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Home My WebLink About197-115 Im: ~. Project Well History File Cow '~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing CAN Color items: [] Grayscale items: DIGITAL DATA [] Diskettes, No. [] Other, No/Type [] Poor Quality Originals: [/g~ Other: ~(~,..(~k ~(~/ NOTES: BY: BEVERLY ROBIN VINCENT SHERYL~RI WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL .~NINDY Scanning Preparation ~'/ X 30= BY: BEVERLY ROBIN VINCENT SHERY~WINDY OVERSIZED (Scannable) Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUAUTY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .._~YEs NO IF NO IN STAGE t~ PAGE(S) DISCREPANCIES WERE FOUND: ~ YES ~ NO III IIIIIIIIIII II III RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12210~02 Rev3NOTScanned.wpd Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 332,102.26 __ 2.09 - NCI A-02 - - -- 2,586,722.85 - 332,108.29 2,586,721.16 332,111.27 3.43 -- - -- NCI A-03 2,586,728.60 - 332,106.22 - 2,586,728.31 332,109.43 3.22 NCI A-04 -- . _ 2,586,719.62 __- 332,105.09 2,586,718.58 332,108.09 3.18 -- -- NCI A-05 2,586,725.55 332,110.17 2,586,725.14 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 3.83 NCI A-09 _ 2,586,666.58 332,039.08 ' 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 332,044.17 _ 4.78 NCI A-10A -_ 2,586,670.21 __ 332,040.91 2,586,673.71 332,044.17 4.78 --_ NCI A-11 -_ 2,586,670.23 332,039.14 2,586,677.01 332,041.75 7.27 - NCI A-12 2,586,722.73 --- 331,947.80 2,586,723.59 331,994.15 46.36 NCI A-13 2,586,734.88 331,993.50 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 2,586,729.60 332,001.86 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03PB1 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 ~~~~~~ Ohl APR ~ ~ 2008 • • _ ~ s_... r__~ r~ REV DATE BY CK APP SCRIPTION REV DATE BY CK DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 y9~ ~ ~ 36 31 T 12 N 31 32 ~; ~ Y y~i a° 1 6 T I~ N 6 5 N .~, Ro N s rovs• SEC. 6 1206' SCALE: I"-1320' --6- ~ ~ o 1 6 I 6 5 12 7 ~ g GENERAL NOTES: .~~~~ OF /~,~~/ "~~~~~~~ I. SEE SHEET 3 FOR COORDINATE TABLE "''•o~S/~~ ~ i '~P •'~' ~ ~.•• . 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND • ~ ' ~ ~ •~ ~ ~ VERTICAL SURVEY DATA ' 49th ~; ~j ~ 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~""'`""""""""""""""""""`""'% ~ ~ VALUES. ....................................... ....... ~ ~• <~"~ ~ KENNETH W. AYERS ~~ ~~ s '.~ LS-8535 ~•'' Q~~i SURVEYOR'S CERTIFICATE ....... ~~ •,~+j A P~ ~ ROF ~~- ~~ ~ ~ I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND ~~,;"~=~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ME OR UNDER MY DIRECT SUPERVISION AND THAT AL DONE BY L LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & assoclaTES, INC. FEBRUARY 28, 20D8. SURVEYORS ENGINEERS PLANNERS ~ PHONE: 19071 272-5451 AREA: MODULE: UNIT: ConocoPhilli s NORTH C°OK INEET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUIET CADD FILE N0. 08-005 AS BUILT 02/27/08 DRAWING N0: ~g~~5 /~S BU~~T PART: 1 OF 3 REV: 1 REV DATE BY CK APP SCRIPTION REV DATE BY CK DESCRIPTION ~ 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 v ~ ,gw ff T oP; a ~ 9 1~'3 a` aA9 Ttll A9 ~~ s. ~' se a 'v~, ti~ ~, ~a ~o ~~ SCALE: I"=30' a9 RA~ L ESD 600 50 - ESD 600-51 O Ala 7 IO .92 Al A7 AB • B3 • •p5 • A3• A6 Alt 81 : •A5 • A4 A2 WELL HOUSE 2 p • ' p zp A10~ LEGEND: 5 O a ~ A • WEL L p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VALVE) GENERAL NOTES: I. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE N0. 4, AND IT WAS NOT & nssoclATES, INC. A S B UIL T SURVEYORS ENGINEERS PLANNERS 907 272 PH NE 451 1 -5 O : ( `,~ AREA: MODULE: UNIT: ConocoR'hilli s NORTH COOK INLET p TYONEK PLATFORM Alaska, Inc. WELD CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08-005 AS BUILT 2 of 3 1 e e r~ ."".,,--, ·"'Ii!'"'' 1 MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marker.doc PHilliPS PETROLEUM COMPANY H(:oUSTor',J TE,,,':'S -~~'~,'-'9¿.ì e.(Yx , 'Õ4f. :- eElL':'.IRE TE <':'S 0:,::='(.1 \'VES T lC"~"P SC'UTH PHilliP':' E,UllDlr Je; r JC,RTH .:.r.1E¡::;:IC':' FRCJDuCTI,~,r J DI\'I:::.I(,1 I July 7, 1999 Alaska Oil & Gas Conservation Con1mission 300 I Porcupine Drive Anchorage, Alaska 99501-3192 Attn: l'vls. Lori Taylor o~., lí~ Re: Tyonek Deep \\'ell Infonnation Dear l\ls. Taylor: By letter dated l\lay 13 (see attached copy). you indicated that Phillips had not pre\"iously provided sepia or vellun1 copies of certain logs for several of the wells in the subject project. Enclosed \vith this letter is one box containing vel1l1111 copies of the logs that we believe are listed in you prior letter. Please note that the logs appear to be labeled incorrectly in some cases and the log itself BUist be reviewed to confirm the interval covered. In addition, we were not able to provide the last item listed on your exhibit for the NCIU B-1 ST (the Array Dens Neutron 4~ 1530 I ~ -1786.''") since this depth interval runs deeper than the total depth of the B-1 ST well. I hope that this data will con1plete the required information and I apologize for any inconvenience that 1l1ay have been caused. If you find that any additional copies are required. please forward your copy of such data to the w1dersigned and we will promptly have the necessary copies made and returned to you. If you wish to discuss this please contact me at 713-669-2942. Sjncere]y~ /f~/I W~ Robel1 N. 'Nelch Landlnan .... --.. .. - - - .- - -.. '- . - 1"'.1 J " . < : ~" I J ' " '. ,I, ,L. TONY KNOWLES, GOVERNOR I .....: . , - .- . . - ~- ... - -. - A.1~A~1iA. ORA5D GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501.3192 PHONE: (907) 279-1433 FAX' (907) 276.7542 ~ ¡Q7-1/6, ReceiYed A1aIka Region MAY 1 8 1999 May 13, 1999 Robert N. Welch, Landman Phillips Petroleum Company Box 1967 Houston, TX 77251-1967 Dear Mr. Welch: - Thank you for your telephone call on March 12, 1999. Our commission regulations 20 AAC 25.071(b)(5) require we receive a sepia and a reproduced copy of all logs run in the well, except VSP's and experimental logs. I am sending you attachments 1 through 4. This is the list of logs that AOGCC still needs a sepia to complete our collection. Vellum or mylar will also be acceptable and you do not need to send blueline copies as we have reproduced copies of all these logs. Regards, ~ ~:.