equipment detail sheet. PERFORATIONS' See attached completion equipment detail sheet. STATUS' Shut in PROCEDURE' OCT i 6 Oil & G~s ConS. Commiss~o~ Anchorage · RU and tie into flow line. Test acid for strength by titration method. Pressure test surface equipment to 3000 psi. e Dead head 300 gal of 15% HCl down swab valve. Displace with filtered injection water. e After all acid is displaced, place well on production. 4~ RIH with wireline tools to retrieve stuck tools. Continue with wi rel i ne work. NOTE- Monitor and treat for proper PH at Onshore facility. SBBF/asa. I015a APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate 1~' Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KBi Shell Western E&P Inc. 116' 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface Platform "A", Leg 1, Conductor 1, 1632'N & 437'W of SE corner of Sec. 11. TSN. RI~W, S.M. At top of productNe ~n[erva~ At effective depth At total depth 7. Well number A 12-01 8. Permit number 77-55 9. APl number 50--733-10081-01 10. Pool "G" Pool feet 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1,642' 13-3/8", 53.5# 2500 sx 10,508' 7-5/8", 33.7 & 29#, N-80 1,678' 5-1/2", 17#, N-80 measured 10,292-11,768 ' 11 intervals true vertical 1,642 ' 10,508' 10,302-11,980' Tul~ir~8{~ize. orade' and measured depth) , 6.5#, N-80 EUE, 8rd to 10,164' 2-3/8", 4.7#, N-80 EUE, 8rd 10,264' to 11,230' Packers and SSSV (type and measured depth) packers at 10,155', 10,580', 10,677', 10,923', 11,230' Measured depth True Vertical depth OCT 0 6 i987 0it & 6as Cons. Commission 12.Attachments Description summary of proposal [] Detailed operations program '~ BOP sketch [] 13. Estimated date for commencing operation OCTOBER 7, 1987o 14. If proposal was verbally approved Name of appr~ Date approved 15. I here,~.~e~//~h~,~th_e f. or~g~ing is true and correct to the best of mY knowledge Signed /'f~].._~ ~/~~__~,¢~ Title Production Superintendent Conditions of approval Approved by / Commission Use Only Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearanceI Approval No. ~ .., ~? ~,.,,/ ..... ~:'~ ~, ~I~ Commissioner by order of .... -'~) ~ ~ '~~ the commission Date/ ~ 0 /~ Submit in triplicate¢ Form 10-403 Rev 12-1-85 PLATFORM "A" WELL TEST DATA Al2-1 INJ PROD PSI PSI PSI DATE GROSS CUT CLEAN MCF MCF GOR /64 TUB CAS GRAV SEP 1/1 256 50.0 128 858 93 727 128 80 810 20.0 61 1/8 346 44.0 194 1018 75 387 128 90 720 20.0 64 1/20 352 44,0 197 1197 0 0 128 90 730 20.0 67 1/28 354 44.0 198 1237 17 86 128 90 730 20.0 64 2/6 348 46,0 188 1157 57 303 128 90 730 20.0 63 2/14 350 44.0 196 1157 57 291 128 90 725 20.0 62 3/3 344 46.0 186 1037 55 296 128 90 725 20.0 65 4/20 148 76.0 36 1456 21 591 128 100 820 20.0 60 5/8 172 76,0 41 1197 118 2859 128 90 790 20.0 65 5/27 172 76.0 41 1097 36 872 128 90 800 20.0 68 6/9 180 68.0 58 1289 0 0 128 100 810 20.0 6/22 PULL AND CLEAN OUT GLV #6, BOTTOM ORIFICE. 6/23 306 54,0 141 1417 203 128 110 615 6/27 300 64,0 108 1895 0 0 128 110 595 20,0 7/8 306 60.0 122 1676 0 0 128 100 600 7/11 SI FOR COMPRESSOR WORK. 7/16 226 68.0 72 1796 25 346 128 110 7/27 254 60,0 102 1736 0 0 128 100 8/1 252 56.0 111 1756 0 0 128 100 8/31 258 58.0 108 1676 0 0 128 100 9/8 262 62.0 100 1616 0 0 128 100 9/17 257 60.0 103 1596 0 0 128 100 9/20 258 58.0 108 1535 0 0 128 100 10/16 266 60.0 106 1249 0 0 128 100 11/5 352 52.0 169 1557 0 0 128 100 11/13 352 48.0 183 1556 49 268 128 110 11/22 356 54.0 164 1580 5 31 128 110 12/01 354 54.0 163 1606 14 86 128 110 12/8 360 52.0 173 1616 23 133 128 110 1/7/87 360 52.0 173 1561 22 127 128 120 600 2/10 236 54.0 109 1617 62 571 128 110 860 2/15 368 54.0 169 1677 43 254 128 125 600 3/03 240 50.0 120 1714 66 880 128 130 890 3/12 362 54.0 167 1687 33 198 128 130 610 3/28 352 52.0 169 1719 21 124 128 135 595 4/6 354 50.0 177 1804 73 412 128 120 4/15 348 50.0 174 1693 3 17 128 140 4/29 340 52.0 163 1702 0 0 128 120 5/9 336 50.0 168 1620 0 0 128 130 5/18 334 54.0 154 1648 0 0 128 120 5/29 332 52.0 159 1665 0 0 128 120 6/19 334 54.0 154 1767 0 0 128 130 7/7 326 58.0 137 1727 0 0 128 130 7/17 326 60.0 130 1691 0 0 128 110 7/26 324 52.0 156 1696 0 0 128 125 8/04 322 56.0 142 1738 0 0 128 120 8/12 318 54.0 146 1735 0 0 128 120 8/20 318 54.0 146 1748 0 0 128 125 8/30 314 56.0 138 1741 0 0 128 120 9/23 232 80.0 46 1700 0 0 128 125 830 500 20.0 500 64 500 20.0 63 490 20.0 65 500 20.0 64 490 865 20,0 590 20.0 63 590 20.0 590 20,0 600 20.0 65 585'20,0 65 20,0 2°'° E EIVE OCT 0 6 ? 6 0 0 A~,a6 0 0 811 & A~l~orageGas Cons, Commissio: 600 20.0 615 20.0 605 620 20.0 600 78 610 610 20.0 76 600 20.0 76 595 20.0 600 20.0 590 20.0 595 20.0 650 20.O PROGNOSIS AI2-OI OPE_R_AT_I_O~- COILED TUBING ACID TREATMENT TO REMOVE SCALE PROM TUBING CURRENTLY PREVENTING REPLACEMENT OF GAS LIFT VALVES 5 AND 6. REPLACE VALVES 5 AND 6 AS SPECIFIED BY ANCHORAGE PRODUCTION ENGINEER. T_.U_B_I_NG_: SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET PERFORATIONS: SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET ~~: PRODUCING 109 BO + 127 BWPD INJ. 1617 MCFPD 2/10/87 NOTE:I. THE MINIMUM RESTRICTION IN TUBING IS 1.8'/5 .... X"- NIPPLE AT !]160' . 2. AVOID GETTING ACID ON FORMATION BY KEEPING WELL LIFTING THROUGHOUT OPERATION. DO NOT ALLOW WELL TO LOAD UP. ].RU COILED TUBING UNIT AND PUMPING EQUIPMENT. BULLET NOSE WASH NOZZLE IS TO BE SECURED TO ] 1/4" COILED TUBING WITH SWEDGE LOCK OR ALLEN SCREW CONNECTOR. WASH NOZZLE IS NOT TO BE THREADED ON DIRECTLY TO COILED TUBING. TEST ACID FOR STRENGTH BY TITRATION METHOD. PRESSURE TEST ALL SURFACE EQUIPMENT FROM THE PUMP DISCHARGE TO THE WELL HEAD TO 3000 PSI. 2. IF COILED TUBING CONTAINS DIESEL RIH. IF COILED TUBING CONTAINS ANTI-FREEZE DISPLACE ANTIFREEZE ~!TH DIESEL BEFORE RI~. MAINTAIN AT LEAST lO00 PSI O~ COIL ~SING DIESEL W~ILE RIB. HAVE PRODUCTION OPERATOR PUT WELL IN TEST AND MONITOR THROUGHOUT OPERATION. IF WELL STOPS LIFTING. DISCONTINUE PUMPING AND ALLO~ WELL TO UNLOAD. 3. AT 8800' STOP TUBING AND BEGIN PUMPING THE FOLLOWING ACID AT 0.5 BPM' 1000 GALLONS 15~ HCL CONTAINING 1~ A250 AND 1~ U-66 (DOWELL) 4.WHEN ACID REACHES THE END OF COILED TUBING, RIH AT 80 FPM TO EOT AT 11230'. AT EOT, COKTINUE PUMPING AT 0.5 BPN AND COME OUT OF HOLE AT 80 FPN. KEEP WELL FLO#I~G. IF NECESSARY, STOP PUMPING AND ALLOW WELL TO UNLOAD. MAKE SURE SUFFICIENT ACID IS SPOTTED ACROSS MANDRELS AT 9865' AND 10118'. 5.AFTER ALL ACID IS PUMPED, DISPLACE COIL WITH DIESEL AND RD. 6. IF WELL DOES NOT LIFT DOWN WHICH WILL BE INDICATED BY INCREASE IN PRODUCTIO~ A~D A DECREASE IN CASING PRESSURE BELO# 8OO PSI, ADDITIONAL GAS LIFT WORK IS NECESSARY. PULL AND REPLACE THE CURRENT GAS LIFT STRING WITH THE ATTACHED DESIGN. DATE: / 5 6 7 8 9 ~.10 11 12 13 14 15 16 17 18 19 20 21 COMPLETION EQUIPMENT[ MGS A12-%, 8/11/87 I L StiEET NO. ITEM APPROXIMATE TVD. MD. PSI OR ]. OTIS XEL LANDING NIPPLE (2.313"1D) 2. KBMG MANDREL #1 (2.395"ID) 3. KRMG MANDREL #2 (2,395"]!)) 4. KBMG MANDREL #3 (2.395"ID) 5. KBMG MANDREL #4 (2.395"]D) 6. KRMG MANDREL #5 (2,395"ID) 7. KIIMG MANDREl, #6 (2.395"11)) 3]3 3]3 1647 1647 955 3/16 3425 3753 950 3/16 4785 6217 945 3/16 5661 7823 975 1/4 6860 9865 I)UMM¥ 7039 10118 OR ]/4 8. GUIB UNI-PACKER VII (2.438"ID) 7066 10155 9. 2 7/8" X 2 3/8" X-OVER (1.994"ID) 707] 10104 lO. KBH(; MANDREL #7 (1.901"II)) 7239 10383 DUMMY 11. GUIB UNI-PACKER VII (1.938"ID) 7396 ]0580 12. KBMG MANDREL #8 (l.901"II)) 7422 10613 DUMHY 13. GUIB UNI-PACKER VII (1.938"ID) 7473 10677 14. KBMG MANDREL #9 (I.90I"ID) 7513 10727 DUMMY 15. GUIB UNI-PACKER VII (1.938"ID) 7665 10923 16. KBMG MANDREL #]0 (1.901"ID) 7720 10995 I)UMMY 17. OTIS "X" NIPPLE (1.875"ID) 7845 11160 18. 2 3/8" X 2 7/8" X-OVER (1.994"ID) 7894 11225 19. 2 7/8" I.,ANDINO SEAl, NIPPLE (2.375"ID) 7895 11227 20. SEAl, UNIT (2.375"ID) 7898 11230 21. 5 1/2" GUIB MAGNUM G (3.00"ID) 7898 11230 CASING 13 3/8", 54.5#, .1-55 @ 1642' w/2500 sx 7 5/8", 33.7#, N-80 @ 10508' w/400 sx 5 1/2", 17#, N--80 LINER @ ]0302--11970' w/200 sx PBTD = 11,970' TD = 12,000' TUBING 2 7/8", 6.5#, N-80 EUE 8RD @ 10164' 2 3/8", 4.7#, N-80 EUE 8RD @ 10164-11230' 2 7/8", 6.5#, N-80 EUE 8RD @ 11225' PERFORATED ZONE GROSS INTERVAL GR-GS 10292-10350 HC-IID 10619-10675 HC-HD 10686-10740 HE-HF 10776-10819 HI-HK 10882-10888 HI-IlK 10900-10922 IIK-HN 10947-11225 HN-IIR 11250-11313' HN-HR 11319-11301' lIN-fIR 11375-'11556' HR-HZ ]1570-]1690' IIR-IIZ 11716-11768' August 4, 1987 Shell Westem E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT- APPROVED STIMULATION OF MIDDLE GROUND SHOAL WELL A 12-01 (APPROVAL #7-113) Gentlemen' In a recent telephone conversation with Susan Brown (SWEPI), John Boyle (AOGCC) requested information on the status of the approved stimulation of MGS A 12-01 that was approved in February, 1987. Our operations people have informed us that the work has been postponed. Accordingly, enclosed, in duplicate, is the 10-404 form/Report of Sundry Well Operations for that stimulation. We understand that if the stimu- lation is to be performed at a later date we will have to submit a 10-403 form (Application for Sundry Approval). If you have any questions, please contact Susan Brown at (907) 263-9613. truly yours, ~h Manag/~r Regulatq/ry Affairs A1 ask~a Division~ SBB/kka EnClosure RECEIVED AUG Rlaska Oil & Gas Cons. Commission Anchorage SBBF/aogcc. O3f /~,¢' STATE OF ALASKA ~ AL A OIL AND GAS CONSERVATION CO .iSSlON REPORTOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P Inc. 116' KB Feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface Platform "A", Leg 1, Conductor 1 1632'N & 437'W of SE corner of Sec 11, TSN,R13W, S.M. At top of productive interval At effective depth At total depth 7. Well number A 1 2-01 8. Approval number 7-113 9. APl number 50-- 733-1 0081 -01 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural Conductor 1 ,642 ' Surface Intermediate Production 1 0,508 ' Liner 1 ,678 ' Perforation depth: measured Size Cemented Measured depth 13-3/8", 53.5# 2500sx 1,642' 7-5/8", 33.7 & 29#, N-80 5-1/2", 17#, N-80 10,292'-11,768' I 1 interval s true vertical True Vertical depth 10,508' 10,302'-11,980' Tubing (size, grade and measured depth) 2-7/8" ~.5#, N-80 EUE, 8rd to 10,164' Packers ~n,_, SSSV (type and measured depth) ; 2-3/8", 4.7#, N-80 EUE, 8rd 10,264'-11,230' packers @ 10,155'; 10,580'; 10,677'; 10,923'; 11,230' 12. 13. Stimulation or cement squeeze summary Intervals treated (measured) The job has been postponed. Treatment description including volumes used and final pressure RECEIVED AUG 1 0 1987 Representative Daily Average Production or Injectio~'~'~ .... ~h~rage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form i'0-404 SBBF/roswo.03f Title Production Superintendent Date 8/5/87 Submit in Duplicate February lg, 1987 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99,501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' :. SUBJECT' UPCOMING WORKOVER ON MIDDLE GROUND SHOAL (MGS) WELL A 12-01 Enclosed are three copies of an Application for Sundry Approval to Perform a workover on MGS well A 12-01. The workover will involve coiled tubing acidizing of the well to remove scale and, if necessary, replace gas lift valves. The work will begin as soon as approval is obtained. If you have any questions regarding this application, please contact Susan B. Brown at (907) 263-9613. Very truly yours, i ~ana~7', Re§ulall:ory ^flairs , SBB/kka Enclosures RECEIVED FEB 2 4 t337 Alaska Oil & Gas Cons, SBBE/aogcc.01 f STATE OF ALASKA I~ ALASKA OIL AND GAS CONSERVATION COM ,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P Inc, 116' feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 7. Well number A 12-01 4. Location of well at surface Platform "A", Leg 1, Conductor 1, 1632'N & 437'W of SE A~orner ~f Sec..ll,.T~N, E13W, S.M. lop ofproouctlv~ interval At effective depth ,, At total depth 8. Permit number 77-55 9. APl number 50-- 733-10081-01 10. Pool 'tGi' Pool 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1,642' 13-3/8", 53.5# 2500 sx 10,508' 7-5/8", 33.7 & 29#, N-80 1,678' 5-1/2", 17#, N-80 measured 10,292-11,768 ' 11 intervals true vertical Tubino (size, grade and measured depth) 2'-7/8", 6.5#, N-80 RUE, 8rd to 10,164' P 2-3/8" 4.7#, N-80 RUE, 8rd 10,264' to 11,230' ackers and' SSSV (type and measured depth) packers at 10,155', 10,580', 10,677', 10,923', 11,230' Measured depth True Vertical depth 1,642' 10,508' 10,302-11,980' RECEIVED 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation AS SOON AS APPROVAL IS OBTAINED. 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,,/~,~1~.¢-.. -~""'_~ Title Producti on Superintendent Commission Use Only Date ;;Z//~ ~'/~"7 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance .... '""" ............. ' ....................... '~missioner IApproval No. ~--/? ..~ by order of the commission Date Form 10-403 Rev 12-1-85 FORMS/0216 Submit in triplicate PLATFORM 'A" WELL TEST DATA Al2 DAT l/1 1/8 I/2 1/2 2/6 2/1 3/3 4/2 5/8 5/2 6/9 6/2 6/2 6/2 7/8 7/1 7/1 7/2 8/1 8/3 9/8 9/1 9/2 10/ 11/ ]1/ 11/ 12/ 12/ 1/7 2/1 -1 INJ E GROSS CUT CLEAN NCF 0 8 4 0 7 2 3 7 1 SI 6 7 1 7 0 16 5 ]3 22 O~ 8 /87 0 256 50.0 128 858 346 44.0 194 1018 352 44.0 197 1197 354 44.0 198 1237 348 46.0 188 1157 350 44.0 196 1157 344 46.0 186 1037 148 76.0 36 1456 172 76.0 41 1197 172 76.0 41 1097 180 68.0 58 1289 PULL AND C 306 54.0 300 64.0 306 60.0 FOR COMPR 226 68.0 254 60.0 252 56.0 258 58.0 262 62.0 257 60.0 258 58.0 266 60.0 352 52.0 352 48.0 356 54.0 354 54.0 360 52.0 360 52.0 236-54.0 PROD PSI MCF GOR /64 TUB 93 727 128 80 75 387 128 90 0 0 128 90 17 86 128 90 57 303 128 90 57 291 128 90 55 296 128 90 21 591 128 100 118 2859 128 90 36 872 128 90 0 0 128 100 BOTTOM ORIFICE. 203 128 110 0 0 128 110 0 0 128 100 LEAN OUT 6LV #6, 141 1417 108 1895 122 1676 ESSOR WORK. 72 1796 102 1736 111 1756 108 1676 100 1616 103 1596 108 1535 106 1249 169 1557 183 1556 164 1580 163 1606 173 1616 173 1561 109 1617 25 346 128 110 0 0 128 100 0 0 128 100 0 0 !28 100 0 0 128 100 0 0 128 100 0 0 128 100 0 0 128 100 0 0 128 100 49 268 128 110 5 31 128 110 14 86 128 110 23 133 128 110 22 127 128 120 62 571 128 110 PSI PSI CAS GRAV SEP 810 20.0 61 720 20.0 64 730 20.0 67 730 20.0 64 730 20.0 63 725 20.0 62 725 20.0 65 820 20.0 60 79O 20.O 65 800 20.0 68 810 20.0 615 595 20.0 600 830 500 20.0 500 64 500 20.0 63 490 20.0 65 500 20.0 64 490 865 20.0 590 20.0 63 590 20.0 590 20.0 600 20.0 65 585 20.0 65 600 20.0 860 20.0 PROGNOS I S ........ OPERITION: COILED TUBIN6 ACID TREATNENT TO RENOVE SCALE FRO~ TUBING CURRENTLY PREVENTING REPLACEMENT OF GAS LIFT VALVES 5 AND 6. REPLACE VALVES 5 AND 6 AS SPECIFIED BY ANCHORAGE PRODUCTION ENGINEER. TUBING: SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET PERFORATIONS: SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET STATUS: PRODUCING 109 BO + 127 BWPD INJ. 1617 MCFPD 2/10/87 PROCEDURE: NOTE:]. THE MINIMUM RESTRICTION IN TUBING IS 1.875 .... X"- NIPPLE AT 11160' 2. AVOID GETTING ACID ON FORMATION BY KEEPINO WELL LIFTING THROUGHOUT OPERATION. DO NOT ALLOW WELL TO LOAD UP. I.RU COILED TUBING UNIT AND PUMPING EQUIPMENT. BULLET NOSE WASH NOZZLE IS TO BE SECURED TO 1 1/4" COILED TUBING WITH SWEDGE LOCK OR ALLEN SCREW CONNECTOR. WASH NOZZLE IS NOT TO BE THREADED ON DIRECTLY TO COILED TUBING. TEST ACID FOR STRENGTH BY TITRATION METHOD. PRESSURE TEST ALL SURFACE EQUIPMENT FROM THE PUMP DISCHARGE TO THE WELL HEAD TO 3000 PSI. 2. IF COILED TUBING CONTAINS DIESEL RIH. IF COILED TUBING CONTAINS ANTI-FREEZE DISPLACE ANTIFREEZE #!TH DIESEL BEFORE RIH. MAINTAIN AT LEAST 1000 PSI ON COIL USING DIESEL WHILE RIH. HAVE PRODUCTION OPERATOR PUT WELL IN TEST AND MONITOR THROUGHOUT OPERATION. IF WELL STOPS LIFTINO, DISCONTINUE PUMPING AND ALLOW WELL TO UNLOAD. 