~ X~(¿~~ Lori Taylor <:J Admin Clerk II ('I()7- ~7f - /Ý.1~) -S;-,n ~./¡V/~ t;. . n. ~J /".1Þ I dJ~ ;11~ t.4-Jh.e.ft.e-r PJ~>e- rtA/.~ ~ '..:r+ -r -,) ï.)/~s e. ..JA. e...'" I.A e..- st-J. "",,-u....:t e-r-l a-l I' .5 ~ I / ~ é!- . " .I I J , :::L- I'" ~ 'r--eJ..' ~ r .-.1/ ~~ ì GL-,$.$CA4-'t G.:I e. 11 e... ~ IA ' C ~ e.. 5 . " ) ..--? L -fo ~e. .s-rJ..e. (e.-v~ ~..ç ~&.. "p~;"tL7 .saP'- -7/. / ~>. ~~ f/y/ff NCill B-1 PERMIT 97-115 LOG INTERVALS RUN AIT - TVD 8600-12870 AIT -MD 10200-15590 RFT 14313-14498 CN/LDT- TVD 8710-12870 CN/LDT-MD 10375-15500 DSS- TVD 8850-12825 DSS-MD 10375-15445.80 MWD-FET-MD 2646-15500 FINAL MWD-FET-TVD 2565-12880 FINAL DDL-MD 2646-15500 FINAL CDR-MD 2575-15463 FINAL CDR-TVD 2500-12853 FINAL REC. CDR-TVD 2400-12400 Attachment ( 1 ) ./ . l ~ NCIU B-IST C\T' \ PERMIT 98-002 LOG INTERVALS RUN CNILDT/GR- TVD 14500-16590 CNILDTlGR-MD 14500-16590 FET - TVD 8860-12942 FINAL MWD-FET-TVD 8860-12942 FINAL FET-MD 10400-16720 FINAL M\VD-FET-!\1D 10400- 1 6720 FINAL DDL-MD 10400-16720 FINAL PDL- TVD 8860-12942 ARRA Y DENS NEUTRON 4 15301-17864 Attachment (2) NCIU B-2 C 1/ \ \ S PERMIT 97-210 LOG INTER V ALS RUN CDR-MD 8909-13416.6 1-9 CDR- TVD 8142-13340 1-9 MWD-FET-TVD 8123-13377 FET -MD 8990-14537 MWD-FET-MD 8990-14537 DDL-MD 8990-14537 FET- TVD 8123-13377 CN/LDT/GR 11000-14500 AIT 11000-14500 DSI 1 1000- 1 4500 MSCT 13 1 75- 13956 GRJCCL 12624-13007 PERF 13000-13999 RELABEL DSI 1 1000-13500 GR/CCL 13000-13999 Attachment (3) NCIU B-3 PERMIT 98-059 LOG INTERVALS RUN PEX-3DETECTORILDT/CN 4400-8820 CALIPER/GR 11774-11910 IMP-MD 15301-17864 STl IMP- TVD 11400-13300 STl ADN4- TVD 11400-13300 STI /' Ol,\l~ Attachment (4) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well O~L r~. of O lillips Petroleum _C, , ' ~. Permit Number 6330 W. Lo I~:k,J~_..` a~r~., TX 77401 APl Number of well at~'"rfa"~, ~ ~ ~ .... Unit Name .i ~ ~ -/ ~ ;1250' FNL & 980' ~L Producing Inte~al ; ---~~~ SE 10. Well Number " ' '"~ i'~ ::'' 2178' FSL & 2086' FEL SEC 7-T 11N-R09W To~I Dep~ '~~-----~!~ I~ I~ 11. Field and P~I ~' FSL & ~O' FEL SEC 7-T 11N-R09W Elevation in feet (indi~te KB, DF, etc.) 6. Lease Designa~on and Sedal No. RKB 132 ff. NClU 12. Date Spudded ~13. Date T.D. Rea~ed ~/97 J18. Plug Ba~ ~D+~D) ~0,029(MD) 8,605 (~D) O7/30/97 17. Total Depth 15500 22. Type Electric Logs Run SUSPENDED~ ~ SERVICE ~ Suspended (TemporadlyAbandoned) 97-115 50-883-20093 Nodh Cooklnlet NCIU B-1 Cook Inlet / Beluga 23. O..,Date Suspended . Directional Survey AIT/DSI/GR/AMS; Den/Neutron; RFT/GR; Dipmeter/GR 15. Water Depth ~ompletions 20. SSSV Depth 121. Thickness of Permafrost i KB CASING, LINER AND CEMENTING RECORD Casing Size 30" 20" 13 3/8" 9 5/8" 9 5/8" wt. per__.___~ff. 133 72 53.5 53.5 Grade Setting Depth (MD~ 407 K-55 2,579 L-80 P-110 P-100 3,76O 10,376 3,558 24. Perforations open to Production(MD+TVD of Top and Bottom and interval, size, and number) 13 3/8" casing perforated from 3500-3540 (For purpose of cuttings disposal) 27. Date First Production Date of Test FTP 28. NA nTested ~ ~-~ressure Hole Size 25. Size 26. Cementing Record Amount Pulled Ddven 24" 1690 sx. None 18.5" 1234 sx. None 12.25 2400 sx. None 12.25 None None Tubing Record IDepth Set (MD) JPacker Set (MD) 2 3/8" ~ 3663' ITubing cemented 2 3/8" J 3663' ~for cuttings disposal Acid, Fracture, Cement Sqeeze, ETC. PRODUCTION TEST Method of Operation (flowing, gas lift, etc.) Temporadly abandoned Prod. for Gas Water-BBL Test Period Calculated Gas Water-BBL 24 hr Rate CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. GOR Choke GOR (~Cored from 14,273-14,454 and 14,972-15,056 A ,-. ~ _ , ~B~ 0il & GaS ~ns. Commissi Anchorage t,¢Utll IL,IL..t I I ii-il.. PHiLLiPS PETROLEuM:CO:::i::: :: ' ·page 1 of:;i Legal Name: NORTH COOK INLET UNIT-B 000001 Common Name: NORTH COOK INLET UNIT B-1 Well Location Country: USA APl #: 50883 Location: 000/6 -00-011-N 00/00 Field Name: North Cook Inlet Field Block: License No: Spud Daterrime:07/31/97- : Well ID: D0124 State/Prov: ALASKA County: TYONEK OFFSHORE Slot No: 4 Platform: Tyonek License Date: Licensee: P&A Date: Latitude: Longitude: Distance North/(-)South: Distance East/(-)West: Measured From: 61.07676 -150.94878 1,250.00 (ft) -980.00 (ft) j NW CORNER SECTION 6 T-11N R9W Permanent Datum: MEAN SEA LEVEL Kelly Bushing: 132.00 (ft) Ground Level/Mudline: (ft) Casing Flange: 73.00 (ft) Tubing Hanger: (ft) KB to Datum: 132.00 (ft) KB to GL/Mudline: 132.00 (ft) Date Measured: 08/03/97 Date Measured: Datum Elev: (ft) Water TMD: 130.00 (ft) Measured Depth: (ft) TVD: (ft) Plugback TMD: (ft) Fill: (ft) Deviated Well: N Operator: PHILLIPS PETROLEUM CO Region: E&P KENAI AREA Well Type: EXPLORATION / OIL Geological Play: Authorized TVD: 13,262.00 (ft) Division: KENAI SUBDIST Status: PENDING SP Authorized TMD: 15,840.00 (ft) . . District: KENAI SUBDIST Event Type Test Sidetrack Original Drilling Test Objectives I Drill to a new Ioction !Drill J 11/01/97 Printed: 05/28/98 12:12:24 PM Legal Well Name: NORTH Common Well Name: NORTH Event Name: Original COOK INLET UNIT-B COOK INLET UNIT B-1 Drilling 0OO001 Start Date: 06/05/97 End Date: 06/06/97 06/07/97 06/08/97 06/09/97 06/10/97 06/11/97 06/12/97 06/13/97 06/14/97 06/15/97 06/16/97 06/17/97 06118/97 06/19/97 06/20/97 06/21/97 06/22/97 06/23/97 06/24/97 06/25/97 06/26/97 06/27/97 06/28/97 06/29/97 06/30/97 07/01/97 07/02/97 07/03/97 07/04/97 07/05/97 07/06/97 07/07/97 07/08/97 07/09/97 07/10/97 07/11/97 (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (rt) (ft) (ft) (ft) FIN TBG BOARD IN DRK. HANG TURBINE INTKE.INSTALL MUD END #2 Pdnted: 05/28/98 12:08:34 PM Legal Well Name: Common Well Name: Event Name: ;: Fin , ..Well' ./:EVe tsu'. ma:ry .... 