3. AT 8800' STOP TUBINO AND BEGIN PUMPING THE FOLLOWINO ACID AT 0.5 BPM: 1000 GALLONS 15~ HCL CONTAININO l~ A250 AND 1~ U-66 (DOWELL) 4.WHEN ACID REACHES THE END OF COILED TUBING, RIH AT 80 FPM TO EOT AT 11230' AT EOT, CONTINUE PUMPING AT 0.5 BPM AND COME OUT OF HOLE AT 80 FPM. KEEP'WELL FLOWING. IF NECESSARY, STOP PUMPING AND ALLOW WELL TO UNLOAD. MAKE SURE SUFFICIENT ACID IS SPOTTED ACROSS MANDRELS AT 9865' AND 10118'. 5.AFTER ALL ACID IS PUMPED, DISPLACE COIL WITH DIESEL AND RD. 6. IF WELL DOES NOT LIFT DOWN WHICH WILL BE INDICATED BY INCREASE IN PRODUCTION AND A DECREASE IN CASING PRESSURE BELOW 800 PSI, ADDITIONAL GAS LIFT WORK IS NECESSARY. PULL AND REPLACE THE CURRENT GAS LIFT STRING WITH THE ATTACHED DESIGN. DATE: DATE: 2.---/Z -~7 11 12 13 14 3, 4. 5, &. 7, 8. 9. lo. 11. 12. 13. 14. 15. 16. 17. 18. {9. COPI~ETI~ EI~.IIPI~E~ DETRIL SHEET WGS AlE-el · · ,[TEIq WIN ID OTIS xEL I_q~IN6 NIP. PIE 2.313 ~ 7/8" ~ NRI~REL 4il 2,395 ~ 7/8" KBI~ ~REL 02 2,395 2 7/8' KDP,6 ~l~'X. 03 2.395 ~ 7/8' KBI~3 flGb~REL 04 fL 395 2 7/8' KBNB MRNDREL 05 L~,395 2 7Z8' 395 7 5/8" 438 2 7/8' 994 2 3/8" 981 Id/ EK EGLgU..IZII~ DUMMY 5 l/E" 6UIB UNI-VI I (88892) I, 938 2 3/8' KIqBG I~INDREL 1.991 Id/ EK E(~.Id:LIZING ~ 5 1/2' 6UIB UNI-VII(8889;~)I.938 2 3/8' ~ I~NI)REL 1.98! Id/ EK EDUPIIZING DL.M~ 5 1/2' 6UIS U~I-¥I ! (80892) 1.938 2 3/8' KBI~B J~NDREL 1,901 #/ EK EOUPd_IZII~3 ~ 2 3/8" OTIS 'X' NIPPLE 1.875 2 3/8' x ;' 7/8' X-OVER 1.994 2 7/8' LP. NDIN~ SE~I. 2.375 NIPPLE (83336) S~{:L UNIT (82689) 2. 375 LERD-IN SUB (83074) 2. 375 5 I/2"6UIB I~BNUM KDI~ Wd:~DREL 06 6UIB UNI-VI I (69999) 2, 3/8" X-I)q~R 1, ~ HP, NDREL 1. 313 1647 3753 6,?.17 7&?.3 9865 10118 18155 10164 10383 10580 IE~13 18677 1e727 10923 10~:~ 11169 -IIL:~5 11227 11239 11239 11230 16 17 18 19 2O 21 '22 CRSII~ · 7 5/8', 33.7-;..:'9-33.74{~ N-80 ~ 10508' 5 1/2'~174{,N-80 LINER FRON 10302-11980' TIJBINB 2 7/8'~ 6.51~ N-80 EUE~8~d to 10164~ 2 3/8'~ ~o ?It~ N-80 E1JE~ 8~d 152~~ to 11:=3d}~ PERFDR~TED ZONE GR-GS HC-HD (1) HC-HD (2) Hi.(-HN HR-HZ 10882-10888 11250-11361 11570-11690 Top 10£'92-103,'.~ 10618-10675 10686-10740 (SQUEEZED) 10776-10819 10900-109~2. 10947-11~5 11375-11556 11716-117£8 Page 28 Shell Oil Company 200 North Dairy Ashford P. O. Box 527 Houston, TX 77001 August 3, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gen tl emen' Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell's Middle Ground Shoal Well No."A-12-1 and Seal Island Well No. BF-47. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH: mh Attachment ' [ STATE OF ALASKA £ //~ , ALASK/~ ,L AND GAS CONSERVATION C~MMISSION ! ~..~. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATI #S/ Drilling well [I/IX 2. Name of operator Shell Oil Compan.y 3. Address 601 !,lest 5th St., #8113, Anchoraoe, AK 995nl 4. Location of Well at surface 1625'N & 440'1,! from SE Corner Sec. 11, T8N, R13W, SM. 5. Elqv~tj-Oln i~loJ, eet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. /lb 18754 7. Permit No. 83-106 8. APl Number so- 733-20367 9. Unit or Lease Name 10. Well No. A-12A-1 11. Field and Pool MRS "G" Pool For the Month of July ,19 83 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded 7/22/83 Depth 7/31/83 - 2825'MD Foota.e Drilled - 2825'MD Corrected directional drillinq 2225'-2414'MD 13. Casing or miner run and quantities of cement, results of pressure tests 13 3/8" casin¢ 2811' with 2075' sx Class "e." cmt. Pressure tested to 1500 PSI 14. Coring resume and brief description 15. Logs run and depth where run E£E VEI} ..16. DST data, perforating data, shows of H2S, miscellaneous data ~a$~,a 0il & Gas C0ns~ Commiss~Dn Ancho[a~e 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED i)"~J /~ TITLE Manager Production Adm. DATE 8/3/83 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 M EMORAN DUM State of Alaska TO: C. ~7'. ,~]~tterton DATE: AUg%L~t .].# ~ 83 ,. ..~.~. FILE NO: 0 Thr~: ~n~e C. S~th ~'"~"~ TELEPHONE NO: Commissioner FROM: Bobby Foster~~ ' SUBJECT: Petroleum Inspector Witness BOPE Test on Shell's Platform A-12A-1, Sec. 11, T 8N, R13W,SM Permit No. 83-106 Saturday_ July 30,_~_ 19~3: I traveled this date to Shell's Platform A to withess~ the ~c~ming BOPE test. Sunday_.~ly.. 31, 1983., The BOPE Test began at 3~00 a.m. and was ConclUded at 7~00 P'm. As the attached BOPE Test Report shows there was one failure which was corrected and tested, In summary, I witnessed the BOPE Test on .Shell's A-12A-1. Attachment 02-00IA(Rev. 10/79) STATE OF ALA$~\ AIASKA 0{' & CAS-CONSERVATION COMMISSION (" B .~. P.E. Inspection Report I ~ Date ,' ~' ~' ~- _Inspector Operator Representatzve. ~ , ~ ~tion: sec .// ~R/J~M 5 "~q"':" ' ,,Z~as:g .Set 0~~/) ..... ft. ~il ling ~n~a~o~~~,~.~ Rig ~ '7. Repre~ntat ~=tion, ~n~a~ ' ~ f' ' ~1 AC~U~ SYS~ . . Well Si~ ,ps,.. · ~arge ~es=e /~ .~ psig C~n~al Ho~e~g ~, '' ~l~essuro ~ter Clo~ro~~ ~ ~g ~e ~_.. ..... ,, ~ s : mn,.J D sec. Controls: ~ster R~te/~7~ Blinds ~it~ cover ~ Sta~ :''~ '~" ..... ~es~e Kelly ~d Fi~_ Safe~ V~ves - / ~ular ~eventer+ , ~ ~r ~lly , .Test ~essure ~ ~ / .~W ~r K~ly fl, Test ~es~e Bled ~s ~ ~ ~11 ~pe , , V~' Test ~es~re ~ -.,.,~ f ~oke r.~ne V~ve~ / ~ide ~E / Test ~es~e H.C.R. Val~ / , ~oke ~fol~est ~essure ~J"~. Ki~l U ne V~s r- m. V~s NO flanges ' -, ___. '=. , ~j=t~le ~o~ / l~a~lly operat~ ~e /' T~t Re~lts: Fail~es. .......... / Test Ti~~~s., Repair or Replac~ent of fail~ ~uip~nt. to ~ ~de wi~ --'~ ~ys ~d I~~or/C~ssion ~fice notifi~. Remarks: Distribution ori9. - AO&G2C cc - Operator cc - Supervisor July 28, 1983 Shell Oil Company Q 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- Further to the July 25 and 26 tel conversations concerning the bottom hole location of request the Commission's approval to mi hole location 100' to the east. In preparing to drill this well, we recently completed some new gyro surveys on nearby wells. The interpretation of the new data prompted the proposed change. The desired total depth location will be 1620'S and 650'E from NW corner of Sec. 1, T8N, R31W, SM. As agreed, because this well is a development well rather than a wildcat, we will catch samples at 30' intervals above the 9-5/8" casing point rather than at 10' intervals and prepare a mud log from that point to TD rather than from the surface to TD. RGH' KLE Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division Shell Oil Company Q 200 North Dairy Ashford P. O. Box 527 Houston. TX 77001 July 13, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' In response to the July I letter from The Commission's Mr. William Van Alen, we enclose a complete history for Shell's West Mikkelsen Unit No. 4 well. The well's mud log was transmitted under separate cover last week. The requested reports of production tests, including time intervals, quantity and description of recovered fluids and pressure data were included on the Well Completion Report (Form No. 10-407) which was sent to the Commission on June 3. A separate page of the Well Completion Report Form was submitted for each of the four production tests. No drill stem tests were performed. Also enclosed are the following routine reports' 1. Sundry~Notices - Subsequent Reports for Middle Ground Shoal Wells A12-01, A42-11, A43-23, C23-23, C44-14, A43-11, A42-14, and A24-01. 2, Monthly Report of Drilling & Workover Operations for Seal Island Well No. BF-47 #1. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH: mh Enclosures ~[~ STATE OF ALASKA (" ALASKA'OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IXIX OTHER [] 2. Name of Operator 7. Permit No. Shell Oil Company 77-55 3. Address 8. APl Number John Douglas, P.O. Box 4500, Kenai, AK 99611 5o-733-10081-01 4. Location of Well Platform A, Le,~ 1, Conductor 1, 1632'N & 437'W of SE Corner of Sec. 11, T8N, R12W. 5. Elevation in feet (indicate KB, DF, etc.) 116' K.B. 12. I 6 . Lease Designation and Serial No. ADL 18754 9. Unit or Lease Name Middle Ground Shoal 10. Well Number A 12-01 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation J~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give 'pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Job Cancel 1 ed. JUL 2 Alaska 0it a Gas C0ns~ Anchorag~ Date 7/13/83 14. I hereby certif_y that the foregoing is true and correct to the best of my knowledge. Signed ~/~ /~ Title Manager Pr°d- Adm- The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 SUbmit "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate ALASK ~LAND GAS CONSERVATION ~ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. SHELL 0IL C0HPANY 77-55 3. Address 8. APl Number John Douglas ,P.O. Box 4500, Kenai, AK 99611 so-¢33-10081-01 4. Location of Well Platform A, Leg 1, Conductor 1, 1632'N & 437'W of SE corner of Sec 11-T8N-R12W ,, 5. Elevation in feet (indicate KB, DF, etc.) 116' K.B. 6. Lease Desiqnation and Serial No. ADL 18754 9. Unit or Lease Name Middle r,.round Shoal 10. Well Number A 12-01 ! I. Field and Pool MIDDLE GROUND SHOAL "G" POOL 12, Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] ~ Perforations Stimulate X~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report rnultiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estima*,ed date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use T~,~, Production Administration 5/18/83 Conditions of Approval, if any: Approved by Form ~ 0-403 Rev. 7-1-80 Approved Copy Returned By' Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Oupqcate COILED TUBING ACID STIMULATION A 12-O1 PLATFORM "A" W.H. ROOM #1 CONDUCTOR #1 MIDDLE GROUND SHOAL FIELD KENAI , ALASKA Status: Well gas lif'l:in!! 1')4 BDO (66% cut) from HC through HZ Mechanical Details' See Attach' Purpose' Clean out to DO~'CO~ perforation with coiled tubing, acidize with coiled tubing, and return well to production. Procedure' 1. M.I.R.U. Wireline and lubricator. Test lubricator to 3000 psi. Pull Ball Valve. 2. R.I.H. with gauge run. Clean out tubing as necessary to bottom. Tag and record bottom depth. If.fill is present, R.I.H. with wireline bailer and obtain sample. Send sample to Dowell for acid and solvent solubility testing. Rig down wireline. Return well to production. Note: Have copy of all test results sent to T.S. Burns, Houston. 3. Obtain oil sample from flowline and send to Dowell for compatibility test with prognosed acid treatment. 4. M.I.R.U. coiled tubing and Dowell acidizing equipment. Test lines, tree, and coiled tubing to 5000 psi. Test hydraulic system and B.O.P. Place well on test separator and monitor production closely throughout operation. 5. Shut master valve and open swab valve. Pump filtered injection water through system to flush system. After system is flushed, filter all fluids through a 2 micron filter positioned immed- iately before coiled tubing (see attached piping sketch). Cut .. back pumPing rate to a minimum (1/8 - 1/16 bb/min). Be pre- pared to choke pump outflow line if the.equipment wilt not pump at a slow rate. RECEIVED Alaska 0II & Gas Cons, ~mmlsSlo~ Ah~hgra~l~l 6. Open master valve and R.I.H. with dyna drill on coiled tubing (no more than 100 FPM). If well's production interferes with coiled " tubing, choke well back at surface. Note: Do not pump down coiled tubing at a rate faster than the returns and production rates out the flowline. Attempt to maintain flowing well conditions at all times. An increase in injection gas may be necessary to keep the well from loading up. 7. Tag fill and record depth. Drill ~nd circulate fill out of hole e using filtered injection water. ~t = 4750 psi maximum pumping pressure and produce well at n~axi~,~ ~ rate with minimum back pr,essure. Note- Keep coiled tubing ..... ~t! Limes while circulating fill to help prevent ~',',,'~.~,,.~i which could stick tubing. Clean out to top of fishat 11,568'. Circulate' bottoms up . ~ while continuing to move tubing. Circulate until production is clean (no particulate fallout when centrifuged). Pump 50 bbls diesel to displace injection water out of well. P.O.O.H. 9. Shut well in at surface and allow well to build up and stabilize. Maintian 1000 psi casing pressure. 10. R.I.H. with wash tool on coiled tubing to bottom, pump 1260 gal (30 bbls) P-20 Solvent down coiled tubing at 1/4 bbl/min, Move coil uphole to treat entire :interval (10,618' - 11,568'). With coiled tubing on bottom, pump 1260 gal (30 bbls) 10% HCL with additives down coiled tubing at 1/4 bbl/min. Move coiled tubing uphole while pumping to treat entire interval.(lO,618' - 11,568'). ll. With the coiled tubing on bottom, pump 2520 gal (60 bbls) 7-1/2% - 1-1/2% HCL-HF acid with additives at 1/4 bbl/min. Move coiled tubing uphole to treat the entire interval (10,618' - 11,568'). 12. With the coiled tubing on bottom, pump 1260 gal (30 bbls) 10% HCL with additives at 1/4 bbl/min. Move coiled tubing uphole to treat entire interval. Displace acid to end of tubing with diesel and pump an additional 5 bbls diesel to flush coil. P.O.O.H. with coiled tubing. 13. Bleed off gas column and slowly return well to production. Test well daily until stable. RECEIVED Alaska Oil it Gas Oons. bummtsslor~ : · ... .;"COMPLETION DETAIL.'. ." ...... -. · ,, · . RE "COMPLETED. 6 17=78 .... ," ' :,,~,.-. ~. ', . , . . ... : ''.. , · .-. . .. .'.: '.,..,?."..' : . .,:--. . '', ~ I · · ' ''' ; ' '" ' "' . ' "' ' ' " _Bescriptidni, ...[:." .,:'.:. ": ' v """ :' "' "' alve Size': ;'.' ".":"'72'',')~' "Camco KBUG'Mandrel. - .... "3'1 ,," ,":":.'"'"" .!.:(.i'~..37~: · ,, . ,, . .,,.... : '. / 6 '" :',.,' ':..,' t.t':.:.'4",.~..::!,':! ..,, ..... -,,:.. ,,... " 3/16" '. '.,':'. '. ,.' ' .... '" 5/16" .... .. 7. '" " " " 1/2"'S.0. ' , 8...', Guiberson Uni 'VII'Pack,:r ' .. '" ....;. 9,' Camco KBUG Mandrel 10. BOT Tie ba'ck packer, .'?l l,, Baker FAB Packer ..'r 1.2., "-'., Otis X-Nipple , . '":'1,3',".'..E 0 T' ' "' ' ," t. ~,'., · i i '. . "[i '"' ;.t,. ; ,., :'t/'.,:. . · ':' i .' .' ........ , .. ".,?.L::.:. '.';'." 3~,, o"o'* N-80 'Buttress`.. to ?:..:' ,~ :'":.~ ~ ,', ~ . '.,. , · ; ; ~ . ; . : · . ..~..,,.., .:- . : ':" ' "' '' '" . · 7. , ·· .... : . ~,i ;, .,',.' . ,. .. · ,. ';,.',.: .,- ..'-:.' '" . .'!. · ' ~ ., ,' , _' _ .''-'-i ~". '.': .... ' .- · .. :..';itt'..:. ",; ,, ::..,, .,,.... , ,, .. '... , ,,,,,,~,~.,,,,,..~ ,..' · ,.. ':'., f,- · .... , ! ,. ~ - , '~ '.'i ,," 320' ":'~::"'"'"':':' " , .,.. :,/:' :,: .... . . . 4301 -.. '." .!.:.. [.~i.~..~!~.; i: .. '6764 · - ,'.-... ,- ..- '8545 ~ ', ,.'..'~,,, , · , 1 0 ' ~' '" ' ': "'' ' ' : /' '"' :~'"%%""';(:" :' ~ ' ': '" ' '. i:,t. .i .""' ":":'":L'~NE~. '.. ".".. ,,',...'.,.'. .......... .':'.:'-" '.;.. , k."¢.. · '', '', ", '.','." ' ~7",;".".:'" ' ~' '~'''': ' ' '~ '"i · ";,'"'"" :.., :',:.i.' .:, ' 17//,'N-80 shoe 1,980' ' " ' '- ' ' · .1 2') : "~ ""'""' · .,~. ~ ..... : . . -: . , , ; ." . .... · ,.,,, ,. . ~ CASING' "" " "'"" ' :'"'"'"'':;i ! i o 7.-5/8" 33.7# 'N'80 ~o '4~22'" ,, 7-5/8" 29,7# N:80 .from 4022'-74'9"7',"" 7-5/8" 33.7~! N-80 from 74.97.'-10,508" -- "SURFACE' p I P.E , 13'-3/8" 54.5// 0-55 w/shoe. O 1642' GR-GS . 