07/12/97 07/13/97 07/14/97 07/15/97 07/16/97 07/17/97 07/18/97 07/19/97 07/20/97 07/21/97 07/22/97 07/23/97 07/24/97 07/25/97 07/26/97 07/27/97 07/28/97 07/29/97 07/30/97 07/31/97 08/01/97 08/02/97 08/03/97 08/04/97 08/05/97 08/06/97 08/07/97 08/08/97 08/09/97 08/10/97 08/11/97 08/12/97 08/13/97 08/14/97 08/15/97 08/16/97 NORTH COOK INLET UNIT-B NORTH COOK INLET UNIT B-1 Original Drilling O0O0O1 Start Date: 06/05/97 End Date: CONTINUE WLDG PROJECTS. SKID RIG OVER WELL. RU TURBINE EXHST. (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) 467 (fi) 530 (ft) 1,930 (ft) 2,646 (ft) 2,646 (ft) 2,646 (ft) 3,018 (ft) 3,770 (fi) 3,770 (ft) 3,770 (ft) 3,770 (ft) 3,770 (ft) 3,770 (ft) 3,770 (ft) 3,770 (ft) 3,770 (ft) 3,770 (ft) 3,780 (ft) HOOK UP MUD LINE, CMT MFLD,STNDPE, VENT LINE, SWIVEL,T/DRIVE. SKID CRANE,RU CAMP SUPPORTS. RU SERVICE TO TOP DR. WORK BOAT. CONT. WELD ON CAMP STRUCTURE, SET CUTTING INJ. WORK FLOOR WORK ON NEW QUARTERS. HANG FLOW LINE. HANG CAMERAS IN DRK. INSPECT TOP DRIVE . SET CAMP UNITS. WORK PUMPS & PLTFM PITS CONT. RU CAMP. OFF LOAD BOAT. CONT. PULL WIRES AND PLUMB RIG. INSTALL MUD END PMP ~2. TEST KOOMEY&REMOTE STA.TEST WTRPMP RU POOL ARCTIC ALASKA RIG #428 CONTINUE RIG UP RIG #428 CONTINUE RIG UP RIG 428 CONTINUE RIG UP RIG 428 RIG UP 428# CONTINUE RIG UP 428 CONTINUE RIG UP 428 RIG UP/PU 5" DP STD DERRICK/PU BHNCLEANOUT 30"/DRLG 405-467' DRILL TO 530/POOH/CHG BHA DRILLED, SURVEYED, & BUILT ANGLE F/530' TO 1930' DRILLED FROM 1930' TO 2646'/BACK REAM OUT OF HOLE TO RUN CSG FINISHED OUT OF HOLE W/BIT. RUN 62 JTS OF CSG TO 2579' FINISHED CIRC CSG/RAN DP IN HOLE/CEMENTED 20" CSG/RUN PK OFF FINISHED MU BHNDRILLED FLOAT TRACK/DRILLED TO 3018'. TD' HOLE AT 3770'/BK REAMED HOLE/POOH/ LD BHA,RU & RUN 13 3/8" CSG WI2 318" INJECTION STRINGS FINISHED RUNNING 13 3~8" CSG & CEMENTED SAME FINISHED CEMENTING CSG/ND DIVERTERJNU WELLHEAD ATTEMPT PERFORATING 2 3~8" STRINGS WINO SUCCESS ATTEMPTED DUMMY RUNS ON 2 3/8", NU BOP'S & CHOKE MANIFOLD BUIDING 10,000# MANIFOLD & NU BOP'S BUILDING CHOKE MANIFOLD & NU BOP'S BUILDING 10,000# CHOKE MANIFOLD FINISHED BOP TEST/CENTER RIG/TEST CSG/MU BHA RIH, TAG HARD @980', POH, RIH W/DRLG ASSY, DRILL CMT & LOT Pdnted: 05/28/98 12:08:34 PM Legal Well Name: NORTH Common Well Name: NORTH Event Name: Original COOK INLET UNIT-B COOK INLET UNIT B-1 Drilling 000001 Start Date: 06~05~97 End Date: 08/17/97 08/18/97 08/19/97 08/20/97 08/21/97 08/22/97 08/23/97 08/24/97 08/25/97 08/26/97 08/27/97 08/28/97 08/29/97 08/30/97 08/31/97 09/01/97 09/02/97 09/03/97 '09/04/97 09/05/97 09/06/97 09/07/97 09/08/97 09/09/97 09/10/97 09/11/97 09/12/97 09/13/97 09/14/97 09/15/97 09/16/97 09/17/97 09/18/97 09/19/97 09/20/97 09/21/97 4,463 (ft) 4,847 (ft) 4,899 (ft) 5,767 (ft) 5,892 (ft) 6,896 (ft) 7,350 (ft) 7,640 (ft) 8,375 (ft) 8,7Ol (ft) 9,006 (ft) .9,357 (ft) 9,641 (ft) 9,648 (ft) 9,727 (fl:) 10,115 (fi) 10,339 (ft) 10,378 (fl:) 10,378 (ft) 10,378 (ft) 10,378 (ft) 10,378 (ft) 10,378 (ft) 10,378 (ft) 10,378 (fi) 10,378 (ft) 10,378 (ft) 10,378 (ft) 10,378 (ft) 10,378 (ft) 10,495 (ft) 10,865 (ft) 10,865 (fi) 11,528 (ft) 11,748 (ft) 12,113 (ft) RIH W/MOTOR, PDC BHA, DRLD F/3780-4463' DRLD F4463-4644', POH F/BIT, RIH, DRLD TO 4847', TOP DR BRAKE FAILURE REMOVE TOP DR BRAKE, PU & STD BACK DP, REPAIR TOP DR, RIH, DRILL DRILL & SLIDE F/4899-5767', BACKREAM TO 4528' , TRIP F/BHA & BIT TIH W/PDC BIT, CLAY BALLING ON BIT, POH, TEST BOPE, RIH, DRILL SLIDE & DRLD F/5792-6751', SHORT TRIP, RIH, SLIDE & DRILL TO 6896' RIH W/NEW BHA & BIT, REAM 70' TO BTM, SLIDE & ROTARY DRILL F/6896-7340 SLIDE & ROTARY DRILL F/7'350-7640', POH F/BIT, RIH RIH W/NEW MILL TOOTH BIT, DRILL F/7640-8375' SLIDE & ROTARY DRILL F/8375-8701', CBU, POH F/BHA & BIT TIH W/NEW BIT/BHA. DRILLED FR/8701 - 9006 FT. DRILLED FROM 9006 TO 9357 FT. DRILLED FR/9357 - 9641'. CBU. BACKREAM OOH F/BIT & BHA CHANGE. FINISH POOH. TESTED BOP'S. PUN BIT/BHA. TIH. DRLG. DRILL 9648 - 9729'. BACKREAM OOH. CHANGED BIT & BHA. START TIH. FINISH TIH. DRILLED (RTRY) FPJ 9727- 10115 FT. DRILLED (RTRY) 10115 - 10339'. CIRC OUT GAS & RAISE MW. DRLD TO 10378'. RAISE MW. S/TRIP. RAISE MW. B/REAM OOH. FINISHED POOH. RAN OPEN HOLE LOGS, BOND LOG & RFT PRESS SURVEY FINISH RFT'S & RD SCHLUM. TIH. C&CM F/CSG. BACKREAM OOH. FINISH POOH. PU 5" HWDP. RU CSG TOOLS. NOW RNG 9 5/8" LINER. FINISHED RNG & CMTG 9 5/8" LINER. CIRC. POOH. TIH & SET PKR. SET PKR. CLEAN OUT 13 3~8". TEST BOPE. DRESS OFF TIEBACK. R/U SCHL, PERF 13-3/8 CSG, L/D BHA, EST INJ RATE, RUN CSG LAND TIE BACK CSG, INSTALL PACKOFF, TEST, ATTEMPT TO FIND LEAK POH W/RTTS, L/D HGR, P/U CSG, RELAND, PRESS TEST, L/D CSG, RIH W/MILL CIRC LINER TOP, POH, P/U SEAL ASSY & RIH W/CSG, LAND & TEST TO 5K CLEAN PITS, CHANGE MUD PUMP LINERS, CHANGE SCREENS, PREPARE F/OBM CONT. PREPARING TO SWAP TO OBM, TEST BOPE, M/U BHA & RIH RIH, TAG CMT, CBU, DRILL CMT TO LDG CLR, CLEAN PITS, BUILD OBM. BUILD OBM, PUMP HI VIS SWEEPS, DISPLACE TO OBM, DRILL AHEAD. CONTINUED DRILLING F/10,495'- 10,865' CBU, POH F/BHA & BIT, RIH, CIO KELLY HOSE, LOG & REAM TO BTM, DRILL WASH TO BTM W/CDR TOOL, DRILL F/10865-11528 DRLD TO 11660', POH TO SHOE, REPAIR TOP DRIVE, RIH, CIRC, DRILL DRLD F/11,748-12,113' Pdnted: 05~28~98 12:08:34 PM Legal Well Name: Common Well Name: Event Name: NORTH COOK INLET UNIT-B NORTH COOK INLET UNIT B-1 Original Drilling DATE TMD 12,252 12,378 12,952 13,477 14,045 14,273 14,273 14,333 14,393 14,453 14,468 14,888 14,972 15,013 15,056 15,308 15,500 15,500 (ft) 15,500 (ft) 15,5oo ¢) 15,500 (ft) 15,5oo (rt) 15,500 (ft) 15,5oo (rt) 15,5oo (ft) 15,5oo (ft) 15,500 (rt) 15,500 (ft) 15,500 (ft) 15,5oo (rt) (ft) (ft) (ft) (fi) (ft) (ft) (ft) (rt) (ft) (ft) (ft) (rt) (rt) (ft) (ft) (ft) (ft) 09/22/97 09/23/97 09/24/97 09/25/97 09/26/97 09/27/97 09/28/97 09/29/97 09/30/97 10/01/97 10/02/97 10/03/97 10/04/97 10/05/97 10/06/97 10/07/97 10/08/97 10/09/97 10/10/97 10/11/97 10/12/97 10/13~97 10/14/97 10/15/97 10/16/97 10/17/97 10/18/97 10/19/97 10/20/97 10/21/97 000001 Start Date: 06/05/97 End Date: · :. ': ;,:~::i i':: 24 HOUR SUMMARY DRLD F/12113'-12252', MOTOR FAILED, CBU, POH, PREPARE TO TEST BOPE. TEST BOPE, MAKE UP BHA, RIH, WASH & REAM TO BTM, DRILL. DRILLED ( RTRY ) FR/12378 TO 12952 FT. DRLG & SLIDING AHEAD - 8 1/2" SECTION. DRLG & SLIDING FR/13477 TO 14045'. DRLG 14045 - 14273' . CIRC F/SAMPLES. BACKREAM OOH F/CORE. FINISH B/RF__.AM TO SHOE. POOH. PU CORE ASSY & TIH. CUT 60' CORE IN SUNFISH