1 HC-HD 1 HC-HD2 1 HI-HK U&L1 HK-HN 1 'HN-HR U&L1 HR-HZ 1 Perforations 0,292-10,350 0,618'10,675 -(1_21_80) 0,686-10,740 (Squeezed 6-78). 0,'882-10,888 10,900-10,922 O, 947-1'1,2'25 1,250-11,361 11 ;375-11,556 1,570-11,690 ll ,716-11,768 in Hole: 32' · D,/A Perf, Gun, 221' lk"'Tubing (,top la 11,568,) SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. SHELL 0IL COMPANY 77-55 3. Address 8. APl Number John Doug]as, P.O. Box 4500, Kenai, Al< 99611 50- 733-10081-01 4. Location of Well 6912'N & 437'W f~.om SE Corner Platform A, Conductor 1, Leg 1, Sec. 14, T8N, R15W. 5. Elevation in feet (indicate KB, DF, etc.) 116' K.B. 12. I6. Lease Designation and Serial No. ADL 18754 9. Unit or Lease Name MGS 10. Well Number A 12-01 11. Field and Pool HIODLE GROUND SHOAL "G" Pool Check Appropriate Box To indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [~X Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment i'-I Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting a~y proposed work, for Abandonment see 20 AAC 25.105-170). Job cancel led. L RECEIVED MAY 0 9 1983 Alaska 0ii & Gas Cons. C0~rnJssion Anchorage 14. I hereby certify that the f/oregoing is true and correct to the best of my kncwledge. Signed Tide_ Production Administration The spece below for Commission use Conditions of Approval, if any: Bv Order of Approved by__ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 Submit "Intent[ohs" ir~ Triplicate and "Subsequent Reports" ir~ Duplicate STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL r~ OTHER [] 2. Name of Operator SHELL OIL COMPANY 3. Address - ..Oo.hn Douq!as,.P.O. Box 4500, Kenai, AK 99611 4. Location of Well 6912'N & 437'W from SE Corner Platform A, Conductor 1, Leg 1, Sec. 14, TSN, R15W. 7. Permit No. 77 -55 8. APl Number 50- 733-10081-01 9. Unit or Lease Name MGS 10. Well Number A 12-01 11. Field and Pool MIDDLE GROUND SHOAL 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ,r,, ,.~ Pool 116' K.B.. . I ADL 18754 Check Appropriate Box To Indicate Nature of'NOtice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit i'n Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~ [] Abandonment Repair Well [] Change Plans [] Repairs Made I--) Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached MAR ~ o 1983 Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. PRODUCTION ADMN. The space be~o~for Commission use Date 3/24/83 Conditions of Approval, if any: Approved by.. COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1:-80 Submit "Intentions" in Triplicate and "~ub;~cluent A12-01 Middle Ground Shoal Field Reperforation Worksheet Status- Well gas lifting 244 gross (5B% cut). Mechanical Details: See Attached Schematic. Proposal: Reperforate the HK/HN (L) and HN/HR (U,L) in A12-01. Procedure' Note' (Reperforate A12-01 after A22-01) le 2, , , 6, Obtain a good 12 hour production test before reperforating for comparison. Rig up wireline, test lubricator to 3,000 psi and make a 2-5/8" gauge run. M.I.R.U. Dresser Atlas with lubricator and grease injection head. Pressure test lubricator to 3000 psi. Perforate selected intervals with 4 holes per foot using a 2-5/8" hollow carrier gun loaded with 12 gm charges (0° phasing) and positioned with a magnet at the bottom of the gun assembly. DO NOT PERFORATE ANY ZONE FOUND TO BE W~T IN A22-01 S.equence Zone DIL Depths Total HN/HR~.& 11510'-11540' 30 I 11450'-11480' 30 11390'-11420' 30 2 HN/H~((U~ 11310'-11340' 30 11270'-11300' 30 3 HK/HN(L) 11190'-11220' 30 Casing Collars' 11116, 11156, 11190, 11324, 11366, 11409, 11452, 11494, ..1.1536 Keep well "gas lifted down" while perforating. Establish inflow rate with +12 hours (or until stable) flow test after each sequence, send rates to T. S. Burns, Houston. Rig down Dresser Atlas. Approve ,~~~ Date TSB 'mh DATUM Item # 3. 6., . · ?;. 8. 9. 10. 1.3. Descripti6n: -- A 12..- 1. .. · · "COMPLETION· DETAIL ., ' · · · RE-'COMPLETED: 6-17=78. " " .. · ' · ' oo .. · ~' -. : : ·-'- .' o -. · ·, Valve Size . J: · ?', · Val.ve NiPple ' ... 3~1 ' ' " ':" ":'' 6 "'' ':':" .... ':" · .3/16" . '.- . 3/16" :'"' - 1/4"' . ' ' · 5/16" · '. 1/2". S.O. Otis A,O, Ball · Camco KBUG'Mandrel.. · II II · II · .. · . I! ·" II II· ·' .,:' II ' II I'1 ' · ., , II II II · ,' Ii II Guiberson Dni VII Packer Camco KBUG Mandrel BOT Tie ba'ck packer B~ker FAB Packer-' · Otis X-Ni.pple .. .." E.O.T.. · · · . .. · .. TUBING'. " -. ' '.".' .. 3½"..9.2# N-80 Buttress to 10,375' '.i'" '"' '"' , · LINER ''" "': ' · , ,' · ~_. ·, · 5½" 17// N-80 ~/shoe 0 11,980'/(Top'@ .10,302') : CASING .,' . · · - , 7-5/8" 33 7~ 'N-80 to 4022' "' "' "'"'"" .... 7-5/8" 29i7# N-80 .from 4022'-749'~7)' :' .' "'~-... 7-5/8" 33 7# N-.80 from. 7497.'-lO,508" . · M.'D~' ' .,, · . .320" ' ' '"2026 ...... · 4301 · ," · 6764.1. "8545. 9597 . , . 10,124 ' 10,192 10,234 ' , · . 10,302 : . ,.10,375 · · 10,388 · · .10',401 ' · .. · -.. · · . · . · . · · . .. · · · . : ~' :. · · ,, SURFACE PIPE " 13-3/8" 54.5// 0-55 w/shoe.@ 1642' · Perforations GR-GS 10,292-10,.350 HC-HD 10,618-10,675'(1-21-80) HC-HD2 10,686-10,740 (Squee.zed 6-78) HI-HK U&L10,882-10,888 10,900-10,922 HK-HN 10,947-1'1,2'25 .- · 'HN-HR U&Lll ,250-11,361' 11;375-11,556 HR-HZ , 11,570~,11,690 11,716-11,768 · ,- · · Alaska Oil. & ~as Fish in Hole: 32' D/A Perf. Gun, 221' o · · l~" Tubi.ng (.top @ 11,56B') · · ,, · DODO l O0:O 1 DOt 00! Ot MAR . . WESTERN E&P OPERATIONS r iDI]LE GROUND SHOAL, FIELD ~ SHELL-ATLANTIC-STANDARD PATTE;RN '::;¢1 /~ ~ PDS 18449 ADL ! 1756 5120 ~:. - ,, ,,,,,, ,, , ,, _..'~33-.~4 : j ~ d , , ,,,, , ~ I~.~--· ~ [/ INJECTION WELL PRODUCING WELL -~P.~ PLUGGED ~, ABND. September 23~1980 State of Alaska Alaska Oil' and Gas Conservation Commision ATTN Mr. H.W. Kugler 3001 Porcupine Drive Anchorage, .Alaska 99510 Gentlemen: Shell Oil Company .~ STA T TEC STAT TEC - Attached are the necessary reports for wells C-24-26 (redrill),[A/~-i (reperforate), and A 34-14 (convert to injection). Forthcoming'/gre reports on A 11-13 (P&A) and A 14 A-1. Please excuse the delay. / Yours very truly, G.L. Sauer Division Production Engineer Pacific Division EDS' crj Attachments Vorm P--7 SUBMIT IN DUPI.IC STATE OF ALASKA (See other ln- struct ions on OIL AND GAS CONSERVATION cOMMITTEE ~e,'erse side) 5. API NU'~LE, RIC.qJ-, CODE 50-133-10081-01 ~ · ii Ill I II I WELL COMPLETION OR,RECOM~LET!ON. REPORT AND LOG* --la. TYPE OF WELL: OZL ~ ,,'z~ WZLL ~ D~, ~ Other ~. TYPE OF COMPLE~ON: ~ -.~ NEW ~ WORK ox'g~ ~ g~D~ZP' ~ nacKPLa~ ~ . pzr,.r.~sv,. ~ Other 8. UmT,F~ OR WELL ~. ~,,z or o~.,,,o~ , .... Middle Ground Shoal- She 11 Oil_ Company ......................... ' ,. w~. No.' a. ~,,, o, o~,o, ~ , MGS A-12-1 ~ -, 10. F~.~ ~ P~L, OR W~T 4. LOCATION OF WELL (~epoFt ]ocGtio~ c]eG~]~ G~ i~ GCCOr~G~C8 ~{g~ ~y ~lGtg F~quirememt~)' MGS "G" Pool - · t,u~, Platform A, Leg 1, Conductor 1 ~ -.' ~: . ,.~ n.s~c..r.,R..~..~~O~o~~ - At top prod. ~nterval reported below ~ x : . _ ~ ; , Sec. I-T8N-R13W ~ttotal dep~ 1632'N & 437'W of SE corner of Sec ll-T8N-RI3W -' ~ ~ 12. P~IT ~O. ~- ,- ~ ; .... - 77'55 -: ' 13. DA~ ~UDDD !14. DA~ T.D. ~C~ 115. DA~ CO~, ~P, OR ~. 116. ~VA~ONS (DF, ~B, RT, GR, ~)*117. ~. ~SING~ : I ! -23- 0 I ! -:, 18. T~'D~H, ~ & TVDg9. PLUG ~ MD & ~D~. ~ ~Tm~ ~L.,? ' ! ~' 7 L. rlNT~R~ALS~RILL~D B' ' " 12,000 IBad csg or fill ~11~350' i ;~ I - ~:" :~' :' ~ - ~.: Pao~uc~ ~v~{s), oF ms ~P~Tzom--~P, ~m~, ~ (~ ~ ~- ' ~. w~ m~o~ ~ -- :- 10619 to 10665~:~10665 to 10675 t ;"~: 6. L~_.A_q~ E D~IGNATION AND S~.RI.A_L NO. APL 18754 7. IF INDIAN, ,aJ.,L~TrEE OR TRIBE NA.~,LE None 24. TYPE ELECTRIC A.ND OTHE~ LOGS I~UN Ran GR-CCL ~. , ~, ': , CAS~G R~ CRe~ ;il strings set'in 7-5/8" 3377: .~ I CzZ~ [ 10508' 29:7 I- 1 ~NER ~CO~ '~. : ~ ' 'I ~ 10302 l 5~ [ 11980 ,. ~.~PE~O~TI~NS OPEN ~' P~ODH~ON' (In~al, ~e ~d numar) < ~0292/~o3so, 10686/f0'74°, 10776/~0819 10882/10888, ]0900/1~0922, 10947/]1225 .. - 110121 SIZE · C~IEa'gTI. NG RECOltD _. ' ~O~ ~Uz,~,m . ' . . . .. (~) ~' ~ 3~'r:~'~' 10401 :'" "I ' 10375 .. ' ' Il Il I I "I I I ~ AC~, SHOT, F~'~;: ~%~ SQU~ZE, ~C. D~I,~V~ iD) [ ~MO~T ;~. ~D OF ~AL U~ DATE Or TEST, HOURS TF-,ST]~D ~ [CHO*~E SIZE PEOD'N ~R 1-23-80 ~ 12~ :~!128/64 ~ F~w' ~mN~ ~h~ ~mS~ IC~~ O~S~. ~s. [~-~OUR ~ - 661 Used for a'rt~ficial lift [ 216~ LIST OF ATT&CHMENTS OIL GI:La. VITY-API (COi:~.) 245 ] 29.4 tTEST WITNESSED BI' T. C. Odoms certify tlmt the fo/,~'~g 'and attached -- information 1.8~n~,~tt and correct as determined f'rom all available records,, 33. I hereby ~/~ 4'0~~-' ~~E ~k~. ~[},~"'~A~ ~--~//~J~-~ ~~~ SIGNED J . TI DATE *(See Instructions and S~ces for AdditiOnal Data on Revere Side) "" STATE'I.J F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Shell Oil 5. AP! NUMERICAL CODE 50-133-10081-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18754 7. IF INDIAN'ALOTTEE OR TRIBE NAME None Company 3. ADDRESS OF OPERATOR 9. WELL NO. MGS A-12-1 11 -T8N-R1 3W 4. LOCATION OF WELL Platform A, Leg 1, Conductor 1 1632' N & 437' W of SE corner of Sec. 8. UNIT FARM OR LEASE NAME Middle Ground Shoal 10. FIELD AND POOL, OR WILDCAT MGS "G" Pool I1. SEC. T. R. M. (BO'II'OM HOLE OBJECTIVE) Sec. 1-T8N-R1 3W 12. PERMIT NO. 77-55 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 1 - 15-80 Rigged up and ran 2.750 pulling tool POOH. Got mule shoe guage from "C". to X-nipple @ 10,401 unable to get deeper. Will run in AM. Off production 12 hrs. 1-16-80 No report 1-17-80 "Husky" brought Dresser Atlas equipment for perforating job 1-18-80 D/A people on board, rigging up to perforate 12-1 1 - 19-80 1-20-80 Rigged up wire Ran GR-CCL log Stopped @ 9150 Looked OK. Ra after attempti line unit and 'lubricator. Pressure test lubricator to 3000 psi. from 11350' to 10000' Pick up and run 2-5/8" slim-kone gun. '. Worked gun but unable to go to depth. Pulled gun and inspected. n 3rd sinker bar:on gun and ran to 9250' Gun stopped. Pull out ng to work through. Pulled gun and changed magnetic decentralized from bottom to top end. Gun would not go past'9100'. Pulled and ran 10' gun - would not go past 6400'. Put well on production, shut down perforating attempts for night. Pick up 2-1/8" slim- kone 6, GM. gun, ran to 10,675 shot 10,675 to 10,665 with 4 JPF. Testing well. 1-21-80 Testing 1-22-80 (6'30 PM 1/21/80) Rigged up Dresser with 2-1/8" 6 GM slim-kone guns and perforated interval 10,665 to 10,619. No misfires or reruns. Rig down unit and prepare to NOTE-Report on this' form is required for each calendar month, regardle~ of the status of operation, and mu~ be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unl~ otherwise dir~t~. load out. Form 10-403 REV. 1-10-~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-J' for such proposals.) 1. WELL I-_J OTHER 2. NAME OF OPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 1700 Broadway, Demrer, Colorado 80290 4. LOCATION OF WELL At surface Platform A, Leg 1, Conductor 1 1632' N & 437' W of SE Corner of Section ll-T8N-R13~ ~-3, ELEVATIONS (Show whether DF, RT, GR, etc.) 116' DF 14. CheCk Appropriate Box To Indicate Nature of N~)tice, Re 9. WELL NO. MGS A-12-I 10. FIELD AND POOL, OR WILDCAT MGS "G" Pool 11. SEC., T., R., M., (BOTTOM HOLE ( Section 1-T8N-R13W, S.~ ! I '"' '" ~ t 5. APl NUMERICAL CODE 50-133-10081-01 [--~(::-':., ,~'~-~ 7. IF INDIAN, ALLOTTEE OR TRIBE IA~E H~ddle G~ouad Shoal ~ ~ L~ 'FILE: ~ , 12. PERMIT NO. 77-55 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. See attachment 16. Iherebyce~ tha~/~e and correct SIGNED -~ ..... :i. TITLE Df.v:: ers ]~n.-r DATE (This space fOr State office use) JAN 1 8 1979 APPROVED BY. CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE . See Instructions On Reverse Side SHELL- CHEVRON-A~OCO-ARC0 LEASE FROM: 6/1/78- 1/16/79 Mss..,. DIVISION WESTERN COUNTY ELEV 1.16 '._~DF___._~ ~ STATE ALA_...~. ~ ..... 'i ALASKA MIDDLE GROUND SHOAL i A-12-1 "FR" TD 12,000. PB 11,850. AFE provides funds to cmt (Cmt sqz, perf & AT) sqz, perf & AT. Hooked up BOPE lines. Test rams to 3000 ~///?y psi, ok. Changed out hydrill bag & test to 3000 psi, ok. A-12-1 TD 12'000. PB 11,850. Pulled pkr loose, picked up 3 its (Cmt sqz, perf & AT) 1-1/4" tbg & screwed onto 1-1/4" in hole, could not work loose. Ran free pt, stopped @ 5260'. POOH & ran sinker bar to 11,542'. 'POOH. Made up 1-1/4" w/34 turns to right, worked 12 turns of torque to left for back off shot. Backed off before shot @ approx 8500'_+. JUN 2 1978 -- A-12-1 (Cmt sqz, perf & AT) A-12-1 (Cmt sqz, perf & AT) A-12-1 (Cmt sqz, perf & AT) _ _ A-12-1 (Cmt sqz, perf & AT) TD 12,000. PB 11,850. 6/2 LD 11,308' of 1-1/4 Hydrill tbg, 478' still in hole. 6/3 LD 399 its 3-1/2 Butt tbg, pkr & 6 mandrels. Picked up overshot, 40 j ts 2-7/8 drill pipe & ran rest of way in hole. Found top of fish @ 10,807'. Could not pull fish loose. 6/4 Rigged up Dia- log to run free point. Determined top of fish to be @ 11,495'. Could not go deeper, fish free at this point. Attempted to back off @ 11,495', fish backed off 4 j ts below overshot. POOH. Pick up Bell w/Hydril pin. RIH, could not screw into fish. JUN 5' 1978 TD 12,000. PB 11,850. RIH w/overshot & latched onto fish, trip'd jars one time & overshot came off fish. Could not get back on fish. POOH. Install new brake bands on rig. Pick'd up new overshot & RIH, latched onto fish, could not jar fish loose. RU & ran Dia-log in hole w/sinker bars, sinker bars stuck in top of fish, tried to work loose but pulled out of rope socket. Dia-log POOH. Made up blind backoff & started POOH. TD 12,000. PB 11,850. Completed POOH after blind backoff. Rec'd 14 jts (443') of 1-1/4" fish, 7 its (221') of fish still in hole. Top of fish now @ 11,568. Re-dressed overshot & RIH. Hole started get'g sticky @ 11~350_+. Ran to 11,478', took 60,000f/ wt to force overshot down hole. Terminated fish'g job & POOH. RU Dresser & shot 1 Gamma Ray JGT @ 10,686. RD Dresser. Pick up bit & scraper & RIH to 10,800. Pull to 10,000 & circ hole clean. POOH. TD 12,000. PB 11,850. Finish'd POOH w/bit & scraper. 'A-12-1 (Cmt sqz, perf & AT)(~ A-12-1 (Cmt sqz, perf & AT) A-12-1 (Cmt sqz, Perf & AT) A-12-1 (Cmt sqz, Perf & AT) A-12-1 (Cmt sqz, Perf & AT) TD 12,000. PB 11,850. RU ~i-State short catch over- shot and RIH. Latched onto~, atrievable BP @ 10,770'. Released BP & POOH. Picked up new retrievable BP & RIH & set BP @ 10,770. Pulled 3 stands of pipe & spot'd 3 sx sand on top of BP. Pulled to 7" & let sand settle. Ran'pipe back to 10,740 & spot'd 420 gals (10 bbls), 15% HCl across perfs. Started disp acid @ 1-1/2 BPM & press increased to 2250 psi, then broke back to 1500 psi. Increased rate to 2 BPM, press 1750, 3 BPM & press 2000. Over displaced acid w/20 bbls inj wtr. Bled press off pipe. POOH to pick up sqz tool. JUN .9 797 TD 12,000. PB 11,850. 6/9 RIH w/sqz tool & set @ 10,585. Close tool & prop 5 bbls to establish inj rate & proper function of tools. Mix 100 sx low wtr loss cmt, containing 1.5% D-19 (Fluid loss additive), & 0.5% R-5 (retarder). Spot'd cmt, closed sqz tool & began sqz @ 1 BPM. Press increased from 800 psi to 2000 psi w/several small breaks during job. Held 2000 psi for 5 mins & bled back. Releas- ed pkr & reverse back 1-2 bbls cmt. Held 700 psi 1 hr & POOH. Picked up bit & scraper & RIH. Started Drlg firm cmt @ 10,885'. Cmt was firm to 10,720'. Fell through cmt @ 10,740'. Circ'd hole clean, closed pipe rams & tested sqz to 2000 psi. Press bled from 2000 to 1200 psi in 15 mins. Prep to POOH & re-sqz. 6/10 POOH, LD bit & csg scraper. RIH w/open end drill pipe to 10,742'. Could not break circ& could not surge loose. POOH & found btm jt Plug'd. Ran back in hole & circ'd last 3 its down then circ'd btms up. Rig up cmt equip w/pipe @ 10,741' Equalize 25 sx cmt across perfs 10,686-10,740'. Pull'd 10 stands, closed pipe rams & held 2000 psi on cmt for 2-1/2 hrs. In 1st 1-1/2 hfs formation took 3.6 bbls fluid & in last 1 hr formation took no fluid. POOH. 6/11 Picked up cmt mill & RIH. Circ'd to 10,745' & found no cmt in csg. Circ'd btms up, pulled up into 7-3/8" WaSting for cmt to cure 24 hfs to press test. J~J~ ~ TD 12,000. PB 11,850. POOH. Picked up cmt mill &~ csg scraper & RIH to 10,795. Circ btms up. POOH. Picked up DST, RIH @ set DST @ 10,545' w/4600' of wtr cushion. Left tool open for 1 hr & shut in for~2 hrs. POOH w/DST. Sfc tests indicated no inflow. Picked up cmt mill & RIH. TD 12,000. PB 11. RIH w/cmt mill & washed sand off top of BP @ 10,770'. POOH & picked up BP retrieving tool & RIH. Latched onto BP, released it & moved it approx 30' up the hole. Rotated to the right & BP appeared to release. POOH, rec'd only the "J" slot retrieving head, threads on retrieving head had stripped out. Picked up overshot & RIH. Latched onto BP & worked for 2 hrs; BP appeared to come loose. Started POOH. 0U~ ~ TD 12,000. PB 11,850. POOH & rec RGT BP. Ran back in w/ open DP. Mixed & spot'd 8.8 ppg KC1. Plug'd 10,775-10,200'. Pull to 7'5/8 - Circ hole. JUN A-12-1 (Cmt sqz, Perf & AT) TD 12,000. PB 11,850. Circ well while waiting on pit lost in transit. JU~ ~ ~7~ A-12-1 ....... (Cmt sqz, Perf & AT) A_122-1 ................... (Cmt sqz, Perf & AT) A-12-1 (Cmt sqz, Perf & AT) A-12-1 (Cmt sqz, Perf & AT) A-12-1 (Cmt sqz, Perf & AT) A-12-1 (Cmt sqz, Perf & AT) A-12-1 (Cmt sqz, Perf & AT) TD 12,000. PB 11,850. Wa'~~ ~g on Bkr pkr. POOH & RU Dresser. RU junk basket w/collar locator. POOH & made up Bkr Mdl FAB-1 retainer production pkr w/assembly below expendable plug, 10' pup jt, Otis x nip, 4' pup jr. Ran pkr w/Dresser & set @ 10,375'. Pulled WL & tore out Dresser. 6/17 Picked up & measured 3-1/2 tbg w/Guib Uni- packer VII & GL mandrels as per W.S.; 318 j ts 3-1/2" Butt tbg w/pkr & GL mandrels as per installation report. Spaced tbg w/30,000# comp on pkrs, pulled up 90'. Rigged up Dresser & perf GR/GS zone from 10292-10350' w/4 jet charges per foot; 2.6" Slim Kone hollow steel carrier gun w/12.5 gram jumbo jet charges. Tore out Dresser & pulled up & installed Otis ball valve @ 320'. RIH & landed tbg, set pkr w/30,O00# Comp. Tore out BOPE. 6/18 Installed tree & tested & blew seals in do-nut. Tore out tree & removed & repaired do-nut. Re-installed tree & tested to 5000 psi, ok. Installing floor & laying down 5-1/2:' DP. TD 12,000. PB 11,850. FiniShed LD 3-1/2" DP & RU WL & pulled ball valve @ 324' & GV @ 10130' RU gas line & gas lifting inj H20 out of well. JU~'t '~ 0 1.~?~ TD 12,000. PB 11,850. Moved rig over from leg 1. Gas lifting inj H20 from well. ~;'~ ~ ~ !978 TD 12,000. PB 11,850. Finished gas lifting all H20 out of well, pmp'd in 426 bbls diesel; both tbg & csg full. RU !A~L & ran gas lift valve to 10130'; could not pocket. POOH & run'g replacement valve. O~ ~ ]nj/B/ TD 12,000. PB 11,850. Finished run'g valve w/WL & seat in #6 GL mandrel. POOH & RU Otis snubbing unit. Shut down due to high winds @ 8:00 am. J0~ ~ TD 12,000. PB 11,850. 6/23 SD due to high winds. 6/24 SD due to high windS. 6/25. Finished RU snubbing unit. Tested BOE to 3500 psi, ok. Picking up & running 1-1/4 tbg w/shear out plug on btm; shear out press 1800 psi. End nip 1 j t from btm & filling tbg every 25 + j ts. TD 12,000. PB 11,850. Ran 1-1/4 tbg to 10,300'. Hooked up prop & circ'd lines. Ran 1-1/4 tbg to 10,400' & pushed out Bkr expendable plug. Run'g 1-1/4 in 5-1/2 liner. JOi'~ 2 ? 'A-1221 ......................................TD 12,000. PB 11,850. Ran 1-1/4" in 5-1/2" liner. (Cmt sqz, Perf & AT) Found fill @ 11,460'. Plug'd tbg 10 times while circ'g out pill. Spot'd acid & wash perfs from 10,775-11,460'; reverse spent acid out w/diesel. Acdz perfs from 10,775- 11,460' w/12% HC1 10% HF mud acid. Overdisplaced w/50 bbls diesel. RU to pull 1-1/4" macaroni. JUN ~ A-12-1 \., (Cmt sqz, Perf & AT) TD 12,000. PB 11,850. 'PUlled &-LD '11,'4-60' '0f-'ll/i74'' .......... tbg. RD Otis snubbing unit & prep to MO. 0UN ~9 ~978 ~ ~AX12-1 TD 12,000. PB 11,850. Ga~S lifting' (Cmt sqz, Perf & AT) unit. (~O~Tg) 0UN B 0 ~978 h~'i22.-1 "II) 12,000. PB 11,850. (RINDS'-6/30/78) .... on 2~-hr test (Cmt s~z, perf & AT) 5/26/78 before work, prod 492 BO, 276 ~ & 415 MCF gas~ On 24-hr test 8/6/78 after work, prod 433 BO, 169 BW 196 MOF gas. JAN 1 8 1979 SHELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO 802.02 July 13, 1978 Subject: Shell-ARCO-Standard Middle Ground Shoal Mr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: AttaChed are two copies of the Monthly Report of Operations for June, 1978. KWL: ts Yours very truly, For: R. Planty Division Operations Engineer Rocky Mountain Operation's Office At tachments cc w/Attach: Atlantic Richfield Company Standard 0il Company Amoco USGS Form Nc~. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-133-10081-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18754 2. NAME OF OPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 1700 Broadway, Denver~ Colorado 80290 4. LOCATION OF WELL Conductor 1, Leg 1, Platform A 1632' N & 437' W of SE Corner of Section ll-T8N-R13W 8. UNIT FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. MGS A-12-1 10. FIELD AND POOL, OR WILDCAT MGS "G" Pool 11. SEC. T. R. M. (BOSOM HOLE OBJECTIVE) Section 1-T8N-R13W, S.M. 12. PERMIT NO. 77-55 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. OPERATIONS FOR JUNE 1978 Squeezed perfs 10,686-10,740 (HC/HD) Perforated 10,292-10,350 (GR/GS) Acidized 10,775-11,460 Presently gas lifting JUL i 7 i978 ' ¢ t~ t~o~ng~u id 14. I hereby tha e correct SIGNED p. ~ ~ TITLE ]~V_ O~'t~. ~__ DATE 7/~_3/78 _., NOTE--Report on this form is re~'uired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. Form 10-403 REV. 1-10-73 SuDmit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-10081-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18754 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL L--J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 1700 Broadway, Denver, Colorado 80290 MGS A-12-1 4. LOCATION OF WELL At surface Platform A, Leg 1, Conductor 1 1632' N & 437' W of SE Corner of Section ll-T8N-R13W 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 116 ' DF 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT MGS "G" Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 1-T8N-R13W, S.M. 12. PERMIT NO. 77-55 )ort, or Other Data NOTICE OF INTENTION TO: ~g~WATER SHUT-OFF L--~ PULL OR ALTER CASING L--~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT O~ ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* - (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. See attached prognosis RECEIVED 0 lg78 16. I hereby certi~hat .~'~l/~egolng/s t rue and correct Div. Opers. Engr. 5/8/78 TITLE DATE (This space for State office use) APPROVED BY ~~ TITLE CONDITIONS OF AppRoviL~ Petroleum Engineer OATE J May 12, 1~78 WORKOVER PROGNOSIS (SHUT-OFF WATER/OPEN/HC/HD1 AND GR/GS) sas MGS A'~'2-1 MIDDLE GROUND SHOAL FIELD, ALASKA Status GL 1025 BG/D cut 31% water (704 BO + 321 BW), GOR 470, inj. gas +1000 MCF/D, TP/CP 100/650 psi (average of April tests). All zones from HC/HD2 through HR/HZ perforated' 1082' gross, 867' net, 3468 holes. Water (+_320 BW/D) inflowing from HC/HD2 10686-10740' (54', 216 holes). ..Obi ecti yes Shut-off (cement squeeze) HC/HD2 water source. Remove suspected formation damage near well bore via Mud Acia(~) treatment. Open (perforate) HC/HDl 10615-10675'. Open (perforat~ GR/GS 10292-10350'. Procedure 1. Rig up Otis snubbing unit. Without shutting-in well (continue gas lifting), snub l-l/4" (nominal) macaroni tubing string to bottom, PBTD 11850'. (Note - all depths are measured depths.) . With macaroni string at bottom, pump 36 Bbls of protective "pill" (taking re- turns out of 1-1/4" x 3-1/2" tubing annulus). Displace pill with 20 Bbls of diesel. These volumes will place the "pill" in the 1-1/4" x 5-1/2" annulus and in the 1-1/4" macaroni string from PBTD 11850' to above liner top near base of packer. (Formulation of "pill" will be supplied in an addendum to this prognosis.) . Shut-off lift gas immediately after pill is in place and bleed off casing pressure. 5. Pull macaroni string. Release snubbing unit. e Rig-up slick line, pull lowermost gas lift valve at +10149', and kill well with injection water. If injection water is not sufficient, displace water with appropriate weighted mud; use as light weight fluid as practical (i.e. based on wellhead pressure with water in well bore). 7. Skid rig to Leg 1 and rig up on Conductor 1. 8. Close Ball Valve, set BPV in tubing hanger, remove X-mas tree, and nipple up BOPE and riser. Test BOPE to 3000 psi. SAS MGS A-12-1 9. Open Ball Valve, remove BPV and pull tubing and packer. 10. Rig-up Dresser Atlas and shoot one Gamma Ray Marker jet shot at 10686' (top of interval to be squeeze cemented). Refer to Dresser Atlas Gamma Ray cased-hole log dated 1/15/78 which was run immediately prior to per- forating (and had been correlated to Schl. DIL/DFL and Sonic logs dated 1/5/78). ll. Run bit and scraper into 5-1/2" liner and scrape perforations 10686-10740'. Do not go deeper than 10800'; do not circulate after entering 5-1/2" liner (i.e. minimize disturbance of protective "pill"). 12. Run retrievable bridge plug (RBP) on work string to +10750'. 13. Rig-up Dresser Atlas and run Gamma Ray/collar locator sonde to accurately position RBP. 14. Set RBP (top of pack-off element) at 10770'. 15. Spot 25' of sand (3.25 ft3) on top of RBP (sand can be pumped down and will settle out freely on RBP if transported to bottom in water). Reverse-out excess sand (if any) to 10745'. 16. Before pulling work string, wash perforations 10686-10740' with l0 Bbls of 15% HC1 acid (formulated as specified in Step 40.e.). After washing perfs, inject spent acid into formation; overflush perforations with 20 Bbls of injection water (20 Bbls in addition to work string volume). Pull work string. 17. Run retrievable full bore cementer (RTTS type) with 180' of tail pipe to top of sand fill at 10745'. 18. Spot 23 cubic feet of retarded cement slurry from 10745' back to +10565' (retard cement for +6 hours pumping time). - 19. Pull cementer +180'. -- 20. Reverse-out excess cement and set retrievable cementer (tail at +10565' and cementer at +10385'). -- 21. Spot +ll5 cubic feet of cement slurry to bottom (packer), close circulating valve--and squeeze perforations 10686-10740'. Displace cement (out of work string) with well bore fluid (water or mud). a. Do not exceed formation fracturing pressure, estimated to be 5170 psi BH? at 10700' (8252' TVD); equivalent to 1540 psi surface pressure with full column of injection water in well bore. b, If surface "squeeze" pressure of +1500 psi is not obtai.ned and cement is being displaced freely into formation, clear retainer, tail pipe and perforations of cement and repeat squeeze attempt wi th an additional ll5 cubic feet of cement SAS ~IGS A- 12-1 slurry. Repeat cementing with ll5 cubic foot batches until "squeeze" pressure is obtained. Do not undertake "hesitation squeeze" procedures until third squeeze attempt. 22. After obtaining squeeze, unseat cementer and reverse out excess slurry. Pull cementer. 23. Run bit and clean out to sand at +10745' (note hard cement, stringers, holi- days, etc.). 24. With hole full of water, pressure test squeezed perfs with 1500 psi surface pressure. 25. Run DST (inflow test) of squeezed perforations with sufficient water cushion to provide 1200 psi back pressure; i.e. approximately 4700' of water in work string with test tool set at +10600' MD. (This pressure is equivalent to operating bottom hole pressure-when gas lifting.) 26. Repeat Steps 17 through 25 if necessary. 27. Run RBP retrieving overshot, wash out sand and retrieve bridge plug. · 28. Run work string with bit and (5-1/2") casing scraper to 10775'. 29. If hole contains mud, reverse out mud with injection water (only down to 10775', however). 30. Spot KCl water from 10775' back to 10200' (approximately 15 Bbls). Mix KC1 water to a density of 8.8 ppg (i.e. lighter than"pill'~and heavier than in- jection water). Pull work string, bit and scraper. 31. Rig-up Dresser Atlas. Run Baker FAB-1 retainer production packer with mill- out extension, Otis type X landing nipple and Baker Model B Expendable Plug Receptacle (with plug in place) on wireline and set in 5-1/2" liner at 10375'. (Depths: refer to Dresser Atlas Gamma Ray log dated 1/15/78.) 32. Run production string as per attached Completion Equipment Detail sheet. 33. With end of 3-1/2" tubing (Baker Locator Tubing Seal Assembly) in top of 5-1/2" liner @ 10279', perforate GR/GS interval 10292-10350' with 4 jet charges per foot employing 2.6" Slim Kone hollow steel carrier gun loaded with 12.5 gm Jumbo Jet charges (zero phased) and positioned with magnet at bottom of gun assembly. (Note - pressure condition observed in offset injector A-23-1 indicates a column of injection water will provide a pressure overbalance on the GR/GS zone.) 34. Lower production string (+90') and insert seal assembly into FAB-1 packer. 35. Set Guiberson Uni-packer VII in 7-5/8" casing at +10225' employing plug in Baker Model B recept'acle below FAB-1 packer to pressure-up against. SAS MGS A-12-1 4 36. Close Ball Valve, install BPV in tubing, remove BOPE and nipple up X-mas tree. Pull BPV and open Ball Valve. 37. Pull lowermost gas lift valve and reverse circulate injection water out with diesel. Re-install lowermost gas lift valve. 38. Release rig. 39. Rig-up Otis snubbing unit, run 1-1/4" (nominal)macaroni string to 10775' and reverse circulate protective pill out with diesel. (Push out plug from Baker Model B receptacle with macaroni string.) 40. After protective pill has been reversed out, acid wash perforations 10776-11768' wi th 15% HC1 acid. Wi th macaroni on bottom PBTD 11850', pump 22 Bbls of acid followed by 22.9 Bbls of diesel flush (taking returns from l-l/4" x 3-1/2" annulus). This will place the acid in the 1-1/4" x 5-1/2" annulus from PBTD 11850' to 10775'. Wash perforations by alternately pumping 22 Bbls of diesel down 1-1/4" x 3-1/2" annulus (taking returns from 1-1/4") and down 1-1/4" (taking returns from 1-1/4" x 3-1/2" annulus). a . bo c . d . e o After 3+ wash cycles, reverse out spent acid and repeat Steps 40.a. and 40.b. two additional times for a total three washes and 66 Bbls of acid. Reverse out all spent acid with diesel. The 15% HC1 wash acid should contain the following' Component Function Concentration A-200 Inhibitor 5 gal/lO00 gal F-75N Surfactant 2 gal/lO00 gal L-41 Sequestering Agent 13#/1000 gal 41. Spot 22 Bbls of 15% HC1 acid on bottom from PBTD 11850' to 10775'. Acid formulation should be as above with the addition of a non-emulsifying agent. 42. Pull macaroni string. 43. Perform Clay Aci~)treatment as per Dowell recommendations. 