FORM. CBU. POOH. LD CORE. 100% RECOVERY. TIH. CUT DRLG LINE. REPAIR TDS. FINISH TIH. CUT 2ND CORE. POOH. FINISH POOH & LD 2ND CORE. TIH W/3RD CORE BBL. CUT CORE. POOH. LD CORE #3. PU STEERABLE BHA & TIH. W&R (LOG) 180 FT TO BTM. DRILL DRLD 8 1/2" HOLE FPJ 14468 - 14888'. DRLD FPJ 14880 - 14972' (CORE POINT). BACKREAM TO SHOE. POOH. FINISH POOH. PU CORE ASSY & TIH. W&R TIGHT HOLE. CORE N FORLAND SAND. CORED N FORELAND SAND. POOH, LD CORE & CORE BBL. PU DRLG BHA. TIH. SLIP/CUT DRILL LINE. REAM/LOG TO BTM. DRLG 15056 - 15308'. DRLD F/15,308-15,500', CIRC BTMS UP. POH, TEST BOPE, R/U SCHLUMBERGER & LOG POH W/RUN #1, RUN LOG #2 LDT/CNL/GR, RJD SCHL, WIPER TRIP TO T.D. WIPER TRIP, UNSUCCESSFUL, DIPMETER & RFT WIRELING RUNS. WAITED ON SCHLUMBERGER ENGINEER/RIH W/RFT ON DP LJD NON FUNCTIONING RFT. MAKE STRING REAMER RUN TO OPEN HOLE REAMED TO BTM TO OPEN UP HOLE/POOH TO RUN RFT POOH/RU WL TIH W-RFT TOOL/TAKE SETS/POOH RD WL/TIH W/DP SET 2 CEMENT PLUGS/POOH INTO CSG-CBU-CUT DRLG LINE- WOC SET CMT PLUGS/TAG SAME REQUIRED BY STATE/POOH LD HWDP & TBG PULL WEAR BUSHING/CLEAN MUD PITS & RIG CLEAN BOP/ND STACK/NU DRYHOLE FLANGE/CLEAN PITS & RIG CONTINUED TO CLEAN RIG & PITS CLEAN PITS/RU JACKS/PREPARE SKID RO A-12. RELEASED RIG Pdnted: 05/28/98 12:08:34 PM PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS I~UILDING May 25, 1999 North Cook Inlet Unit "B" No. 1 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Cuttings Injection System Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Gentlemen: In response to your letter dated April 21, 1999, enclosed is a Schematic of the Cuttings Injection System with the following summary of the Phillips Petroleum Company operations for clarification as to what was happening. The 13 3/8" casing with the two strings of 2 3/8" tubing attached had been set and cemented to surface, providing zonal isolation to the Sterling Sand Interval. As the reports state, there was difficulty getting down the tubings to perforate, in fact the deepest we could get was 2600'. The decision was made to run the next string of casing (9 5/8") in two steps, rather than as a single intermediate casing string. With the approval of the AOGCC, the 9 5~8" casing was set as a liner, with the top of the liner set at 3588 and cemented. A liner top packer was also installed and set to further insure the integrity of the casing. The 13 3/8" casing and 9 5/8" liner were then tested to 3000 psi. At this point, the well was perforated in three separate wireline runs from 3500' - 3540' with the intent of penetrating both the Sterling Sand interval and the 2 3/8" tubing strings at the Sterling Sand level. The injection tests were ran and confirmed that we could pump into the Sterling Sands at acceptable rates via the 13 3/8" casing or the 2 3/8" tubings. With the tubings being perforated and in communication with the Sterling Sands, they were then used as the injection system rather than using the 9 5/8" x 13 3/8" annulus as this would provide more control over the system in the event the perforations or tubings became plugged with cuttings. We would be able to "rock" the system by pumping either down the tubings or the annulus and hopefully remedy any plugging problem. The 9 5~8" tie back string was then installed with a 10' seal assembly and landed at the surface. The 9 5/8" casing was pressure tested for integrity to 5000 psi. Operations continued with very few problems pertaining to the injection and disposal of the cuttings. Should you require any additional information, please contact P. R. Dean at (713) 669-3502. NPO/prd~ cc: Well File Regards, .... N. P. Omsberg -~' ~ ~" ~ 1 V ~-.,m,~!. E & P America's DrillingN~a..,rlAger~.t ~ " 0il & Gas Cons. TONY KNOWLES, GOVERNOR A~~S OIL AND GAS CONSERYATION COCa--II. SION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 21, 1999 N.P.Omsberg North America Drag. Mgr. Phillips Petroleum Co. Box 1967 Houston, Texas 77251-1967 Re: Annular Disposal Con_~g~-------------~ North Cook Inlet ~ Dear Mr. Omsbcrg: Your February 19,1998 letter to me states that "The cuttings are disposed of through the 2-3/8" tubing string attached to the 13-3/8" surface easing." From the Operation Summary describing attempts to get down thc two 2-3/8" tubing strings run to 3663', stropped to the 13 3/8" casing: 8/10/97 UNABLE TO GET PAST 1076' ON ONE STRING & 1930' ON THE OTHER STRING. TRIED DIFFERENT HOOK-UPS W/NO SUCCESS ...... SLICK LINE PROGRESS = 1768' & 1538'. UNABLE TO GET ANY DEEPER. 8/11/97 ATTEMPT I 318" DUMMY RUNS ON BOTH 2 318" INJECTION STRINGS W/N SUCCESS. 2550 & 2600' MAX PROG. An APPLICATION FOR SUNDRY APPROVALS No. 397-176 Dated 8/21/97 states: Approval is requested to alter the approved casing program. The request is made due to the inability to successfully perforate the 2 3/8" tubing strings designed for the cullings injection service. The alteration consists of setting The 9 5/8" casing string shallower (above the MGS formation), and setting it as a liner, with subsequent tie-back being made after perforating and completing the ,'umulus as a disposal horizon for the oil base cuttings. From Operation Summary: 9/9/97 RIH W/4.5' CSG GUNS & PERF AT 4 SPF STERLING SANDS FOR DISPOSAL. ON RUN #1 F/3530 TO 3540', RUN #2 F/3520-3530' . ..... RIH WITH GUN RUN RR #3 & PERFORATE F/3500' TO 3520'. ALL SHOTS FIRED ....... CLOSED BLINDS & ESTABLISHED INJ RATE THROUGH STERLING PERFS AS FOLLOWS; ...... 1000 PSI AT 8.0 BPM. TOTAL OF 45 BBLS INJECTED. 9/13/97 PERFORMED INJECTION TEST WITH APOLLO THRU INJECTION TBG: ~A BPM ~ 1150 PSI. % BPM ~ 1250 PSI, 1-1/2 BPM (?~ 1400 PSI. ' ._. N. P. Omsb~rg ~ 2 April 21, ! 999 On thc completion report ( ! 0-407) signed bx' Paul Dean on Nov i 2, 1997 under section 24. Perforations open to Production (MD+~:VD of Top and Bottom' and interval, size, ar~c~ number) "13 3/8" casing perforated from 3500-3540 (For purpose of cuttings disposal)" Please review this well and explain how the mud, water, and cuttings were pumped into the Sterling Formation. If the 2-3/8" tubing strings were used, please provide the information as to how they were drilled, cleaned out, and perforated for injection. If you have questions, please call me at 907-279-1433. Ext 226 or E-mail blair wondzell~admin.state.ak.us. Thank you for your efforts, Blair E. Wondzell, P.