44. Put well on gas lift and establish production rate and composition. 45. With well lifting, rig-up Dresser Atlas and perforate HC/HD1 interval 10615- 10675' with 4 jet shots per foot employing 2.6" Slim Kone h611ow steel carrier gun loaded with 12.5 gm Jumbo Jet charges (zero phased) and positioned with magnet at bottom of gun assembly. (Note - perforate bottom 10' first (10665- 10675') and establish fluid content before continuing perforation job.) SAS MGS A-12-1 5 46. After production rate and composition has been established from HC/HD, through HR/HZ zones, pull dummy from gas mandrel serving GR/GS perfora- tions and establish contribution of GR/GS. 47. If warranted, run a multi-rate/inflow profile test. EDM- KW Attachments Prepared and Recommended' Recommended' Concur- Approved' f4 C I-'ID HE. /-'! F t'-i K. /t 00~ r -I'D ~ !zoo~'( D WOP-_V. OYP_Z~_ lq~"/ 1978 IOz~Z ~ ,--~ r.~ ,. " I 1 S H ELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO ~][ 80290 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. O. K. Gilbreth Gentlemen: Enclosed ar~ts of the well logs for C-44-14RD. The well logs for A-31-14 an~ A-i~-i ~re beingo reproduced,, in our Houston office and will be sent to ~j~ial Delivery as soon as' they are ready. I have also attached an additional copy of the documents we sent you yesterday. Unfortunately they were sent regular mail and this letter will be sent "Special Delivery" to avoid delay. THB:DW R. Planty DivisiOn Operations Engineer Rocky Mountain Operations Office Enclosure ECEIV[:'D b4A¥ ,-. 5 l~y 3, lg78 State of Alaska Division of Oil and Cas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Mr. O. K. Gilbretb Oentlemen: Attached are the following.documents per your discussions with Mr. M. L. Woodson: . ., 1. Monthly Report (March 1'978) - C-42-23- 2. Monthly Report (April 1978 3. Monthly Report (April 1978 4. Sundry Notice - A-23-1 5. Directional Surveys - A-31-I4, A-12rl and C-44-14 The well logs for A-31-14~nd 0-44-14 will be sent to you shortly under separate cover ~ Houston Office. TB :ts Yours very truly, R. Planty Division Operations Engineer Rocky Mountain Opera~ions Office At tachments cc: Mr. M. L. Woodson Forn~ P--7 SUBMIT IN DU ATE* STATE OF ALASKA l'Si~,'other in- structions on OIL AND GAS CONSERVATION coMMITTEE ~,.~ ~;a~ i ii i i I i ii iiii ii III i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* i ii ,,. TYP~ oF w~,~L: · o.. [] .s [2] .... Vq W ELL W ELL DR V Other b. TYPE OF COMPLE~ION: .~ ~ wo.i,r-] DEE,-f--1 ~L~I--] .X..~ WELL OVER EN BACK nESVR. Other 8. LTNIT,F.4~q/V~ OR LEASE NA1VIE 5..~A,,E or OeERATO~ Middle Ground Shoal Shell Oil Company ~.W~L~O. s. AOD~ESS O, OVEr,TO, MGS A-12-1 1700 Broadway, Denver, Colorado 80290 ~. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* at sa~ce Platform A, Leg 1, Conductor~ 1: 1632'N & 437~W of SE - Corner of Section ll-T8N-R13W, S.M. 1~ teo_nrod, tnter?a_l .rqpprted below _ ,zg~'H & 1044'E of SE Corner' of. Section 1~-TSN-R13W, S:H. _ ~t Intel depth ~ .. · 1329'E of SE Corner of Section 14,T8N-R13W, S.M. ~,..vmmmrso. · ' 77-55 13. DATE SPUDDED . ii. DATE T:D, RF-~CziJ~J~ 15, DA~E .CO'M-P SUSP OR ABA1N-D.!6. ELEVATIONS (D.F, RKB, I~T, GR, E~I~)® 17. EI.,~. CASINGHEAD 10/25/77 1/5/78 1/31/78 X~jI~,f~L I)__~r~T_ H, MD a TVD[lg-PLU~G, B~CKMD & TVD]20. I~ 1VfUL'r ~k'LE COI~PL., 21. 8f~3~--~w~-' [8465 TVD [- ~ow Total ( 2,ooo / 11,970 ~ I - ~.~~'r~AL(S), OF ~Is COM~TiON--~, BOSOM, N~B (~ AND Top: 10,615 MD, 7417 TVD Btm: 11,768 .. MD~ 8306 ~D ~. AP1 ~CAL CODE 50-133-10081-01 ~.~SSD~S~S~os'~r~DSm~n~u~o. ADL 18754 7. IF Lt'N~D1AA~I, AJ-J. XDTTEE OR TRIBE NAM~ 10. FrELr~ A2VD POOL, OR WILDCAT MGS - "G" Pool it] SEC., T., R.,' M., (Box'roM HOLE S o~. ~CTZV~% ecuxon ~-T8N-R13W, S.M. 24. TYPE ELECTRIC AND OT~ LOGS RUN 116' DF - INTERVALS DRILLED BY 'l ' CABLE TOOLS -- 23. WAS DIREC~rI0,NAL I SURVEY 1ViA D E Yes mDIL/S, FL~ BHC Soni,C, GRN ~ C~SING RECORD (Report all strings set in well) CASLNG SIZE WEIGHTi ~B/FT. I 'GR~D,E I DEPTI-I SET (iVID) HOLE SIZE 13-3/8" 54.5 1642'_ 17-.1/2 26. LINER I~EC Ot~D : SACKS CEMEATT* 28.' PESO.RATIONS OP~ TO PRODU~-I'IO (interv~, size and number) 11,716-11,768 10,9~7-11,225 i CEk%Ir~NTING RECOi~I) l1 ~VIOU1XrT PULLED , 2500 sx - 400 sx . SCR~ (MD) SIZE D~ SET (~D) [ PA'CKER SET - 3-i/2 ' 10~336 ".. 10~241 . ACID, Si~OT, F~CT~, C~ENT SQUEEZE, ~C. 11,570-11,690 10,900-10,922 all perfs - .m-~-Z. mTm~Va~ (no)iAnOU~T ,4~b~ .~:~a¢ 11,375-11,556 10],882-10,888 4 holes/ft '~ ' ' ~ ~ ' ' 2 ". 11,319-11,361 10,716-10,819 ~A~- ~ ~j[~ , . 11,250-11,313 10,686-10,740~ ~.' ..... ~ "' "~ODU~ZO~'' uun OI DATE ~R,ST P~ODUC~O~ [ ~ODUCTION MErHoo (Flowh,.g, ga~ li'~7 pump~g--size and type of pump) 1/16/78 [ Gas lift ~ [ ~'~'~" ~rod'g .... ~ow, ~m~ lcA~o ~ss~ lc~~~ o~. ~~. wA~m~. ~om omAvrzy,~r (co~.) 110-150 I 795 :I~ [ 752 I 404 I 502 31. vmvos[~[os or ~ss (8otd, U~ed )or fuel, vented, etc.) I TEST WITNESSED BY Gas lif~, fuel, sold ........ 32. LI~T O~ ATTACHMENTS Well History 33.'I "hereby certifyf the~oing~and attached information is complete and correct as determined, frOm alFavatlable records SIGNED ~'~' i TITLE Div. Opers.. Engr. ,.,~ ~P~ ! ~-(ELL~DIL -- FILR.Si:.i£t R12 £ HETHDZ! BF CDi'IPUTFITI I.S RRDIU._-', DF ,Z:URVRTURE FIF'PF.'DPCH 3 U F.: :-/ E 'K D R T FI i.!ERZ-:URED DEVIRTIDH DEPTH DRIFT DF., IF'T ' ~DF> RiIGLE Z~IRECTIDit VEE'T I CRL DEPTi4 ' BDF > LFtTERRL DEFLECT I Di't FF:Di'I ._--'.URFRCE LDCRTIDit it DR .3 ..'.-- ) E DF.: i.,.I ' .- > 3 3 b._..- ~-' 45 16~34 4 15 1715 6 .:'1747 -:..-.'-: -7 15 1816 9 --.. 154 3 . 10 45 1904 1 19.38 1 ,23.36 14 45 ,-'39'..4 1,$ 15 :'14C-; 17 4=, 2237 19' 3 2270 20 45 ,-.:,.:, o .-'.:: 2.394 ,-',:5 '3 245;3 :'~ -~ 3 ~ I -~.' 25,] 1 2G: 45 2562 2'?. 45 262 3. 3 3 3 26~:1 .31 45 2755 32 3,) 2816 33 45 2'?07 35 15 3031 '" 37 45 3095 .2.9 45 319 3 41 ,3 327"8 ' 42 1 344 0 44 .30 3:-;.3.3 45 45 362;3 43 3722 5 · 3;377 52 15 40;31 54 412.3 56 15 4256 56 45 4.33 3 57 ,_'l 4492 56 3 45'.99 54 3 4,:,,:.2__ 5:':'"; ._,':'n. 4756 53 3 4S53 5G; 45 -497:3 .-%:3 15 o135 5:3 30 526.3 5;3 45 541 =, 54-7 .] ='_, ._-':' 5635 57 .S 3 5 ;-6 O 56. 3 ;] ~;-. ,z, ,] it 3 i":"- H 44 F'- iq 35 E H .3,3E H 36 E i'"l 25 F- i'4:'3 E &. it 1-1 E H 1.:: E it I1 E i"4;3 E f'.! 7 E H ,..:' E i't.3 E i"4.3 E it "' E it 2 E i-41 E i'.! 6 E i:t11 E i'414 E i'.t 12 E i'tI2 E it 11 E i'til E H 11 E i"4! ;_] E it 14 E i".i 21 E H 21 E i't! ..4. r i"1! '?E i"419 E it I '?E i-!19 E. it 19 E it I '~E it I4 E it 13 E it I3 E H 15: E il !-3 E i"!i3 E i'413 E i-4i4 ,-' r4,!._'-: E' H !4 E H ~5 L: 3.;3 3.0 0.O 1651.4 35.9 14 .=, 168.3..3 .37.4 1 =,. 7 1714.2 .39.6 17..~ 1746 · 3 42.6 19.~ 1;314.~_:' 51 .4 24 .7 I ;:-:.37. ;3 z,::,..:: 26.3 1900.=, 67.6 29.7 1933.7 74 · 9 31.7-: :' ;'12R. S '-.-¢;:: 1 .3,'-', 2 L .... · _ · ;'! R-~. = 114 ~ .--:'~ 0 . _ . · I II -- .- I :' I .E:E, .3 12;3 '~ 4 ;_'l '~ &- · · .* · . 2192 ..3 147 .=, 42.3 2251.6, 168.9 4.::. 2 2.--: t 3. O 1-}2 ..:." 44 . ~ 2.--: 6.'--, "-' :' 17 I 45 ~:: -- · i_1 i · I 242.--: .2 245.4 47. ,] 2461.1 265.6 4 7 · :5 2514 ..3 295.4 49.4 256 7.,.._:' 325.4 ::, .:; . ;:', 2617. ,3 354.5 ,:, d..:: 2679.6 .392 · ;3 6 '?. l 27.3 ,]. 7 425.4 76.1 2;3 ,] 5.7 475.9 5:6.3 2;3 6' 1 . .3 5.33.3 97. ,] 2'? 54.6 o ;:: ;.4..:, 1 O ;3.2 · 3 ;]27. ,] 649. i 119.5 · 3092.7 706.2 1.31.6 · --:21 ,]. 5 :312.2 1 E, 5.3 · 3276.1 ;3 ;-'.3. ;3 1:3 ;3. ,'-' 3341. ,'l 9.::,::.__. 7 21 ~...:' '~ ,34 32. ,"" 1 O ;35. ,':, ' 5'._--', 6.6 · 3:'-; ,] ;3.3 1119.7 275. '? · 35 74.4 121.3.5 .3 O 3.2 :3644.1 1' .3 ,] 3.1 .34 ,]. 3 3717. :3 141.3.3 376.9 · 376' 5..?, 1:3 1 I . 1 4 1 3.7 .3:347.1 1539.4 44 1.1 · 3 ..9 ,] ;3.5 16 ;3.]-'. ::, 46 G. ,] 3944 ':~ 1 -'-' '" =, 47';3 0 · .. l' ,,D --', ,, · 3'? 9 E,. 4 1:31 3. I 4 '? 5.7 4 O 4 7.~_:' 1 :::_..':~ ,',.. ,S 514 . .3 41 ! 2 · ~':, I '?'74 . 4 -_'3._:;;-3.2 41 94. "~.. ,_:' 124 . '-', 5F,;3_ . .3 4261 . :3 22.31 . I 592. '~ ~-' 'i - 62.3 :' ~..:, 4 ,_ 4 ,-'-:;.'} ,' . · il,... 4 3 ,S '>. 2 24 ;3 .S ..'~ ,S .34.2 444 i ..:7 23 ! 4. O 66 ;] .,3 4525.7 2E,S'?. } 6-3.?. 4 xbtbiVb'D MAY - 5 1978 D:vision of Oil a~d '~ G~S Corlg~Ft Anchor,q,, DOG LEG "DEG,-" 1 0O ' > 3.2 5.0 3.9 .~ --, i~ I,._ 1,.6 o,~. = i' · 3,1 · 3.4 .3. ;2, 4.3 .:: · 1 4.3 4.1 4.3 1.3 1.:3 ~. ,.-,. · 1 .5 1.3 · I .:3 1.4 3.4 0 ;i.9 4.3 ? · ;]. 4 L'I :' 2.1 3. j; /. 6035 6,254 64L~ J 6.E4 1 6604 6663 6764 59. 59 57 6~: 1 57 '~-i ?03;3 i'"' o~' :J~_:7195 - - 56 :~ .,.'. 't?:. 7~:49 . ~372 O 9 ~2~ 9436 9673 9~B~9 9933 10161 1 ;1 0421 1 1053:5 1'05~7 10979 1104 I 11 -- . 54 53 54 54 5.3 -52 54 57 57 56 5.3 4'.-.-4 47 45 4.3 3.5 35 '.~ 39 4I 41 41 0 3 O 45 45 0 15 0 45 15 15 45 15 15 0 15 45 15 15 15 15 45 45 15 45 30 4.5 11175 1124.3 11.3F'4 11553 11700 I 1786 11F:44 45 45 45 45" 0 3 5 4,] · .:4. 3 J .BiB 15 3? 15 M 15 E 4525.? H 14 E 45:31.~ it !5 E 467;3.5 it I5 E 4;349.;3 H !4 E 4914.~ M 14 E 494~.~ H 14 r 4977..3 M 15 E 5037.9 H 14 E 5061.6 H 8 E 5125.2 M 14 E 5210.7 H 13 E 5296 .~ M 14 E 53~:3.4 H I3 E 5521.1 H 14 E 5663.6 i"{I2 E 5772.9 H 11. E 5864.6 H ~IE ---~ 5 H 11 E 60~:6.4 H 12 E 61~5..:, ~ H I1 E 6302.3 H 11 E 640~ .6 H 11 E 6496.4 H I~:'E 6606.'~. iI 1~:'E 67~4.0 it I2 E 6887.6 it 1 TM' ~- 6934.1 it I ~-~ - 7061.6 it 18 E it 13 E 7865.1 it I'.:, E 7343 .'~. it I3 E ~.35~.0 it 16 E '73.70. O i~ 1.3 E ~493.3 it !5 ~ 761~..3 H I4 E 7700.6 it !5 E 774~'4 it 16 E 7770.~3 it !6 E 7:?,4-4.9 it 17 E 7903.2 it 20 E 7961.T it 2I E 3818.6 it ~ E G~10~.3 iff24 E 8319.9 it 24 E 8.365.9 IiiTERF'DLRTEB i'IER._:iJF.'EB DEF'TH 26.3'3. 2720.4 2~61 ..3 .31,_.:'1 . 1 3225. :3 · 3277'. O' · 3329.6 .337 ;3.4 3.461 :' ~i... 3557.6 · 36:-_-.'6. · 3314.7 · :, ..41 , 4141 :' mi.. 4-34 5.9 44;37. 4611 4~z,:-,m_~. :_', 47;3.3 4 '9 0.3.9 5 327.1 5251 .G: 5364.1 549~3..3 565 ,]. 57'.-.4.3. :_', 5'957'. :5 6316.1 6137. I 6,224.5 6.35 ,] 6360.9 6.3 ~, b. :_-, F,.3 ? C-,'. 9 6465.5 6562.4 6632.7 6691 . ,? 675.3. 6~349. 6 ;.3:37.7 6959.1 7 57 ,]. 7119. 7152.1 69.;:. 4 714.2 7 ::3 ,]. 6 ;32 0.2 :]-', 47..3 :360.1 ;~:'-. - ,-' ._-1. ;385. ;3 '~ ,_] 7 :' · .-.-',36.3 951.1 9;_=: 1 . ;3 1 Jl,._--'. 10,:.5_ .,_ 11 03.1 1141 .'3. 1167.1 1175.9 1,_:'31.3. 1'351.3 1236.9 131-3.4 ! ._--:44. :'-, 1375. :'-; 1455 .;3 14.--'. ,]. 1 1454.,.. 14;_::2.1 15 51. :5 151 C-:. 4 1 :"~.:-:,3. 1:57:.::. 6 1 ::'";.]-: 6. 155'.:'. 1 .'_-'.' C-: 3.._=: 16 31. :z-.; 1611.7" 1617.1 1634. 1 ,:, 4 ;3..'-: 1,_:,65.1 1679.5 17 ,]7.7 175,.3. '177.3 . 5 17C-:7.9 I 0,'~ FDEtT Iit,-:FIEHEitT.2 DF THE ._%!2.?ER DEPTH 1.:] ,].6 :1.3. ,3.0 I :' · I.,.. 0.7' 0.4 0.9 -' 0.9 0.4 0.7 0.7 1.1 1.6 :-...:2 1 · ;3 1.9 1.4 1.4 1.1 :' 6 I.. · 1.7 :' 6 k- · 1.? 1.6 1..3 1.1 :' 1 0.9 1.3 m i" 1.5 -/ ._'--:U B.g E R DEPTH i,IER._--.:iJF.'ED .3UB.SER CDDF.:D IitRTE.Z DER,'[H :-:.' '," 3UB-.SEFt ;iEPTH - 103. 233. 330. 433. 533. 603. ,'-"33. 833 · 930. . 1033. 1103. 1200. 1330. 1403. . _ 1'--, O 3 · 1633. 1703. 1833. 1930. :'OOa :'130 L-- · 2200 · --'.33 2400. :'50;.* L-- ! .- · 2600. 2730. 2~ 00. 2900. 3030. .~1 O0. 3203. 9.33 O. 3400. · ~:5 O O. :_--:6 O O. 3703. ,::-'33 O. ._--o o a. 4000 · 4100. 4200. 4._:: 00. 4400. 45,]0. 46 0'3. 4 70 0. 4;3 ,) O. 49 33. '-_-'-00 O. 51,33. 52;,3. '2, :: J ,_;. 'S: ~ ,j ,.t ,, 57 03. :5 :{: 0,3 . '593 O. b d .J d. i,IEF~.-'.:iJDE D DEPTH 216. 316. 416. 516. 616. 716. 816. 916. 1316. 111; · 1216. 131;'. 1417. 1517. !6.17. 1717. 18 l:_:: · 1920. :'323 L.. · 2127. :'.3 :' 2343. 2453. 256,4. 2680. -~:'79.3 . 292,]. 3346. 3176. 3.313. 3448. 35'3. I. 374-::. 39 04. 4 074. 425.3. · 44-.3G. 461':' i... 479 3. 5176. o:5:5.3. 5742. 5'3.23. 6105. ,:_.~'~ I. 64 u=~ -::. 667;3. ,_:.;_--:64. 734.3. 72.30. 744 ,]. 7'z'-: _~ ,3 . 7 7~S =',. 7'3 3._--;. 2;! .] 2. ;_:I 2 :'-" .?. .3 4-iE.. .Si_IBSEFt CDEIRDIi'~t~TE.E:.. ,,",, ! 1 . ;_::9 4.6. 9 77 6, 3.6 5 9.0.3 4.5.3 I I. 2 ,] 5.4 O 1.3..-::7' 6, .28 1:2, ::,::, 7 16 17 ~:' · · ! L-- ;_--: . 04 1 '3. . ;---: .'q 1. ,..,_ .:':' 0~-'._ '~. 79 24 :'.--: 1 3.67 26.40 11 . :_--,4 2:3.57 !~.:'. 42 .3 ,'~... ,'-"4 13..-:: 3 .3,--'. 92 14.18 3:7-,. 17.46 39.79 24. :33 51.68 .30.44 71.03 35.54 93.0 4 3.34 1 ~,:'. 77 42. F,;_:: 156,. 02 44 .,Bi 194.96 4 G. A =, 241 . :-::.-:: 49. :50 29. 6,..3.-:; 6 0.16 .--:5.-:;. 8'3. 74.07 416.00 ;37.79 4 ;_--:.3.._--: 7 10 2..3.-:: 5:5 ;~. 14 117 . 75 6.39. ;3'3. 13;3.21 727. 167.02 8!7.42 2 3.3.57 '3.1.3.68 241 .9.8 1 021 . 1 2 F-; 2.85 11.3'3.. C-: 7 32~ . 6.3 1269. ,.. · 376.12- 141 :]. 75 42:'5.7'3. 1554.99 46 ;3.46 16. 9._--:. 79 5 ;] 2. ;_::4 1 ;_::41 · 11 53 '3.. 4 ;_:; 19'~ '9. ;--; 4 :376 . 09 215 ;:,. 4 ~:, 1.3. ;34 231 ;2:. 43 6:_--, 1 . 46 247::3.12 6;_::'3.. 6,2 ,:'6,2::-.,. 4;3 727.,_:' ,]_ 277 O.. 77 765.0:5 291 ;3.19 ,~'" ,]. G . 4 ;3 .':;_ ,]_ ,:, 9. C': 1 ;_--:47.93 .::22;_::. ~ 1 ;3 ;3'3.. ,] 1 .2.3'~ 0. C-: 2 -- -- -- · ! 'P2'.3.2:'5 .'~:-',4.:~ --',- 95,2.9 ;3 '- .36 '34,. 7' 6 9:38.6,--' 384.3. ,2.3 I ,].2 ;:: .S--' --:"~ --: '~ ,] ,] ! ,]']:;3..3 9 4 [ 3.2. 1 ,]'32. L 3 42 ,..-4 ..:-4 [124..3g 4411 I I =} . 7';:-; 4 _--,4:~ .~,6 I 1:3 ,'_,. :3 O 46;3 O. 4'9 1 ~ 0',--'. ? O 4:31 ,--'. 7 ! 1234.15 494~ .6'P 126t .72 507;3.20 · ............. .. ,J C. ~..:. ~-. '_-',4,. 0 0. '7"' ~'~ 0. i ,)'_'5-, F: .~: 9 4 1 --:.:: .... .55,3 ,]. 7'766. i ,)-_~,--'. ! ,3 4,.~74. .---'6 O ,_'). ?'.:'. 3,::. [ 124. ~:~ 44 1 t-. 2,2 57 00. .31 0.::. I ! :-'] 3. ,.-'~ 4.---'---'4.---'. ~,6 :-: '3.30. J-'. 4 ~ G. i ,2 ,'! ?. 7.- ,3 4 C-: 1 ,?. 6:,3 ,-, 0 '-~,: l :' ...... -, ,--. 1:'34,.. 1.5 494: · I.._ · _ .. 6. I ,30. ,37 :~: 3. 1261 . 7' 2 5,3 ,--';~'-. 2 0 6_',2 00. :_--,'~6,2. ! 29 0. ~ ,--'- :-,,-'~,z.'. '~._--: G 3 00. 914 ?. 1 .:: 2 ..',. :37. :5.3 ? G. 7. G 4 00 .- ~ 32 -~ l ._::'--] ,'~ ,3 ,-~ :--.:--'] ~-- ...... "· -' · - - ,'3 :-_-, ,30. '3. :~ 00. l .--: 7. 7.. ~:-,,:z: "_'JTG 1 . '~ 0 ,:',G 00. ~GG 0. 14,3.3.7.'9 :'-i ?c--:.3.7.7. 6,"7' 00. 9~_:: 1. `2. 142 ?..3:_:: :.',:::94. 6~_--:. 00. 9'357'. 145 0.0;3 ::,'~'~ ?. 7.1 69 00. 1.309 ?. 147.`2.1,2' 6,3'3._::. 9 0 ? O O O. 1 0C-'34. 14 9J-'. 5._-'3, 61 :_--:4.1 7'1 CIO. 1 8.36,4. 151 0.7.3 6,~6G .,:'? ,20 ,', 1 849 0. 1 u,,-' ,-'. 66 G.'-:4 0.94 7-_,'00. ! 06,14 · 1545.3,_": 641 ,..:'. 05 7.4.30. 1.374 O. 156,4.1.3 ,S4c::5.44 7. 5 ,'~ 0. 1 0 ~36, :::. 1 :-'] :::.3.47. 6 :-'] 6,,.Y. ? 6 00. I 0'~ 99. 16 04. ~:.3 G 64 :_=,. 6 0 7. ? ,30. I ! 1 .'-: 2. 1 ,:, ,2 Z'. :--: 9 6, ?,:' 9. ,23 7.E:,) 0. I 1,26,4. I65,--' .6,1 6:311 79 .) 0. 11.3'~.,,,,. 1 ~-', ~_~: 1 . 19 G ;39 ! . 94 ~30 O O. 1 1 ~-'],2"-~. ! 7.1 1 . 64 6 '~. 6 ~::. . _ '" G: 1 0 O. I I ;35._--:. i ? 41 . G: 4 7. ,'~ 4.3.7.`2 F-:,2 00. 11 ?:31 . 1 ,? 7.,:'.._--,'.3 71 16. Di::l '~'DU i.,.!]'.~.:H TD F'F.:EICE..--:.-':: FIH'," i'IEI~:E i.,.~ELL._.:: DF.: TD ~:EF'F.:DCE._=t._..-.' U..--:]:i'i3 FI T~[I-~-~::Ei'tT i'!ETHEID DF C:FtL,_-:ULFiT]:E]i't ~'T',"PE 'r'E.'-.: THIS b.IELL i'] D > -'i't Di~TF~ ~"~ ~°' ~'-~ STATE OF ALASKA RE~. &- 1-70 OIL AND GAS CONSERVATION COMMrl-i'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WKLL WELL NAME OF OP~%ATOR SHELL OIL COMPANY 802?0 3. A~D~ OF OPERATOR 1700 BroadwaT, Denver~ Colorado 4. ~ca'no~ o~ w~.,.,~ SUBMIT IN DUPLICATE Platform A, Leg 1, Conductor 1 1632' N & 437' W of SE corner of Sec 11, T8N, R13W, SM APl ~UAfERICAL CODE 50-133-10081-01 LEASE DE~IG1~TATION AND S~IAL NO. ADL 18754 IF INDIA~. A~Yi~ OR TRIBE NA~E ~. L~IT F.~ OR LEASE MGS "¢" Pool o~ Sec ~ - T8~-T~3~-S.~. 