~ Senior Petroleum Engineer File:neiu-b-l.doe SCHEMATtL, ( OF CUTTINGS INJE~,,'ION SYSTEM Slurry Injection WellHead 20" x 13 318" Annulus nted to Surface 20" Conductor 2600' Tubing Clamps Cement o $18" Tie-Back Casing ~..3500' - ~! [~! I ~F....':F-~ Tubings Perforated n 4, 3540',, ~LJ~L*' ~ ~~j When Casing Perforated "T~bings Baker Liner Top Packer 3/8" Surface Cas'rog (?.~ I;".'~- XTop of Cement $18" Intermediate Casing ~~? r( (~ 10,376' ~,. PRD~ PERMIT 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 .{ AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 03/03/99 DATA T DATA PLUS RUN RECVD FLUID COMP CBL AIT-TVD AIT-MD RFT CN/LDT-TVD CN/LDT-MD DSS-TVD DSS-MD MWD-FET-MD MWD-FET-TVD DDL-MD 7864 DIR SRVY CDR-MD 'CDR-TVD RFT-32 PRES STA GR/CCL PERF REC~ CDR-TVD PIL/GR CN/LDT/MIRC6 L 1500-3760 1 L LGR(C) 8600-12870 1 L LGR(C) 10200-15590 1 L LGR(C) 14313-14498 1 L LGR(C) 8710-12870 L LGR(C) 10375-15500 1 L LGR (C) 8850-12825 1 L LGR (C) 10375-15445.80' 1 L LGR(C) 2646-15500 ,'.i FINAL L BL '2565-12880 FINAL L BL 2646-15500~~'' FINAL T SCHLUM AIT/DSI/DITE/LDT/CNT/ML 1,2 R SCHLUM 0-15498 L LGR 2575-15463 FINAL L LGR 2500-.12853 .~, FINAL L 4225-6284 1 L 3400-3650 1 L BL 2400-12400'~' 1 L 3700-9984 L 3700-9984 i 09/06/97 11/03/97 11/03/97 11/03/97 11/03/97 11/03/97 11/03/97 11/03/97 11/13/97 11/13/97 11/13/97 11/21/97 12/18/97 12/18/97 12/18/97 02/09/99 02/09/99 02/09/99 02/09/99 02/09/99 SGANNED SEP 1 2002 PHILLIPS PETROLEUM HOUSTON. TEXAS 77251-1967 BOX 1967 AMERICAS DIVISION COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Enclosed is a copy of the 'Conventional Core Analysis' 'Final Report' for the NC1U B-l, it unfortthuately a.,rived to.late to be. included in the two boxes that I sent earlier. If you need anything else, feel free to give me a call. Jim Lachenmaier ~ ? 13-669-3731 RECEIVED FEB 221~ I CONVENTIONAL CORE ANALYSIS FINAL REPORT For PHILLIPS PETROLEUM COMPANY NORTH COOK INLET UNIT NO. B-01 NORTH COOK INLET FIELD ALASKA Core Laboratories File No. 57151-18618 ORIGINAL RECEIVED FEB 22 19~ NinlcaO~ & Ga~'C~& Gonm~ion CORE LABORATORIES PETROLEUM SERVICEIS CONVENTIONAL CORE ANALYSIS FINAL REPORT For PHILLIPS PETROLEUM COMPANY NORTH COOK INLET UNIT NO. B-01 NORTH COOK INLET FIELD ALASKA Core Laboratories File No. 57151-18618 Prepared by Core Laboratories 5630 Guhn Road, Suite 100 Houston, Texas 77040 February, 1998. Corn Laboratories, Inc. 5630 Guhn Road, Houston, Texas 77040, (713) 460-8113, Fax (713) 460-8211 . PETROLEUM SERVICES February 20, 1998 Phillips Petroleum Company 6330 West Loop South Houston, Texas 77401 Attn: Mr. Mark Kingsley Core Analysis Report North Cook Inlet Unit No. B-01 North Cook Inlet Field Alaska Core Laboratories File No. 57151-18618 Dear Mr. Kingsley, Conventional cores from the subject well were retrieved at the wellsite by Core Laboratories' personnel. The cores were transported to Core Laboratories' Anchorage, Alaska facility for preliminary evaluation and sample preparation. All core material was the shipped to the Houston, Texas laboratory where analysis was performed .as directed by representatives of Phillips Petroleum Company. The following documentation includes: procedures for wellsite services, sample preparation and petrophysical measurements; a list of Houston laboratory personnel involved in this project; and the resultant data reported in tabular, graphical, and digital formats. The type of equipment used in each procedure is also specified. We appreciate this opportunity to be of service. If we can be of further assistance, please'do not hesitate to contact us. Sincerely, CORE LABORATORIES Michael R. Long Laboratory Manager Core Laboratories, Inc. 5630 Guhn Road, Houston, Texas 77040, (713) 460-8113, Fax (713) 460-8211 TABLE OF CONTENTS PROCEDURES DOCUMENTATION WELLSITE SERVICES SAMPLE PREPARATION CORE GAMMA CORE EXTRUSION PLUG DRILLING AND TRIMMING SAMPLE MOUNTING CORE SLABBING DETERMINATION OF SAMPLE DRYING METHOD SAMPLE SELECTION DEAN STARK ANALYSIS (SAMPLE SUBSET) PLUG CLEANING PLUG DRYING (HUMIDITY CONTROLLED) GRAIN VOLUME PLUG DIMENSIONS CMS-300 ANALYSIS (HUMIDITY DRIED SAMPLES) PLUG DRYING (CONVECTION OVEN) GRAIN DENSITY (CONVECTION OVEN DRIED SAMPLES ONLY) DEAN STARK SATURATIONS (SAMPLES SUBSET) DRYING METHOD SELECTION CONVENTIONAL PLUG ANALYSIS PLUG CLEANING PLUG DRYING GRAIN VOLUME CMS-300 PLUG ANALYSIS (CONVECTION DRYING) AMBIENT POROSITY CORE PHOTOGRAPHY QUICK TURNAROUND SUBSET- BAKERSFIELD LABORATORY CORE STORAGE SAMPLE SHIPMENTS REPORTS- TABULAR CMS-300 PLUG ANALYSIS CMS-300 PLUG ANALYSIS (HUMIDITY OVEN DRIED SUBSET) CMS-300 PLUG ANALYSIS (CONVECTION OVEN DRIED SUBSET) REPORTS - GRAPHICAL TOTAL CORE GAMMA APPENDICES APPENDIX A: QUICK TURNAROUND SUBSET- BAKERSFIELD LABORATORY APPENDIX B: LIST OF PROJECT ANALYSTS AND PERSONNEL APPENDIX C: REPORT DISTRIBUTION WELLSITE SERVICES Personnel from Core Laboratories' Anchorage facility retrieved the cores at the wellsite. The aluminum core barrel liner was wiped to remove drilling mud and marked with orientation lines and depth marks. Pipe cutters were used to cut the liner into 3' segments. Excess drilling mud was drained off. One end of each segment was capped and sealed with a hose clamp and duct tape. All relief holes were also covered with duct tape. The annular space of each segment was filled with 2% KCI brine solution to within 4 inches of the top. Caps were then placed on the open end of each segment and secured with a hose clamp and duct tape. The segments were packed in boxes provided by Phillips Petroleum and transported to Core laboratories' Anchorage, Alaska facility. SAMPLE PREPARATION CORE GAMMA: Upon arriVal at the Anchorage lab the natural gamma radiation count of the core was recorded as a function of depth and was recorded in APl units of gamma activity The instrument was calibrated against APl standards and adjusted for background radiation. The digital core gamma data was e-mailed to