12 P~IT ~O. 77-55 '"':Il RF~:~ORT TOTAL DI~TH AT F2~ID OF MONTH, CIrIANGE~S IN HOL~ SIZe, CASING A~ SET ~ VOL~ USED. P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ J~K ~ HO~ AND SIDE-~CKED HO~ ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ CO~ITIONS OPERATIONS FOR JANUARY, 1978 1. Drilled 6-1/2" hole to 12,000' 2. Logged w/DIL/SFL & BHC-Sonic 3. Ran &eemented 5-1/2" liner @ 11,970' w/200 sx Class "G" 4. Logged w/ CBL/CLL, GRN 5. Set Liner seal assembly 6. Ran tubing and packer 7. Perforated as follows: (4'~i~h~les/ft) 11,716' - 11,768' HR/HZ 11,570' - 11,690' HR/HZ 11,375' - 11,556' HN/HR 11,319' - 11,361' HN/HR 11,250' - 11,313' HN/HR 10,947' - 11,225' HK/HN 10,900' - 10,922' HI/HK 10,882' - 10,888' HI/HK 10~J76' - 10,819' HI/HK 10,686' - 10,740' HE/HD STATUS: 1/31/78 Well Completed. RECE i/ D A~hor,q.~o hF' 1~. ~ he.by ~if~t t ~ ................. ...... ~,, _ ~ _.~ .... ,,~ NOTE--Report on t is o~ · required for .each calendar ~nth~ regardless of the ,tatus of operations, and must ~ filed in duplicate with oil and gas conservot~n commi~ee by the 15~ of the succ~ding mon~, unle~ otherwis~ directed. NMW. OIL WELL s a ~.%L- C~EVRON USA-AM6C'O-ARCO FROM: 10/13/77- 3/21/78 · . MIDDLE GROUND SHOAL LEASE MGS WELL NO. A- 12- ! DIVISION WESTERN ELEV 116~' DF COUNTY STATE ALASKA MIDDLE GROUND SHOAL A-12-1 (A-32-11) (D) Platform A 12,200' "G" Pool 116 ' DF (A-32-11) (D) Platform A 12,200' "G" Pool 116' DF A-12-1 (A-32-11) (D) Platform A 12,200' "G" Pool 116' DF A-12-1 (A-32-11) (D) Platform A 12,200' "G" Pool 116 ' DF A-12-1 ' (A-32-11) (D) Platform A 12,200' "G" Pool 116 ' DF A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF "FR" TD 11,052. PB 9420. Funds' are provided to plug & abandon A-32-11 & drl A-12-1 from same csg. 10/12/77 RU. OCT 1 3 1977 TD 11,052. PB 9420. Prep to NU. RU & circ'd well w/570 bbls; 225 in hole, 161 in pits, 100 in storage & 84 bbls mud lost. Mud: (.613) 11.8 x 43 O{~T 1 ~ 1977 TD 11,052. PB 9420. Test'g BOP's. Chng"d to 2-3/8 rams, installed BPV in tree, ND tree & NU BOP's. Mud: (.613) 11.8 x 43 TD 11,052. PB 9420. Circ'g btms up. Pulled & LD 195 jts 2-3/8 tbg & found 3/4" hole in short string @ 6088'. Screwed into long string & tried to pull pkrs loose. RU & circ'd tbg; pkr came loose or tbg prt'd. Mud: (.608) 11.7 x 43 TD 11,052. PB 9420. Mak'g up fish'g tools. Pulled 5 its tbg & stuck in hole 193' up. Ran dialog freept & could not get below 6455. RIH w/jet cut'r. POOH & LD 213 its 2-3/8 tbg, pkr & mndrl. Made up fish'g tools on 3-1/2" pipe. Mud: (.608) 11.7 x 43 0CI 1 ? 1977 TD 11,052. PB 9420. RU to run WL. TIH & could not get below 6358' w/5-3/4" OD overshot. Circ'd for bit. RIH w/6" bit & csg scraper; could not get below 6355. Bit showed csg flat or prt'd. Trip'd for 4-11/16" OD overshot. Latched onto fish; unable to circ thru fish or move fish. Found top fish @ 6508. 0CI 1 8 1977 Mud: (.592) 11.4 x 45 TD 11,052. PB 9420. Perf'rs RIH. Ran 'Dresser WL & sh0-t tbg off @ 6831. Circ'd btms up. POOH & LD fish; rec'd 310.78' 2-3/8 tbg. RIH w/4-11/16 overshot. Ran dialog out btm tbg 50'. Tested thru tbg w/1500 psi 10 rains; bled to 1450. Top of fish 6831 WL. Mud: (.592) 11.4 x 45 0CY 1 9 1977 TD 11,052. PB 9420. Prep to drl cmt. Dress Atlas perf'd 4 holes thru tbg @ 7166-68. Press tested holes to 2100 psi; bled to !850 in 15 mins. LD fish'g tools & RIH OE. Circ'd cmt & POOH. RIH w/bit & scraper to polish cmt w/OE 3-1/2" DP @ 6831. BJ put 10 BW ahead of 115 s× + .1% R5 (15.7-15.9) slurry. CIP 1:30 p.m. 10/19. Mud: (.592) 11.4 x 45 OCT 2 0 1977 A-12-1 (A-32-11) (D) Platform A 12,200' "G" Pool 116' DF A-12-1 (A-32-11) (D) Platform A 12,200' "G" Pool 116 ' DF TD 11,052. PB 5885. Bld'g spud mud. RIH & tag'd cmt @ 6346 & polished off to 6363. ~' : cmt ret @ 6203, circ'd & cmt'd Tested 7 csg to 1000~£,0 mins, ok. Brk down thru ret 3 B/M @ 900 psi. BJ put 5 BW ahead 75 sx "G" neat slurry. Displ'd w/22 bbls & sqz'd 2-1/2 B/H w/800 psi. Final press 1200 psi. CIP 4:15 p.m. OCT ~ 1 1977 TD 11,052. PB 5885. No report. Ol~T 2 4 1977 A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' TD 11,052. RIH w/csg cut'rs. Tested BOP's & blind to 2000#, rams 1000#, hyd 1000#, chk & kill line valves 2000#. Mud: (.462) 8.9 x 42 TD 11,052. NU BOP's. Cut csg @ 1805'. LD 7" csg. With cmt sub @ 1912' on 3-1/2 DP, BJ put 20 BW ahead 400 sx Class "G" w/2% CaCl2. Displ'd w/9 BW. Est top of cst 1457 ' . Mud: (.462) 8.9 x 42 TD 11,052. Drlg cmt. Tested pipe rams to 3000#, blind rams to 1200#, hyd to 1500#, chk & kill lines to 3000#. Tag'd cmt @ 1371'; CO to 1650'. Depth 1802; cut 152', Dyna drlg. RIH w/dyna drl #1; kick off pt 1650'. Survey: 1652'/2 deg 45'/N44E, 1684'/ 4 de.g 25'/N35E, 1715'/6 deg 0'/N36E & 1747'/7 deg 15'/N36E. Mud: (.462) 8.9 x 38 x 12 00T 25 1977 Depth 1816; cut 14'. Surveying. Dyna drld to 1816. RIH & hit cmt @ 1375; reamed & CO to 1465. Drld cmt from 1374- 1640. Reamed & dyna drld from 1640-1816. Mud: (.473) 9.1 x 42 x 9.8 A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' · Depth 1916; cut 100'. Run'g gyro multishot. Drld to 1816 & surveyed w/gyro. Drld to 1840, ran gyro & chk'd w/magnetic survey. Drld to 1904, circ'd clean & chk'd w/both surveys again. ~M~'de wiper run to shoe. Ran gyro survey & tools malfunctioned on 1st 2 runs; run'g 3rd time. Gyro: 1816'/ 9 deg 45'/N25E, 1840'/10 deg 45'/N20E, 1904'/12 deg 15'/NilE. Mud: (.478) 9.2 x 38 x 9.8 OCT 2 7 1977' Depth 1974; cut 58'. Run'g gyro; RU EYE tool & drld to 1974. POOH w/EYE tool. PU Sperry Sun Gyro & chk'd shot @ 1938; survey no good. Reran & it didn't chk w/EYE tool. Ran a 3rd time; showed tools to be bad. Chng'd gyro. 'M~ad: (.478) 9.2 x 38 x 9.8 OCT 2 8 7§77 Depth 1974; cut 0'. POOH. Found top of cmt @ 1458; no stringers. CO to 1642; had good cmt. POOH & chng'd bit. RIH & drld to 1672 & circ'd clean. POOH to PU dyna- drl. Mud: (.473) 9.1 x 37 x 10.5 Depth 1974; cut 0'. WOC. Ran new gyro; proved that orig gyro was not read'g true. Sgl'd in 5" DP to repl HWDP. RIH OE to 1970 & circ'd btms up. Pmp'd in 20 BW ahead. Mixed total of 339 sx Class "G" w/37 BW w/2% CaCI2; total of 369 cuft 16.2# slurry (including 50% excess on 9-7/8 hole). Foll'd w/2 BW & 23 bbls mud (25 bbls displmt). Cmt slurry in place 10:55 p.m. POOH & sg!'d down 36 its DP. Survey: 1938'/13 deg 15'/N13-1/2E Mud: (.473) 9.1+ x 38 x 9.8 ~T .3 I ~77 A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 13-3/8" csg @ 1642' !0/30 - No report. ( .... oepth 2270; cut 323'. Run'g survey. Drld & surveyed to 2148. POOH & chng'd BHA. RIH & reamed 1939-2148. Survey: 2036'/14 deg 5"/NllW, 2099'/16 deg 15"/NSW, 2148'/17 deg 45"/N7W & 2207'/19 deg 0"/N2W. Mud: (.478) 9.2 x 42 x 10.5 NOV P 1 1977 Depth 2711; cut 441'-. Chng'g BHA. Survey: 2270'/20 deg 45"/N03E, 233'/23 deg O"/N03E, 2394'/25 deg 0"/N03E, 2458'/27 deg 30"/N02E, 2501'/28 deg 45"/N01E, 2562'/29 deg 45"/N06E, 2623'/30 deg 0"/NILE. Mud: (.478) 9.2 x 40 x 10.2 NOV 02 197~ Depth 3245; cut 534'. Survey'g. Reamed 2489-2711. Drld & surveyed to 3203 & POOH. RIH w/dyna drl. RU eye tool & drld & surveyed. Survey: 2755'/32 deg 30"/N12E, 2816'/33 deg 45"/N12E, 2907'/35 deg 15"/NilE, 3001'/37 deg 45"/NilE, 3095'/39 deg 45"/NILE, 3190'/41 deg O"/NiOE. Mud: (.483) 9.3 x 42 x 10.4 NOV 03 1977 Depth 3482; cut 237'. Drlg. Drilled to 3370' w/eye Tool Reamed 3203 to 3370. Survey @ 3378'. Survey: 3278;/42 deg 15"/N14E, 3378'/43 deg 15"/N22E, 3440'/44 deg 30"/N21E. Mud: ('.483) 9.3 x 40 x 10.8 x 800. Depth 4130; cut 648'. Trip'g. Survey: 3533'/45 deg 45"/ N21E, 3628'/48 deg O"/N20E, 3722'/50 deg 0"/N19E, 3877'/52 deg 15"/N19E, 4001'/54 deg 0"/N19E, 4123'/56 deg 15"/N19E & 4256'/56 deg 45"/N19E. Mud: (.483) 9.3 x 41 x 9.8 Depth 4492; cut 362'. RIH. Reamed 4070-4130 and drld & surveyed to 4492. Installed 16" picture nip for 13-3/8 test plug. Had to reseat several times. Tested hyd to 1500 psi. Tested pipe rams, blind rams, kill line valves, chk line valves, chk manifold & kelly to 3000 psi. Made up dyna drl & RIH. Mud: (.488) 9.4 x 40 x 10.2 ~0V 07 1977 A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 .~,(D) Platform A "o" 116 ' DF 13-3/8" csg @ 1642' Depth 4756i cut 264'. POOH. Survey: 4599'/54 deg 45"/ N14E, 4662 /55 deg 30"/N13E & 4756'/58 deg 0"/N13E. Mud: (.504) 9.7 x 40 x 10.4 Depth 5234; cut 478'. Drlg. Survey: 4853'/58 deg 45"/ N13E, 4978'/58 deg 15"/N13E & 5135'/58 deg 30"/N13E. Mud: (.520) 10 x 42 x 9.8 NOV 0 8 1977 Depth 5605; cut 371'. Drlg. Survey: 5263',/,58 deg 46"/ N13E, 5415'/58 deg 45"/N14E, 5470'/58 deg 15 /N13E & 5605'/ 57 deg 30"/N14E. Mud: (.504) 9.7 x 42 x 7 NOV 09 1977 Depth 6029; cut 424'. Drlg. Reamed 5837-5860. Survey: 5760'/56 deg 30"/N15E & 5860'/56 deg 0"/N14E. Mud: (.509) 9.8 x 38 x 7 NOV ! 0 1~77 Ail2-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12 ;200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' · A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' Depth 6417; cut 388'. Drlg. 'vey: 6035'/56 deg 30"/ N15E, 6193'/57 deg 30"/N14E & ~o54'/58 deg 30"/N15E. Mud: (.509) 9.8 x 39 x 7 NOV 1 1 ",977 Depth 6555; cut 138'. Drlg. Survey: 6480'/59 deg 45"/ N14E & 6541'/59 deg 45"/N14E. Mud: (.514) 9.9 x 38 x 6.8 Depth 6740; cut 185'. Drlg. Survey: 6604'/59 deg 0"/ N14E & 6663'/58 deg 30"/N15E. Mud: (.520) 10 x 42 x 7 Depth 6913; cut 173'. Drlg. Survey: 6764'/5~7,~15"/ N14E & 6881'/57 deg 0"/N13E. ~' ~ & Mud: (.520) 10 x 42 x 6.8 Depth 7209; cut 296'. Drlg. Survey: 7038'/57 deg/N14E & 7195'/56 deg 45"/N13E. Mud: (.520) 10 x 41 x 6.4 NOV 1 5 1977 No report. _.NOV 1 6 '~977 Depth 7446; cut 237'-,- Drlg.. Depth 7858; cut 412'. Drlg.- Survey: 7599'/56 deg 15"/ N13E & 7849'/54 deg 15"/N14E. mud: (.520) lo x 42 x 6.4 NOVl?1977 Depth 8117; cut 259'. Drlg. Washed & reamed 7774-7858. Survey: 8035'/53 deg 45"/N12E. Mud: (.525) 10.! x 45 x 6.2 NOV Depth 8248; cut 131'. RIH w/bit.. Survey: 8191'/54 deg 15"/NILE & 8248'/54 deg 0~/NllE. Mud: (.525) 10.1 x 43 x 6.4 Depth 8501; cut 253'. Drlg. Survey: 8409'/53 deg 15"/N12E. Mud: (.520) 10 x 41 x 6.2 Depth 8756; cut 255'. Drlg. Washed & reamed 8503-8563'. Survey: 8563'/52 deg 30"/NllE & 8720'/54 deg 0"/N12E. Mud: (.520) 10 x 43 x 6.2 NOV g 1 ~977 Depth 8995; cut 239'. Drlg. 'Survey: 8936'/57 deg 15"/ NILE. Mud: (.525) 10.1 x 41 x 6.8 ~0V g g ]977 Depth 9274; cut 279'. Drlg. Survey: 9122'/57 deg 45"/ NllE. Mud: (.525) 10.1 x 40 x 6.8 NOV g ~ ~977 A~12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 ~%(D) Platform A (~!i2,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508 Depth 9427; cut 153'. Drlg. ~"'rvey: 9295'/56 deg 15"/ NILE. Mud: (.525) 10.1 x 40 x 7 Depth 9703; cut 276'. POOH. Survey: 9486'/53 deg O"/N12E, 9673'/49 deg 30"/N12E. Mud: (.525) 10.1 x 42 x 6.4 Depth 9851; cut 148'. Drlg. Survey: 9829'/47 deg 15"/ N12E. Mud: (.520) 10 x 42 x 6.4 Depth 10,077; cut 22'6'. Circ'g for short trip. Survey: 9983'/45 deg 15"/N13E. Mud: (.525) 10.1 x 41 x 6.4 Depth 10,219; cut 142'. Drlg. Survey: 10,161'/43 deg !5"/ N13E. Mud: (.520) 10 x 45 x 15 NOV 2 ~ 1977 Depth 10,365; cut 146'. Drlg. Survey: 10,296'/39 deg 45"/ N12E. Mud: (.525) 10.1 x 43 x 6 NOV Z 9 1977 Depth 10,525; cut 160'. Prep to run csg. Survey: 10,421'/ 37 deg 45"/Ni3E. Mud: (.520) 10 x 43 x 6.4 NOV 3 0 ~977 Depth 10,525; cut 0'. Working on BOP. Ran 7-5/8" csg to 10,508' Pmp'd 15 BW ahead of cmt. Pmp'd 400 sx Class G w/47 BW ~/.75% D31, .2% D19 & .1% D24L. Total of 456 cu ft slurry. Had good returns, but lost approx 50 bbls on last prt of job. Drop'd top plug & displ'd @ 10 B/M for total of 480 bbls; 10 bbls over calculated vol. Did not bump plug; float equip would not hold. Closed cmt'g head. CIP 10:45 p.m. Survey: 10,525'/35 deg/N13E. DEC 0 1 1977 Depth 10,525; cut 0'. LD DP. NU. Tested tbg spool to 3000#, ok. DE0 0 £ 1977 Depth 10,525; cut 0'. LD DP. 15-1/2 hrs LD DP & 8-1/2 hrs thaw'g lines. Depth 10,525; cut 0'. PU 3-1/2" pipe. Lost steam press, froze & heater busted. Chng'd heater, thawed lines & tested BOP. Depth 10,525; cut 0'. PU 3-1/2" pipe. Bearing went out on spear on brk; had to stop for repairs. PU DP until flwline froze; had to thaw out w/steam. 0[0 05 1977 Depth 10,525; cut 0'. IIH. Fin'd PU 3-1/2 DP. Tag'd hard cmt @ 10,338-.& CO. to 10,470. Tested csg to 2000 psi, 6k. Circ~d clean, POOH & chng'd BRA. DEC 0.6 ~977 A.-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) PlatfoTM A~ 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' · . A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 'A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-~5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' Depth 10,555; cut 30'. Drlg. ~.,~urvey: 10,555'/35 deg 15"/ N17E, ~ Mud: (,592) 11.4+ x 44 x 6.8 0~ 07 ~77 Depth 10,617; cut 62'. RIH w/bit. Survey: 10,617'/36 deg 15"/N16E. Mud: (.598) 11.5 x 43 x 6.2 BEC 0 8 1~77 Depth 10,825; cut 208'. POOH w/bit. Mud: (,592) 11.4+ x 45 x 6 0£~ 0 ~ 1°~77 Depth 10,825; cut 0'. Working stuck pipe. Stuck pipe w/bit @ 10,805. Worked pipe & circ'd (lowered mud wt to 11.1 ppg). Spt'd 45 bbls oil base (10.4#). Mud: (.577) 11.1 x 40 x 4.8 (Oil 1%) Depth 10,825; cut 0'. Run'g dialog. Circ & cond mud & worked stuck pipe. Dialog stop'd @ 5200'. Mud: (.577) 11.1 x 40 Depth 10,825; cut 0'. Cond mud to 10.7#. Ran dialog & found pipe partially stuck @ btm of jars @ 10,550 & free @ top of jars @ 10,517. Made 3 attempts to back off @ 10,486 (top 1st j t HWDP). TOOH & PU fish'g tools. RIH & screwed into fish. Circ~d & cut mud wt. Mud: (.556) 10.7 x 45 x 6.8 0~.C I 2 1977 Depth 10,825; cut 0'. POOH for tester. Circ & cond ~ud & ]arid on fish. Spt~d 45 bbls diesel & mill free. Jar'd ~n fish. Circ & cond mud. Ran Dialog; top of fish @ 10,486' Mud: (1546) 10.5+ x 45 x 6 (Oil ~17o) DEC 1 ~ 1977 Depth 10,825; cut 0'. Circ & c~nd mud. RIH w/Johnston tester. Latched onto fish. Set pkr @ 10,476 (strong blw 3. mina) & jartd on fish. Reset pkr. (weak blw 5 mins)& Jar'd on fish. Tried to release overshot; unable to get loose. Mud: (.551) 10.6 x 50 x 5.8 (Oil 11%) O~C ! 4 1977 A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' Depth 10,825; cut 0'. RIH w/fis.h'E tools. Backed off safety Jt & POOH w/tester tools. RIH w/fish'g tools & circ~d btms up. Tried to screw Back into safety jt. TOOH to overhaul safety ~t. Mud: (,551) 10.6 x 44 x 5 (Oil 11%) DEC 1 5 1977 Depth 10,825; cut 0'. POOH w/backoff. RIH, screwed into safety sub, Jar~d & attempted tm release overshot; couldn't. Circ& cond mud & POOH. RIH w/5-3/4" over- shot & latched onto fish. -Ran dialog; freept shows top stab & 3 DC~s free. Backed off @ top of #2 stab; top of fish @ 10,643. OEO I ~ 1977 Mud: (.556) 10.7 x 45 x 5 (Oil 11%) A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' Depth 10,825; cut 0~. WOC. p~,T w/fish. RIH w/OE DP & :irc & cond mud for plug. Wit .. -1/2" OE DP @ 10,643' BJ put 10 BW ahead 100 sx 16-16.5 slurry. Displ'd w/1 BW 65 bbls mud. Pulled 6 stds &-rev'd out (no cmt). Pmp'd away 2-1/2 bbls @ 1000 psi. POOH 45 stds. SI & press'd to & held 500 psi. CIP 4:30 p.m. Est cmt top @ 10,175'. Mud: (.561) 10.8 x 42 x 5 (Oil 11%) Depth 10,582; cut 0. Circ & cond mud. Tag'd cmt @ 10,566. Drld soft cst to 10,580 & firm cmt to 10,582. Mud: (.556) 10.7 Depth 10,200; cut 0'. RIH to CO cmt. Circ & cond mud for plug #2. With 3-1/2" OE DP @ 10,582, BJ put 10 BW ahead 70 sx 16-16.5 slurry + .75% D31 + .002% D19 + .01% D6 equalized w/1 BW & 65 bbls mud. Pulled dry. CIP 11:30 a.m. Est top @ 10,193'. Mud: (.561) 10.8 x 48 x 6 <Oil 9%) OEO 1 9 1977 Depth 10,528; cut 0'. RIH w/dyna drl. Circ'd & CO atringers to 9023;' bridge @ 9864-9988. Tag'd cst @ 10,503 & CO to 10,528. Mud: (,561) 10,8 x 40 x 7 (Oil 9%) DEC 2 0 1977' Depth 10,557; cut 29'. Survey'g @ 10,557'. Dyna drld & circ & cond mud. OEO 2 1 ]9?? Depth 10,667; cut 110'. Drlg. Survey: 10,557'/35 deg 45"/N16E & 10,598'./36 deg O"/N25E. Mud: (.546) 10.5 x 40 x 6.4 (Oil 9%) O[O Z'2 1977 A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DR 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' · .12/22: Depth 10,834; cut 167'. Drlg. Ream 10,641- 10,707 ' . Mud: (.577) 11.1 x 42 x 6.2 (Oil 8%) 12/23: Depth 10,942; cut 108'. Drlg. Ream 10,627 - 10,867'. Survey: 10,707'/37 deg 30"/N13E & 10,867'/39 deg 45~/N15E. Mud: (.577) 11.1 x 48 x 4.2 (Oil 8%). 'I2/24: Depth 11,072; cut 130'. Change BHA. Survey: 10,979'/41 deg/N14E, 11,041 '/41 deg/N15E, 11,072'/41 deg/N16E. POOH. Mud: (.577) 11.1 x 43 x 4.4 (Oil 6%) 12/25: Depth 11,233; cut 161'. Drlg. Reamed 10,927- 11,072'. Survey: 11,170'/40 deg 45"/N16E. Mud: (.577) 11.1 x 46 x 4.4 (Oil 6%) 12/26: Depth 11,324; cut 91'. Survey. POOH. Reamed 11,195 - 11,243'. Mud: (.582) 11.2 x 48 x 4 (Oil 6%). OEO A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' Depth 11,443; cut 119'. Drlg. POOH. Reamed 11,328-11,388. Survey: 11,324'/40 deg 30"/N20E, 11,388'/40 deg/N21E, Mud: (.582) 11.2 x 46 x 3.8. (Oil 5%) DEC 2 8 1977 A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' Depth 11,553; cut 110'. Drlg. Survey: 11,508/39 deg 30"/N22W. Ream 11448 to 11508. Mud: (.582) 11.2 x 45 x 4.4. D~% ~7~ A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" cs§ @ 10,508' JAN. ~ I978 A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' Depth 11,605; cut 52'. Pulling W.L. Dropped Survey. POOH to log. RIH DIL. Found TD at 11601 WLM. Ran Sonic Calip. Tools sticking @ 10700'. POOH. HR top @ 11229, bottom of HZ @ 11560. Mud: (.582) 11.2 x 48 DEC B 0 1971 12/30: Depth 11,695; cut 90'. Drilling. Mud: (.582) 11.2 x 46 x 4.2. ( Oil 6%) 12/31: Depth 11731; cut 36'. Drlg. Dropped Survey. RU Log DIL. Survey: 11700/38 deg 15"/N22W Mud: (.582) 11.2 x 45 1/1: Depth 11,806; cut 75'. Drlg. Dropped Survey. Reamed 11,696 to 11,786. Survey: 11,786'/38 deg/N24W. Mud: (.577) 11.1 x 47 x 3.8. (Oil 6%) l/L2: Depth 11,870; cut 64'. Drlg. Washed out between #3 & #4 jr. Dropped survey. 14~ hour drilling. Survey: 11884/37 deg 15"/N24E Depth 11,923; cut 53'. Reaming. Mud: (.577) 11.1 x 45/4 (Oil 5-1/2%) JAN O't 1978 Depth 12,000; cut 77t. Log'g. Survey: 11,344'/37 deg 15"/N24E, Mud: (.566) 10.9 x 49 x 4 (Oil 6%) A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ ~642' (i!~i~: 7-5/8" csg @ 10,508' ~.- Depth 12,000; cut 0'. Run'g liner. Ran induction log & Sonic. Circ & cond mud to run liner. Survey: 11,844'/37 deg !5"/N24E, Mud: (.572) 11 x 49 x 3.8 (Oil 6%) JAN 06 1978 A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' @ 11,980' 5-1/2" liner A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-i/2" liner @ 11,980' A-i2-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' A-12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' .Depth 12,000; cut 0'. WOC Cm_~' 5-1/2" liner w/200 sx lass G w/.75% D31 + .2% D{9. t~. _g down @ 12. btud: (.572) 11 x 49 x 3.8 (Oil 6%) Depth 12,000; cut 0'. GIH w/sqz tool. RIH w/DC & HW & LD HW & stabs. RIH w/bit; no firm cmt on top of liner. Circ'd out tr of cmt. Tested liner top after WOC 16 hrs; would not test. POOH. RIH w/Johnston sqz tool. Mud: (.572) 11 x 49 x 3.8 (Oil 6%) Depth 12,000; cut 0'. Dry test'g liner. Set sqz tool @ 10,235 & press'd to 2800 psi. POOH. RIH to 650' & press'd to 2000 psi. POOH. RIH w/bit & scraper to 10,302. Circ & cond mud & POOH. Made up jOhnston test tool & RIH. Set pkr @ 10,248 & opened tool. Mud: (.572) 11 x 49 x 3.9 (Oil 6%) JAN 09 1978 Depth 12,000; cut 0'. Prep to run CBL. Ran dry test on liner top & POOH. RIH w/4-3/4 bit to 11,895. Circ'd & displ'd mud w/8.5# inj wtr. Tested csg & liner top to 3000 psi 1 hr. POOH to run CBL. Mud: (.572) 11 x 49 x 3.9 (Oil 6%) 3~N % 0~978 Depth 12,000; cut 0'. Log'g. RU Dresser Atlas to log. Tested lubri to 2000#. Started run'g CBL under 1050#; press 'tool hang'g up @ 11,750'. Ran junk basket. Reran CBL w/2050# press. Mud: (.442) 8.5 J~ 1 1 ~978 Depth 12,000; cut 0'. R1H w/tbg. Fin'd run'g CBL & GR neutron logs. RIH & LD 2-7/8 tbg. R1H w/Burns lead seal & set on top of liner. LD 3-1/2" DP & 4-3/4" collars. Mud: SW JAN 1 ~ 1978 Depth 12,000; cut 0'. Set'g WL valve. Ran tbg in hole w/prod pkr. Installed ball valve & tested. Spaced out tbg & RU WL unit. Now run'g W-L valve in btm of tbg to set pkr. Mud: SW J~N ~ ,~ ~9~. A-12-1 (D) Platform A 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' JAN 1 6 '~978 (D) Platform A 12,200' "G" Pool 116 ' DF i3-3/8" csg @ 1642' 7-5/8" csg @ i0,508' 5-1/2" liner @ 11,980' 1/13: Depth 10,895; cut 0'. Prep to set pkr. Removed BOP & installed tree. Tested to 3000#. Mud: SW 1/14: 10895; cut 0'. Perforating. Atlas perf'd w/4 shots/ft @ 11757-11759'. Mud: SW 1/15: Depth 10895; cut 0'. Perforating. Reran GRN 13 hrs perforating & gas lifting well. Depth 10895; cut 0'. Perforating. JAN A-~ 12-1 (D) Platform A 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' A-12-1 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' 12,000; cut 0'. No repo{~' Depth J~,N 1 8 197~ TD 12,000. PB 11,895. 1/14 @ 2 p.m. Run f~l - perf'd 11,757-11,758 (1' w/4 shots/ft). Prior to 1st perf, tbg had been gas lifted dry. Prod 6 bbls total from 9:05 p.m. 1/14 to 2 p.m. 1/15. Cut drop'd from 90% wtr to 40%. 1/15 2 p.m. Run fi2 - perf'd 11,747-11,768 (4 holes/ft). Well didn't prod any fluid while lift'g betwn runs. 5:20 p.m. Run ~3 - perf'd 11,726-11,747 (4 holes/ft). Again no fluid betwn runs. 10 p.m. Run ~4 - perf'd 11,716- 11,726 (4 holes/ft). HR-HZ lower on prod. 11:15 p.m. 1/15 prod to 9:40 a.m. 1/16. Prod 35 bbls total - 80 BDG 3% - 78 BDO, 1008 MCF inj'd w/80 TP & 740 CP. 1/16 11:15 a.m. Run ~5 - perf'd 11,680-11,690 (4 holes/ft). 4:20 p..m. Run ~J6 - perf'd 11,659-11,680 (4 holes/ft). 11:45 p.m. Run ~J7 - perf'd 11,638-11,659 (4 holes/ft). 1/17 3:25 a.m. Run ~J8 - perf'd 11,617-11,638 (4 holes/ft). 7:25 a.m. Run f~9 - perf'd 11,596-11,617 (4 holes/ft). 11:15 a.m. Run ~10 - perf'd 11,575-11,596 (4 holes/ft). l:40-p.m. Run ~11 - perf'd 11,570-11,575 (4 holes/ft). During above perf'g runs, well prod intermittently (while gun was below tbg tail & inside lubri). During this time (26.5 hrs) a total of 96 bbls gross was prod w/avg cut of 4%. Lubri press tested to 3400~J w/SW prior to each run. Ail perf'g done w/well on gas lift & prod'g. Ail rept'd depths are Schl DIL depths. Rig was released midnight i/i6/78. JAN 1 9 197B A-12-1 (~) 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB 11,895. Perf'g; details to be rept'd later. JAN ~ 0 1978 "G" Pool csg @ 1642' csg @ 10,508' liner @ 11,980' !00' "G" Pool ~ DF 3/8" csg @ 1642' rS" csg @ 10,508' [2" liner @ 11,980' !00' "G" Pool ~ DF 1/8" csg @ 1642' ~8" csg @ 10,508' ~2" liner @ 11,980' ~00' "G" Pool DF ~/8" csg @ 1642' '8" csg @ 10,508' = liner ~9 ii,980 TD 12,000. PB 11,~95. z~ .... ~ ......... to 8 a.m. 1/18. Initial avg cut 12%; after 98 bbls, cut 'd to 3.~~ 5 stabilized. Stabilized prod test (17 hrs)dr°p: 214 B~o - 3.5%, 206 BDO & 1009 b[CF inj (~ ]0# TP & 730# CP (33.9 deg AP1). Run #12-perf'd 11,545-546 (1' interval/4 holes). Prod well 10:20 a.m. to 9:20 p.m. for 124 bbls in 12 hrs. Stabl rate 248 BDG-1.5%, 244 BDO & 1008 MCF inj w/80# TP & 750# CP (35.5 deg AP1). Run #13- perf'd 11,535-556 w/4 holes/ft. 1/19 Run #14-perf'd 11,514-11,535 w/4 holes/ft. Run #15-perf'd 11,493-11,514 w/4 holes/ft. From 6:10 a.m. to 12:40 p.m. prod 93 bbls, 298 BDG-5%, 283 BDO & 1008 MCF inj w/80# TP & 740# CP (33.7 deg AP1). Run #16-perf'd 11,472-11,493 w/4 holes/ft. Run #17-perf'd 11,451-11,472 w/4 holes/ft. Run #18-perf'd 11,430-11,451 w/4 holes/ft. 1/20 Run #19-perf'd 11,409- 11,430 w/4 holes/ft. Run #20-perf'd 11,388-11,409 w/4 holes/ft. Run #21-perf'd 11,375-11,388 w/4 holes/ft. Completed HN-HR lower perfs. POOH for prod test. Prod well from 7:30 a.m. to 4:10 p.m. Well stablz'd & prod 215 bbls total - 8-hr test rate: gross 582, cut 4, clean 559, MCF inj 1008, MCF prod 442, GOR 790, chk 128/64, TP 100, CP 40 & AP1 35.8 deg. Run #22-perf'd 11,350-11,351; 1' @ 4 holes/ft. Put on prod test for wtr entry. Lifted well to 11:45 p.m. for total of 124 bbls w/.5% avg cut; no wtr entry. 1/21 Run #23-perf'd 11,340-11,361 w/4 holes/ft. Run #24-perf'd 11,319-11,340 w/4 holes/ft. When pull'g gun up, it stuck tight @ 9308 & could not free. Flwd well & pulled 1250#; tOol came free. Run #25-perf'd 11,298- 11,313 w/4 holes/ft. Run #26-perf'd 11,277-11,298 w/4 holes/ft. Run #27-perf'd 11,256-11,277 w/4 holes/ft. Run #28-perf'd 11,250-11,256 w/4 holes/ft. This completed HN-HR upper perfs. Put well on prod from 8 p.m. to 9:30 a.m. 1/22. 8-hr test after well stablz'd: gross 669, cut 1%, clean 662, MCF inj 1008, MCF prod 142, GOR 215, chk 2", TP 100, CP 735 & AP1 35.4 deg. Net prod gain from HN-HR - 109 BDO. 1/22 Run #29-perf'd 11,214-11,215; 1' @ 4 holes/ft. Prod well from 12:20 p.m. to 5:25 p.m. for a total of 150 bbls w/.l% cut. Run #30-perf'd 11,204- 11,225 w/4 holes/ft. Run #31-perf'd 11,183-11,204 w/4 holes/ft. 1/23 Run #32-perf'd 11,162-11,183 w/4 holes/ft. Run #33-perf'd 11,141-11,162 w/4 holes/ft @ 4:50 a.m. TD 12,000.' PB 11,895. No report. JAN S ~ 1978 TD 12,000. PB 11,895. No report. JAN 2 5 1978 TD 12,000. PB 11,895. No report; communications down. JAN 2 6 1978 A-12-1 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' 12,000. PB 11,895. No rep . A-12-1 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB 11,895. 1/23 Run #34 - perf'd 11,120- 11,141 (4 holes/ft). Pulled up into tbg & gun stuck @ 10,268. Worked w/1000# pull & flwd well. Pulled out of rope socket @ 3000#; 18,000# over line wt. RIH w/fish'g tools & latched onto rope socket w/overshot & jar'd. POOH w/fish'g tools & CCL; left 21' gun fish. RIH w/spear & jar'd; pull'd gun thru x-nip & ball valve. Btm 3' of perf gun was split. Flwd well while gun stuck in tbg @ 720 BO/D rate w/.2% cut. 1/24 Run #35 - perf'd 11,099- 11,120. Press tested lubri. Run #36 - perf'd 11,067- 11,099; had 3 shots that did not fire. Tested lubri & RIH for Run #37 when motor for odometer failed. Repl'd motor & tested lubri. Run #37 - perf'd 11,035-11,067 w/4 jets/ft. Run #38 - perf'd 11,003-11,035 w/4 jets/ft; 1 shot did not fire. 1/25 Run #39; lost wt & collar locator @ 10,292. POOH; gun had swiveled off rope socket. Run #40 - perf'd 10,971-11,003 w/4 jets/ft. Run #41 - perf'd 10,947-10,971 w/4 jets/ft. POOH w/Gun #41; 3 shots did not fire. RD Dresser Atlas & began test'g well. 1/26 Started perf'g HI/HK lower & middle interval. Tested lubri to 3000 psi. Run #42 - perf'd 10,921-10,922. POOH w/gun & started test'g well. Tbg-liner vol to top perf 103 bbls. With 132 bbls unloaded @ 33 B/H, cut 13.5% wtr. With 166 bbls unloaded @ 34 B/H, cut .1% wtr. 1/27 tested lubri. Run #43 - perf'd 10,900-10,921 w/4 jets/ft. Run #44 - perf'd 10,882-10,888 w/4 jets/ft. POOH w/gun & started test'g well. Run #45 - perf'd 10,818-10,819 w/4 jets/ft while well prod'g. POOH & began test'g well; 101 bbls to move from tbg & liner to 10,818. After remov'g 156 bbls fluid, well prod 34 B/H w/.l% wtr & 36.1 gravity. Run #46 - perf'd 10,797-10,818; 1 shot did not fire. Run #47 - perf'd 10,776-10,797. Began test'g well. 1/28 Prod well 10 hrs @ 38 B/H w/.l% wtr & 36.4 gravity. Prep to perf HE/HD. Tested lubri to 3000 psi. Run #48 - perf'd 10,739-10,740. POOH w/gun & tested well. Tbg & liner vol to 10,739 - 99 bbls. With 163 bbls rec'd, prod 41 B/H w/.l% wtr & 36.1 gravity. Run #49 - perf'd 10,707-10,739. Run #50 - perf'd 10,686-10,707. 10 p.m. wtr cut 54% - suspended perf opers. 10:15 p.m. wtr cut 95% & @ 11 p.m. wtr cut 33%. 1/29 2:30 a.m. SI A23-1 & A33-1 inj'rs. 7 a.m. prod 1248 gross, cut 50%, inj gas 1302, TP 150, CP 820 & sfc pipe press 115 psi. 7:45 a.m. incr'd inj gas by 300 MCF to 1590 MCF. Tested well 12 hrs as foils: gross 1234, cut 46%, inj gas 1596, frm gas 384, GOR 576, TP 100, CP 830. 3 p.m. reopened A23-I & A33-1 inj'rs. Cont'g to take 4-hr readings on wsll. A-12-1 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' A-12-1 (D) 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' fTD 12,000. PB 11,895. No re~-t. ~n~l .~. ~qv~q TD 12,000. PB 11,895. 1/31 Pulled BHPB. Well is lift'g ~6 ' from Valve #4 @ 8533' & Valve ; @ 10,148 · Valve #5 @ 9603' is malfunctioning. Test results: gross 1228, cut 50%, clean 614, MCF Inj 1575, MCF prod 216, GOR 352, TP 120, cP 820. WEB C., 1 1978 A-12-1 (D) 12,200' "G" Pool 116 ' DF ' 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB 11,895. No report. FE~ 0% 1978 A-12-1 (D) 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' A-12-1 (D) 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB !1,895. No report. FEB 0 2 1978 TD 12,000. PB 11,895. No report. FEB 0 6. 1~978 A-12-1 (~) 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB 11,895. No report. FEB 0 ? '1978 A-12-1 (D) 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB 11,895. No report. FEB 0 8 197'8 A-!2-1 ~2,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB 11,895. No report. FEB O 9 '~978 (D) 12,200' "G" Pool 116' DF 13-3/8" csg @ 1642' 5-1/2': liner @ 11,980' A-12-1 (D) 12,200' "G:' Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' ("~O 12,000. PB 11,895. No repo~ F~_B 1 0 1978 TD 12,000. PB 11,895. (Report disqontinued until test results received) FEB 1,3 1978 A-12 =1 (D) 12,200' "G" Pool 116 ' DF 13-3/8" csg @ 1642' 7-5/8" csg @ 10,508' 5-1/2" liner @ 11,980' TD 12,000. PB 11,970. (RRD 2/13/78) OIL WELL COMPLETE° On 24-hr test 2/2/78, prod 752 BO, 502 BW & 404 MCF gas on 128/64 chk w/Il0-150 TP & 795 CP from perfs 11,768-10,686. GOR 537. Completion Date: 1/16/78. Log Tops: FINAL REPORT Name MD TVD HC 10,615 7417 HD 10,740 7516 HE 10,776 7544 HF 10,819 7576 HI 10,854 7608 HK 10,922 7657 HN 11,230 7640 HR 11,556 8140 HZ 11,768 8306 Conservation Ground Shoal #A-12-1 Mr. R. Planty $hell Oil Company 1'700 B~oadway Denver, Colorado 80202 Dear A ~exmit For' the ,~,~ect well was approved on O~tober 5, 1977 and the following ~rationa! infformation has been re~ived:- (1) A Monthly R~Dort o~ Drilling and ~W, orkover Operati~s dated N~~er 15, 1977 an~ receiv~ Noir 21, 1977 ~h a cover let~r fn~ca~t~ ~e re. Et ~r~ ~r- ations for the ~n~ o~ No~r, 1977. h~ver ~ g~stion i~ ~he ~rt is for ~ae perf~. A Monthly Repo~ of Drilling and Workover Operations dated January '13, 1978 and received Janua~ 18, 1978 concerning o~erations for the mongol De~r', 1977. (3) A telephone message on De~.~r 16', 1977 between Mr. John ~ftller of our ~taff and ~r. ~e'~ Ric~nd hole ~d ~ntin~ng to ~ original bo~t~ hole location. The following ~rofluotion data have been February. 