Phillips Petroleum in Houston, TX. CORE EXTRUSION: Upon completion of the core gamma measurement, the core was processed in 9-foot sections. Each section was extruded from the 'aluminum"liner and plugged as described below. PLU.G DRILLING and TRIMMING: One and a..half.inch diameter.plugs, were drilled at. points designated by 'Phillips Petroleum. Company .representatives. These plugs were drilled and clipped using isopar as the drilling and .trimming. lubricant. The plugs were faced with a diamond end-facing tool.to provide right cimular cylinders.. Trimmed ends .were catalogued and stored. All plug samples were labeled, wrapped in Saran wrap and aluminum foil, and placed in ProtecCore pouches. A small subset of plug samples was shipped to Core Laboratories' Bakersfield, CA lab for analysis. The .remainder of the plug 'samples were shipped to the Houston, TX facility. SAMPLE MOUNTING: Several samples were friable and required mounting prior to analysis. The samples were mounted in tin sleeves with sets of 60 mesh and 120 mesh stainless steel screens on each end. Each plug was then seated in a hydrostatic cell at 400 psi to eliminate the annular space between the sleeve material and the plug. CORE SLABBING: A vertical slab saw was used to cut the core vertically into 1/3 - 2/3 sections. A 2% KCI solution was used as the blade coolant/lubricant. The 2/3 section was shipped to Phillips Petroleum Company, 1401 West 14th Street, Bartlesville, OK, 77004, to the attention of Mr. Bill Holeman. The 1/3 section was shipped to Core Laboratories, Inc., Houston, Texas. DETERMINATION OF SAMPLE DRYING METHOD SAMPLE SELECTION: A subset of samples was selected to determine the best drying method to use for the routine plug analysis. Mr. Jim Hedges selected the samples to be tested. . DEAN STARK ANALYSIS (SAMPLE SUBSET): Each sample was weighed, placed in a glass tare, and extracted of hydrocarbons and water using a Dean Stark apparatus. The Dean Stark method uses toluene as the refluxing solvent. Each sample was suspended over boiling toluene at approximately 240 degrees. Toluene vapor, along with water vapor from each sample, was cooled in a distillation tower and collected in a receiving tube where the water separated from the toluene. The extracted oil remained in the toluene. PLUG CLEANING: The samples were cleaned in a soxhlet extractor to remove any hydrocarbons and salts remaining after Dean Stark analysis. A chloroform/methanol azeotrope was used as the refluxing solvent. Extraction was continued until the returning solvent was clear. PLUG DRYING (HUMIDITY CONTROLLED): All samples were first dried in a humidity oven at 140 degrees F. and 40% relative humidity until weight stabilization was achieved. GRAIN VOLUME: Direct' grain volume measurements were made using an automated porosimeter. This instrument utilizes the principle of gas expansion as described by Boyle's law. Helium was used as the test gas. The instrument was calibrated daily and test standards were run to verify instrument accuracy. PLUG DIMENSIONS: Sample lengths and diameters were measured using digital metric calipers. CMS-300 PLUG ANALYSIS (HUMIDITY DRIED SAMPLES): A, PERMEABILITY "k": Permeability. was measured by flowing helium from a reference cell through the plug samples. The downstream, end of the plug was maintained at atmosphericpressure~ The upstream pressure was initially at 240 psig and was allowed to' decay through, the sample. The pressure decay vs. time was monitored, and recorded digitally. The net confining stresses, used for . the subset were 800 psig .and'2000 psig. a. K-air: Permeability to air was calculated from time/pressure decay data. b, K-Klinkenberg: Unsteady state equations were used with time/pressure decay data to calculate the Klinkenberg slip corrected permeability. a. POROSITY: Pore volume was determined by expansion of helium into the core sample from a reference cell of known volume source. The cell was initially pressurized to approximately 240 psig. At pressure equilibrium, Boyle's Law was used to compute pore volume. Porosity was then calculated by using the measured pore volume and the grain volume from the auto-porosimeter. PLUG DRYING (CONVECTION OVEN):. All samples were re-dded in a convection oven at 240 degrees F. until weight stabilization was achieved. Grain volume, plug dimension and CMS-300 measurements were then repeated. GRAIN DENSITY (CONVECTION OVEN DRIED SAMPLES ONLY): Calculated grain densities were obtained utilizing grain volume measurements and clean, dry sample weights. Grain densities were checked against lithology standards. DEAN STARK SATURATIONS (SAMPLE SUBSET): Saturations were calculated by using the measured water volume and a gravimetrically derived oil volume. An oil density of 0.89 g/cra3 and a water density of 1.00 g/cra3 were used for the calculations. Pore volumes were obtained from helium porosity data. DRYING METHOD SELECTION: At the conclusion of the drying test procedure, the decision was made by Mr. Jim Hedges to analyze the remaining plugs using the convection oven drying method. CONVENTIONAL PLUG ANALYSIS PLUG CLEANING: The remaining samples were cleaned in a soxhlet extractor to remove hydrocarbons and salts. A chloroform/methanol azeotrope was used as the refluxing solvent. Extraction was continued until the returning solvent was clear. PLUG DRYING: All samples were dried in a convection oven at 240 degrees F. until weight stabilization was achieved. GRAIN VOLUME: Direct grain volume measurements were made using an automated porosimeter. This instrument utilizes the principle of gas expansion as described by Boyle's law. Helium' was used as the test'gas. The' instrument was calibrated daily and test standards were run to verify instrument accuracy. CMS-300 PLUG ANALYSIS (CONVECTION 'DRYING): a. PERMEABILITY "'k":' Permeability was measured by flowing helium from a reference cell through the plug samples. The downstream end of the plug was maintained at atmospheric pressure. The upstream pressure was initially at 240 psig and' was allowed to' decay through the sample. The pressure decay vs. time was monitored and recorded digitally. Net confining stresses of 800 psig and 3700 psig were used for the Sunfish sand. Stresses of 800 and 2000 were used for the N. Foreland sand. a. K-air: Permeability to air was calculated from time/pressure decay data. b, K-Klinkenberg: Unsteady state equations were used with time/pressure decay data to calculate the Klinkenberg slip corrected permeability. C. POROSITY: Pore volume was determined by expansion of helium into the core sample from a reference cell of known volume. The cell was initially pressurized to approximately 240 psig. At pressure equilibrium, Boyle's Law was used to compute pore volume. Porosity was then calculated by using the measured pore volume and the grain volume from the auto-porosimeter. AMBIENT POROSITY: Bulk volumes for samples with permeabilities < 0.0001 mD were determined using the DEB unit. This device uses Archimedes' principle of buoyancy to determine bulk volume. A container of mercury is placed on a calibrated digital scale. The temperature of the mercury is measured so that the mercury density can be determined. The sample holder is positioned at a reference point and the scale is zeroed. The sample is then submerged in the mercury to the same reference point. The submerged sample weight was divided by the density of the mercury to yield the bulk volume. Porosities were calculated using the bulk volumes from the DEB and the grain volumes from the automated porosimeter. CORE PHOTOGRAPHY: The 1/3 section of the slabbed core was photographed under white light conditions. A "box" format, which displayed two slab boxes in an 8 x 10 photo, was used. Seven sets of completed photographs were delivered to Mr. Mark Kingsley in Houston, Texas. QUICK TURNAROUND SUBSET- BAKERSFIELD LABORATORY: Mr. Jim Hedges selected ten samples for quick turnaround analysis. The results of the analysis were reported under separate cover. For reference, a copy of the analysis is included in Appendix A of this report. CORE STORAGE: Plug samples that were shipped to the Houston lab but were not analyzed are currently stored at an off-site facility. The 113 slabbed sections were also stored off-site. SAMPLE SHIPMENTS: A subset of nine (9) plug samples was shipped to Core Laboratories' Carrollton, TX for extraction and oil analysis. These results were rePorted under separate cover. CORE LABORATORIES, INC. HOUSTON, TEXAS Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location : Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS Sample Depth Reservoir Pore Porosity Permeability Grain b(He) Beta Alpha Number Net Overburden Volume Klinkenberg I Kair, Density ft peig cm3 % md g/cm3 psi ft{-1 ) microns , ~ Sunfish Sand 1 14298.10 800 3.39 4.0 0.005 0.008 2.70 63.61 2.32E+ 16 3.60E+05 2 14301.10 800 6.89 15.1 4.879 6.054 2.66 13.65 6.72E+09 1.05E+02 2 14301.10 3700 6.49 14.4 3.796 4.696 13.43 1.27E+ 10 1.55E+02 3 14305.00 800 2.21 2.6 0.005 0.013 2.69 121.38 4.06E + 16 6.92E + 05 4 14306.90 800 1.86 3.3 0.020 0.024 2.70 13.22 1.99E + 16 1.22E + 06 4 14306.90 3700 1.42 2.6 0.001 0.003 270.80 8.32E+ 16 1.98E+05 5' 14309.80 1.53 1.8 <0.001 <0.001 ............... 6 14317.50 800 5.36 6.5 9.068 9.278 2.68 1.27 1.66E+ 10 4.24E+02 6 14317.50 3700 4.82 5.8 0.388 0.533 20.51 .......... '7 14318.30 800 4.99 6.0 0.037 0.071 2.68 69.99 1.36E+ 12 1.60E+02 7 14318.30 3700 4.33 5.3 0.009 0.012 31.36 6.92E+ 14 1.89E+04 8 14319.10 800 4.03 4.9 0.046 0.076 2.68 50.02 1.21E+14 1.68E+04 8 14319.10 3700 3.43 4.2 0.005 0.013 116.77 1.50E+ 14 2.38E+03 9 14320.20 800 4.40 5.3 0.079 0.129 2.66 46.47 7.46E+ 12 1.79E+03 9 14320.20 3700 3.73 4.5 0.010 0.024 95.37 1.88E+ 14 6.12E+03 10 14320.90 800 4.75 5.7 0.051 0.087 2.66 54.37 3.70E + 13 5.74E + 03 10 14320.90 3700 4.02 4.8 0.006 0.015 111.27 3.23E+ 14 6.26E+03 11 14322.20 800 6.35 7.6 0.025 0.053 2.68 89.49 6.70E + 13 5.25E + 03 ~11 14322.20 3700 5.48 6.7 0.006 0.011 71.68 1.08E+ 15 2.00E +04 12 14323.10 800 3.25 4.8 0.001 0.003 2.69 133.53 .......... 13 14323.90 800 4.47 5.4 0.004 0.008 2.69 98.60 .......... 14 14325.30 800 4.74 5.8 0.001 0.002 147.37 .......... FINAL REPORT Page f Company Well Field Location : PHILLIPS PETROLEUM COMPANY : North Cook Inlet Unit B-01 : 'Cook Inlet : Alaska CORE LABORATORIES, INC. HOUSTON, TEXAS CL File No: 57151-18618 Date: February 3. 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS -Sample Depth Reservoir' Pore Porosity ' ' Pe~meal~ility ' Grain blHe) Beta Alp'hE Number Net Overburden Volume .Kii'nkenberg I .. Kair . Density ft psi; cm3 % md glcm3 psi ft(-1 ) microns 15 14334, 50 800 3.14 3,8 0,002 0,005 2.66 90.27 .16 14335,50 800 5.05 6,0 0,979 1.045 2,66 4,20 16 14335,50 3700 3.95 4.8 0.009 0,014 29.06 17 14336.80 800 3,97 5,8 0.155 0,177 2.67 10.01 17 14336,80 3700 3,15 4,7 0,002 0,005 81,43 18 14344,20 800 1,29 1,5 0,095 0,104 3,39 6,86 18 14344.20 3700 1,21 1,4 0.005 0,013 129,08 19// 14347,50 .............................. 20 14348,40 800 7,07 9,6 0,172 0,256 2,69 34,36 20 14348,40 3700 6.29 8,6 0,035 0,068 65,47 21 14349,30 800 7.99 10.0 0,123 0.194 2.68 42,05 21 14349,30 3700 7,19 9.1 0,030 0,059 69,36 22 14350,80 800 8.25 10,4 0,145 0,224 2,69 38,36 22 14350,80 3700 7,41 9,4' 0,039 0.074 62,53 23 14351,30 800 5,61 7,0 0,080 0.135 2,69 49,66 23 14351,30 3700 4,93 6,2 0,019 0,040 78,86 24 14352,50 800 5,46 6,8 0,118 0.182 2,68 38,83 24 14352,50 3700 4,82 6,0 0,032 0,059 60,39 25 14353,10 800 6,48 8,4 0,212 0,292 2,67 26,17 25 14353,10 3700 5.79 7,6 0,066 O, 104 39.14 26 14354.50 800 5.82 7.5 0,029 0,055 2,69 68,96 26 14354,50 3700 5,12 6,7 0,012 0,016 31,87 27 14355.50 800 8,38 10.4 0.059 0.108 2.70 62,07 27 14355.50 3700 7.62 9.5 0.019 0.037 70.74 5,10E+ 15 3.85E + 04 1.08E+10 3.22E+01 5,41E+ 14 1,66E+04 5.48E+11 2,28E+02 4.41E+ 15 3,28E +04 1,52E+ 13 4,39E+03 1.71E+12 9.11E+02 1.27E+13 1,42E+03 5.47E+11 2.10E+02 9,49E+ 12 9,51E+02 9,49E+11 4,29E+02 3.30E+12 4,30E+02 4,48E+ 12 1,12E+03 6.50E+ 13 4,17E+03 8,46E+ 11 3,16E+02 1,46E+ 13 1,55E+03 1,97E+10 1,31E+01 6,09E + 11 1,34E + 02 2.78E+ 13 2.58E+03 1,07E+14 3,97E+03 2.68E+12 4.99E+02 5.28E+ 13 3.23E+ 03 FINAL REPORT Page 