1978 19,311 Barrels Oil. A commercial report on oil and _~as aetivi~ies that is prin~ed iocaily .indicates that the s~lbJect well was completed on Janua~, 197a and 28 days 9r~ucti,on in Pebrua~,, 1978 we ass~ ~e ~11 was ~1e%~ on or abo~t Februa~ 1, 197~ and $~he11 Oil C~any is in violation of the Oil a~ ~as R~lati.ons of ~ Mr. R. Planty Shell Oil Company April 5, 1978 State of Alaska. The violations are listed as follows: (2) A Monthly ReDort of Drilling and Workover Operations for the month of January, 1978 was required by Feb~ry 15, 1978 -- I month and 21 da~s late. A Well Completion or Recompletion Re~rt and Log was require4 on March 3, 1978 -- (3) All logs r~m on the well, deviation surveys and other ,pertinent information, was required on March 3, 1978 - 'We request that the information and data on ~b~s well be fo~ard~ ~diately. O. K. ~ilbre~,. Jr. SHELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO 802.02 January 13, 1978 Subject: Shell-ARCO-Standard Middle Ground Shoal A-12-1 Mr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Attached are two copies of the Monthly Report of Operations for December, 1978. KWL:ts Attachments cc w/Attach: ly, For: R. Planty Division Operations Engineer Rocky Mountain Operations Atlantic Richfield Company Standard Oil Company Amoco USGS Form No. P-4 R [:.V. 3-1.70 ~' ( SUBMIT IN DUPLICATE ( STAT E 0 F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ADL 18754 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Shell 0il Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 1700 Broadway, Benver, Colorado 80290 A-12-1 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL Platform A, Conductor 1, Leg 1; 1632' N and 437' W of SE Corner of Section ll-T8N-R13W, S.M. 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 1-TSN-R13W, S.M. 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 7-5/8" casing set @ 10,508' Drilled to 10,825 - Stuck Rec'd some fish Set cement plug 10,643-10,503' CO cement to 10,528' Kicked off Drilling @ 11,731' DECE}~BER 1977 14. I hereby cert~t th~rrect SIGNED ~ ~ ~J - ~ TITLE Div. Opers. Engr. DATE 1/13/78 NOTE--Report on this form is reqmred for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. S H ELL OIL COMPANY 1700 BROADWAY DENVER, COLORADO 80202 November 15, 1977 Subject: Shell-ARCO-Standard Middle Ground Shoal A-12-1 Mr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Attached are two copies of the Monthly Report of Operations for November, 1977. KWL: ts Attachments cc w/Attachs: ly, ~R. Planty Division Operations Engineer Rocky Mountain Operations Office Atlantic Richfield Company Standard Oil Company Amoco USGS RECEIVED NOV ~ ] 1§?? l~rm No. P---4 REV. ~- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMrl-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS W~LL NAME OF OP~ATOR OTHER Shell Oil Company 3. ADD~ES~OFOP~&TOR 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF WP.i.T. SUBMIT II~ DUPLICATE Platform A, Conductor 1, Leg 1; 1632' N and 437' W of SE Corner of Section ll-TSN-R13W, S.M. APl NU~{ERICAL CODE 6 LEASE DESiGNA~ON AND SERIAL NO. ADL 18754 IF INDIA]~, ALO'~ ~g O]~ TRIBE NAME 8. L,~IT FA~A{ OR L~ASE NAME Middle Ground Shoal 9 %v~ A-12-1 10 ~'HSLD AND POOL, OR WILDCAT Middle Ground Shoal-"G" Pool 11 SEC , T., R., 1%L. (BOSOM HOI~E o~ Section 1-TSN-R13W, S.M. _ 12. PERMIT NO, 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE. CASING AND C~WIENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. 'rESTS A~D RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TR~CKED HOLE A2~D A.NY OTHER SIGNIFICANT CHANGES IN HOLE C~ON'DITIONS 01d TD 11,052' Cut 7" casing at 1805' Spotted 400 sx cement plug - top at 1457' Dressed plug and kicked off w/dyna drill at 1650' Drilling at 7209' ., SmN~ [_ ;. ~, _.,co-.w~,~.~_ .,.- ~'rLE D~v. npo~.~, v~gr ............. n.~ !!/15/77 NOTE--Report On this fGr& il quired for each calender ~nth~ regardless of the Ito~uS Of operotiofls, Gild must ~ filed ~n duplicate with oil and gas conlervotion commi~ee by the 15~ of the succ~ding mon~, uflle~ otherwis, dirscted. DEP~ (F ~ RESO~4C~S Divisic~ of Oil and Gas Ctm~tic~ 14, ]_977 sa~, ~ 5, 1977 - I left ;tnchox~qe by AAI to Kenai at 7:00 AM. i ':~ve~ c~ Shell '"As' ~~ozm at 8.:45 AM. I~ of this trip ~ to ~~. BC~ ~cs ~ at 5:00 PM and finished at 10:00 PM. The tD 3000 psi OK. ~he kill val~e was ~ zext and ~ dzke val~e to 3000 psi QX. ~ ~ prev~ter ~as test~ to 1500 psi OK. ~ ~ ~ to 3000 psi OK. ~he b~ rams ~ t~~ OK bo 3000 psi. The 5~. : A~ Drlg. Permit No.~_~.~-~..~ Opera tor_~]~. ~,~ A1 a Oil and Gas Conservation Commi Field Inspection Report b X~I/~/~ Well/Platfm Sec_LT ~A/R/'Y~,~_~ M Represented y.,,~.l/,~_/$? Name & Satisfactory Type Inspection Yes No Item ()~ Location,General ( ) ( ) 1. ~'~ell Sign (~ () (~) () () () () () 2. General Housekeepin.m t. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. ( ) Final Abandonment Satisfactory Type Inspection () () () () () () () () () () () () Yes (~ () IX) ( ) (~ ( ) () No Item (~0 BOPE Tests ( ) 15./~'Casin.q se't ( ) 16 Te~sL fluid-(~-)wt~)mud ( ) oil ( ) 17. Master Hyd. Control Sys.-/~-~ psi~ ( ) 18. ~!2 btls-~,2~7~,~,~'~psi~ ( ) 19 Remote Controls (m () (~) () (x) ( ) ex) () 11. P&A Marker (~;~) ( ) 12. Water well-( )capped( )plugged (X) ( ) 20 21 22 23 24 25 26 27 Drillinm spool-_~~''outletS Kill Line-(A~) Check valve Choke Flowline ( ) HCR valve Choke Manifold No. valvs~ flm_s~$1, Chokes-( )Remote( )Pos.~T~.~-~-dj'] Test Pluo-~-)~ellhd( )csq( )none Annul ar ~reventer ~ps i c~ B1 ind Rams,~m~.psiq 28. Pipe Rams~o~_Dsiq K ~ ' 29 elly & Kelly-cock ( ) ( ) 13. Clean-up (~k) ( ) 30. Lower Kelly valve ( ) ( ) 14. Pad leveled (~) ( ) 31 Safety Floor valve~BV /~Dart Total inspection observation time~~-~/days Total number leaks and/or equiP, failures~ Remarks (Ti~e 5, ~ ~t, ive ~). Prior to ~ing may b~ ~7, 1977 Dep~m~nt of Fish ~ ~, Habitat Amoco Production Company P.O. Box 779 Ancho~ a.qe. Alaska 99510 'l.. A. Dt~rsow October 6, 1.977 File: LAD-815-WF Mr. R. Planty Division Operations Engineer Rocky Mountain Operations Shell Oil Company 1700 Broadway Denver, Colorado 80202 Dear Sir: Middle Ground Shoal Platform A, Well A-12-01 NW/4, Sec. 1, T8N, R13W, S.M. Cook Inl.et~ Alaska In response to your letter of September 30, 1977, Amoco Production Company has no objection to the drilling of the subject well at the proposed location of 2940' FSL, 1200' FWL, Section 1, T8N, R13W, S.M. Attached you will find our signed.waiver of objection as requested. We have also forwarded a copy of this waiver to the State of Alaska, Division of oil and Gas Conservation on this date. Yours very truly, L. A. Darsow Area Superintendent Attachment cc:" A. M. Roney, Denver U~.K. Gilbreth J.DM:klt RECEIVED O~.vi~ion of Oil and Gas Conser'~ation SHELL 0.1L COMPANY 1700 B ROADWAY DENVER, COLORADO 802.02 SEPTEMBER 30, 1977 Subject: Middle Ground Shoal Cook Inlet, Alaska Platform A, Well A-12-O1 NW/4, Sec 1-8B-13W, SM Amoco Production Company P. O. Box 779 Anchorage, Alaska Gentlemen: We recently sent to you a copy of a letter dated September 8, 1977 which was addressed to the State of Alaska, Division of Oil and Gas concerning our proposal to drill the subject well. As stated in the letter and accompanying permit application, this well is being proposed as a producer which will penetrate the "G" pool at a location 2940' FSL and 1200' FWL, Section 1, T8N, R13W, SM. Therefore, the well will be located at approximately 2340' south of our common lease line. This additional drainage point is essential to the recovery of oil and gas reserves which would not. otherwise be produced. The possible migration of reserves across our common lease line as a re- sult of this well is nullified by the existence of the lease line in- jector B-12. We should appreciate your waiver of any objection to drill the subject well by endorsement below. When received, we will place a copy on file with the State of Alaska, Division of Oil and Gas. Your early consideration would be greatly appreciated. If you need any further information, feel free to contact us. Approval: Amoco Production Company ANCHORAGE AREA 0111' 5'77 Very truly yours, R. PlantY ' I Division Operations Engineer 0OT 6 t977 1- ...... Division of 0ii ,,m~ G~s "*"~:"'~" ~ -- EXPL SHELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO 80202 September 8, 1977 Subject: Middle Ground Shoal Cook Inlet Alaska Platform A, Well A-12-1 NW/4, Sec 1-8N-13W, SM State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention O. K. Gilbreth, Jr. Gentlemen: We should appreciate administrative approval for completion of subject well in the "G" Pool as an exception to Rule 1 (6) and pursuant to Rule 6 (d) of Conservation Order No. 44. Wells No. A-11-1 and A-22-1 are the two permitted "G" Pool producers in the NW/4, Sec. 1-8N-13W, SM. Our plan is to abandon Well No. A-32-11, a current injector. Attached is Form 10-401 and related data for drilling of the proposed well. Also attached is Form 10-403 for abandonment of Well No. A-32-11 with a diagrammatical prognosis for squeezing off the productive intervals. The proposed well is located in an area of leaseholds owned in un- divided 1/3 interests by Shell, Cheveron, and Arco. As shown on the attached plat, the location is approximately 4/10 of a mile from the nearest common line with anoth producing lease operated by Amoco. Justification for this well is based upon the recovery of additional oil and gas reserves which would not otherwise be produced within the economic life of the project. The additional drainage point is designed to achieve a better balance in the operation and enchance the pressure maintenance program. Your early consideration will be appreciated to enable prompt use of an available rig. JFW/KAR Attachments Yours very truly, R. Planty Division Operations Engineer Rocky Mountain Operations Office cc: Atlantic Richfield Co. P. O. Box 360 Anchorage, Alaska 99510 Amoco Production Co. P. O. Box 779 Anchorage, Alaska 99510 Form 10-401 REV. 1-1-71 la. TYPE OF WORK b. TYPE OF WELL OIL WEI. L ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL GAS WELL 2. NAME OF OPERATOR Shell Oil Company 1632' 3. .~DDRESS OI. OPkRA'/OR ()TILER SUBMIT IN TRIPIIC.~., (Other instr u~t~ons reverse side) DEEPEN 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF WELL ^tsurt'~,:~ Platform A, Conductor 1, Leg 1; SE Corner of Section ll-T8N-R13W, S.M. At proposed prod. zone 13. DISTANCE IN MILES AND DIRE~ION FROM NEAREST 'ro~ OR ~ST OFFICE* 17 miles ~ of Kenai, Alaska SINGLE ZONE MULTIPLE ZONE [__j N and 437' W of /o o8/- ~ / API NO. 50-133-~0309 6. LEASE DESIGNA'FION AND SERIAL NO. ADL 18754 7. IF INDIAN, ALLOFFEE OR TRIBE N.\ME 8. UNIT F'ARM OR LEASE NAME Middle Ground Shoal 9. ~W~LL NO. A-12-1 (*See Below) I0. EIELD AND POOL, OR WILDCAT Middle Ground Shoa!-"G" 11. SEC., T., R., M., (BOTTOM tlOLE OBJECTIVE) Po~ Section 1-T8N-Ri3W., S.M. 12. 14. BOND INFORMATION: Statewide Oil and Gas TIC TYPE Surety and/or No. 136503 Amount $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT._ (Al,o~ ........ ~dri~,u~i~.ir~ny) 2340' (Lease Line) DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED ["OR., FT. 796' @ "G" POol ~r (A-22-1) 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 116 ' DF 23. 16. No. OF ACRES IN LEASE 3746 19. PROPOSED DEPTH 12,200' MD PROPOSED CASING AND CEMENTING PROGRAbl 17. NO:ACRES ASSIGNED TO TillS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START September 25, 1977 , SIZE OF HOLE SIZE OF CASING I~IGIIT PER FOOT GRADE SETTING DE~tt Quantity of cement ..... 17-1/2" 13-3/8" 54.5#- !642' 2500 sx (in place) 9-7/8" 7-5/8'~ 33.7# N80 11,200' 400 sx ,,. 6rt/2" 5-1/2" 17.0# N80 12,200' Sufficient cmt to fill entire liner interval *Plan to abandon MGS A-32-11 (injector - NE/4 Section ll-8N-13W) **Top of productive zone ("G" Pool ~fkr) @ 7616' TVD (7500' SS); 2940' SW Corner, Section 1-T8N-R13W, S.N. ::"' . N and 1200' E of IN ABOVE SPACE DESCRIBE PROPOSE[) PROGRAM: If propo~l is to deepen give data on present productive zone and proposed new productive zone. If propo.mi is to drill or deepen directionaily, give pertinent data on sub~tuface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby cetiify that t~& Fo)~°ing is 'riue and Correct DATE 9 / 8 / 7 7 TITLE D iv, Opers. Engr. (This sPace fbr State office use) SAMPLES AND CORE CIIlPS REQUIRED U YES [] ~o DIRECTIONAL SURVEY REQUIRED [] YES [] NO MUD LOG [] YES CONDITIONS OF APPROVAL, II: ANY: OTItER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-133-~ 77-55 APPOVED BY ~,' TITLE Chairman ~ee Instruction On Reverse Side October 5, 1977 DATE October 5, 1977 SHELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO 80202 September 8, 1977 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Mr. O. K. Gilbreth, Jr. Gentlemen: Ic. g~o,. i~ I2 ,.'-. ~c-i ....... J 4 12 O~OLI I ~ O~OL I-- I~Ev I D~AFTI- I S~ ~ CONFER: Attached in triplicate is a request to drill Middle Ground Shoal A-12-1. Included are the following: 1. Application for Administrative Approval 2. Application to Abandon 3. Application to Drill 4. Abandonment Proposal 5. Proposed Location Sketch and Sectional View 6. BOP Assembly 7. $100 Filing Fee KWL :ts Yours very truly, Division Operations Engineer Rocky Mountain Operations Office Attachments cc: w/Attachments Atlantic Richfield Company Standard Oil Company of California Amoco Production Company USGS - Alaska State of Alaska cc: (cont.) Chevron USA Inc. P. O. Box 7-839 Anchorage, Alaska 99510 United States Geologic Survey Department of Oil and Gas 218 E. Street Anchorage, Alaska t .f TX ~'2"- 3000 J ,, CDOOeLE SHAFFER ,.'SATE 12"- .5000 ~2"-~ooo-x D! ii TO KILL LINE ~~ -,---q?"~ TO CHOF, E MANIFOLD 13"'~8"-3000 ~i ~ ClW RX 57 RISER 12"-- 3000 I 2."- 3000 DOUBLE STUDDED ADAPTER 12"- 3000 24" CONDUCTOR ~ ii ~ ~ cas~ DRt,,V?t ~3'r' i ¢ SCALE DATE 5--~'~-T-~$ Rev S- 20-77 ;:{ ,_ 5000 PSI BLOWOUT PREVENTER STACK PLATFORM A M.G.S., COOK INLET, STATE OF ALASKA MIDDLE GROUND SHOAL A-12-1 PROPOSED LOCATION TSN R13W SECTION 1 All-01 Proposed A-12-01 2940' FSL & i200' FWL~ at "G" Pool Marke~ 7616' TVD (-7500' SS)~ A22-01 A33-01 Injector A23-01 Injector Al4-0 A24-0i Note: Circles represent point of penetration at "G" pool marker. JFW/K~R .( I Ca. K. H'f'CR:L I2"- .'5000 L[ SHAF, FER GATE ~.,, ~2"- sooo 12"-500o ~ TO KILL LINE ~ ~ TO CHOKE MANIFOLD ClW RX 57 RISER t 2"-- 3000 12"- 3000 DOUBLE STUDDED ADAPTER h 12"'- 3000 MIDDLE DECK 24" CONDUCTOR 133/8'' CAS~ oC,~L~. NO;NE :i c~:~:<~ ~ ~ SHELL OiL CO~PANY~ _ '.~ ~;,~ ~-~o-:,~ ~,,.~-~,~-~ ~-V-149 3000 PSI BLOWOUT PREVENTER STACK L~FORM A M.~.S ,. COOK INLET, STATE OF ALASKA -:i i ~' CHECK LIST FOR NEW WELL PERMITS Company " Yes No Remarks - 1. Is the permit fee attached . .' .................... 2. Is well to be located in a defined pool ~ .3. Is a registered sUrvey plat attached ' · · . $~a.~ /t>/~7L /J~'C.~.c6~ 4. Is well located proper distance from property line ......... ._~>/< . 5. · Is well located proper distance from other wells ........ ~f~ /~/~o/.~ 6. Is sufficient undedicated acreage avail'able in this pool ...... 7. Is well to be deviated ................. · ..... 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day wait ........... 10. Does operator have a bond in force ................. ~: ll. Is a conservation order needed ........ .... ' ........ 12. Is administrative approval needed ................ 13. Is conductor string provided ....... . ............. 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production stri'ngs . 16. will cement cover all known productive horizons .......... ~ 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~tO00_ .psig 20. Has DMEM approved Plan of Operation ................ Additional Requirements: Revised 11/17/76