2 CORE LABORATORIES, INC. HOUSTON, TEXAS Company : PHILLIPS PETROLEUM COMPANY Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location : Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS Sample Depth Reeervoir ' Pore ' Porosity ' Permeability Grain b(He) Beta Alpha , Number Net Overburden Volume Klinkenberg I Kair, Density ft psig cm3 % md glcm3 psi ft(-1 ) microns 28 14356.30 800 7.46 9.3 0.024 0.055 2.70 105.06 5.76E + 12 4.34E + 02 .28 14356.30 3700 6.78 8.6 0.012 0.020 53.67 4.21E+ 14 1.63E+04 29 14357.50 800 8.88 11.2 0.158 0.237 2.68 35.01 4.23E+ 11 2.10E+02 29 14357.50 3700 8.10 10.3 0.044 0.081 58.24 1.55E+ 13 2.19E+03 30 14358.50 800 10.39 13.3 0.934 1.219 2.66 19.15 2.26E+ 11 6.67E+02 30 14358.50 3700 9.57' 12.4 0.445 0.575 18.35 1.35E+ 10 1.92E+01 31 14359.10 800 7.70 11.5 0.502 0.688 2.66 24.26 2.87E+ 11 4.57E+02 31 14359.10 3700 7.04 10.6 0.211 0.297 26.69 3.52E+ 11 2.44E+02 32 14360.40 800 9.05 11.5 0.595 0.737 2.68 15.46 3.32E + 12 6.15E + 03 32 14360.40 3700 8.23 10.5 0.170 0.250 30.28 1.26E+ 12 6.82E+02 33 14361.50 800. 9.93 12.0 0.679 0.840 2.66 15.12 2.53E+ 12 5.37E+03 33 14361.50 3700 9.14 11.1 0.243 0.339 25.34 5.11E+11 3.96E +02 34 14362.50 '800 9.44 11.9 0.630 0.787 2.67 16.04 2.93E + 12 5.74E + 03 34 14362.50 3700 8.64 11.0 0.194 0.283 29.41 5.74E+ 11 3.56E+02 35 14363.80 800 9.78 12.4 0.764 1.015 2.66 20.84 2.64E+ 11 6.36E+02 35 14363.80 3700 8.97 11.5 0.353 0.464 19.96 2.43E + 11 2.75E + 02 36 14364.30 800 9.02 11.5 0.431 0.562 2.68 20.10 1.18E+11 1.57E+02 36 14364.30 3700 8.21 10.5 0.129 0.195 34.27 2.48E+ 12 1.02E+03 37# 14365.40 ........................................ .. 38 14366.20 800 8.62 10.8 0.429 0.562 2.67 .-. 20.44 1.37E+ 11 1.85E+02 38 14366.20 3700 7.82 10.0 0.146 0.217 32.17 1.94E+ 12 9.06E+02 39 14367.50 800 7.88 9.8 1.139 1.440 2.68 16.37 4.46E+ 10 1.57E+02 39 14367.50 3700 7.06 8.9 0.365 0.484 20.17 1.47E + 11 1.72E + 02 40 14368.50 800 6.62 8.3 0.688 0.896 2.68 19.36 1.28E + 11 2.70E + 02 FINAL REPORT Page 3 Company Well Field Location : PHILLIPS PETROLEUM COMPANY : North Cook Inlet Unit B-01 : Cook Inlet : Alaska CORE LABORATORIES, INC. HOUSTON, TEXAS CL File No: 57151-18618 Date: February 3, 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS Sample Depth ' Reeewoir Pore" Porosity ' ' Permeability Grain b(He) Beta Alpha Number Net Overburden Volume ' 'Kli~kenberg I KaJr Density ff - psig cm3 % md glcm3 psi ft(-1 ) microns 40 14368.50 3700 5.77 7.3 0.166 0.241 28.57 1.02E+ 12 5.42E+02 41 14369.50 800 5.42 6.8 0.190 0.267 2.68 28.12 1.10E+12 6.35E+02 41 14369.50 3700 4.64 5.9 0.021 0.043 72.33 3.54E+ 13 2.37E +03 42 14370.50 800 8.76 11.0 2.161 2.567 2.67 11.19 8.41E+09 5.55E+01 42 14370.50 3700 7.82 10.0 0.466 0.589 15.67 2.06E+ 12 3.07E +03 43# 14371.50 ........................................ 44 14374.50 800 8.58 11.4 2.499 2.990 2.69 11.60 1.52E+ 10 1.17E+02 44 14374.50 3700 7.65 10.2 0.640 0.850 19.36 2.69E+ 11 5.53E+02 45 14375.50 800 6.58 9.9 1.561 1.937 2.67 14.66 1.51E+ 10 7.40E+01 45 14375.50 3700 5.78 8.8 0.459 0.622 21.72 3.22E + 11 4.88E + 02 46# 14376.50 ........................................ 47 14377.50 800 6.72 9.2 0.910 1.143 2.67 16.09 2.71E+ 10 7.51E+01 47 14377.50 3700 5.76 8.0 0.101 0.158 35.20 2.82E+ 12 8.94E+02 48 14378.50 800 8.32 10.3 1.066 1.313 2.66 14.42 3.73E + 10 1.22E + 02 48 14378.50 3700 7.32 9.2 0.210 0.286 22.72 6.90E+ 10 4.58E+01 49 14378.90 800 8.52 10.8 1.670 1.992 2.66 11.66 2.14E + 10 1.09E + 02 49 14378.90 3700 7.42 9.5 0.312 0.406 18.33 3.94E+ 11 3.94E+02 50 14380.50 800 6.46 8.1 0.392 0.508 2.67 19.69 1.05E+11 1.27E+02 50 14380.50 3700 5.64 7.1 0.062 0.104 44.03 8.15E+ 12 1.63E+03 51 14381.70 800 5.48 6;9 0.049 0.072 2.79 36.28 7.04E+ 13 1.09E+04 51 14381.70 3700 4.97 6.3 0.013 0.022 54.19 1.47E+ 14 6.27E +03 52# 14382.50 ........................................ 53 14383.50 800 2.73 3.'4 0.036 0.048 2.77 26.39 3.28E+ 15 3,65E+05 '53 14383.50 3700 2.26 2.8' 0.003 0.009 156.00 7.89E+ 15 8.05E +04 FINAL REPORT Page 4 CORE LABORATORIES, INC. HOUSTON, TEXAS Company :- PHILLIPS PETROLEUM COMPANY Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location · Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: LonglKosterlMcEIroy CMS-300 PLUG ANALYSIS Sample Depth Reservoir Pore Porosity .. Permeability "' Grain b(He) Beta Alpha Number Net Overburden Volume Klin~(enberg J Kair Density ft pslg cm3 % md glcm3 psi ft(-1 ) microns ~ , 54 14384.50 800 3.10 3.8 0.023 0.032 2.77 31.15 6.00E+ 15 4.41E+05 54 14384.50 3700 2.75 3.4 0.003 0.007 129.14 3.42E+ 15 2.97E+04 55 14385.40 800 4.20 5.2 0.044 0.071 2.76 47.03 3.84E + 14 5.34E + 04 55 14385.40 3700 3.68 4.6 0.008 0.018 94.13 1.78E + 14 4.78E + 03 56 14386.50 800 4.15 5.1 0.040 0.064 2.76 45.59 1.98E+ 13 2,49E+03 56 14386.50 3700 3.81 4.7 0.012 0.022 60.85 9.60E + 13 3.90E + 03 57 14387.50 800 6.07 7.5 0.140 0.210 2.67 35.59 6.25E+ 10 2.70E+01 57 14387.50 3700 5.18 6.5 0.024 0.047 69.76 4.01E+ 13 3.21E+03 58# 14388.50 ........................................ 59 14389.40 800 7.23 9.0 0.134 0.201 2.68 35.60 2.42E+ 12 1.00E+03 59 14389.40 3700 6.37 8.0 0.028 0.054 66.90 3.66E + 13 3.39E + 03 60 14390.50 800 7.75 9.6 0.244 0.347 2.67 28.75 1.76E + 11 1.34E + 02 60 14390.50 3700 6.89 8.7 0.062 0.106 49.30 7.34E+ 12 1.50E+03 61 14391.50 800 7.79 9.6 0.209 0.290 2.73 27.18 1.51E+11 9.85E+01 61 14391.50 3700 6.95 8.7 0.035 0.063 55.54 2.06E+ 13 2.42E+03 62 14392.50 800 6.82 9.9 0.459 0.572 2.67 16.15 4.89E+ 12 6.97E+03 62 14392.50 3700 6.16 9.1 0.128 0.194 34.05 5.88E+ 11 2.39E+02 63 14394.20 800 7.99 9.5 0.980 1.242 2.67 16.76 4.18E+ 10 1.26E+02 63 14394.20 3700 7.08 8.5 0.212 0.299 25.56 6.01E+ 11 4.04E+02 64# 14395.50 ........................................ 65 14396.50 800 8.80 10.7 0.780 0.994 2.67 17.48 1.03E + 11 2.48E + 02 65 14396.50 3700 7.89 9.7 0.187 0.260 24.97 1.07E+ 11 6.34E+01 66 14397.50 800 - 8.97 11.2 0.867 1.106 2.67 17.37 1.20E+ 11 3.19E+02 66 14397.50 3700 8.09 10.3 0.254 0.348 23.32 7.12E+ 11 5.77E+02 FINAL REPORT Page Company Well Field Location :- PHILLIPS PETROLEUM COMPANY : North Cook Inlet Unit B-01 : Cook Inlet : Alaska CORE LABORATORIES, INC, HOUSTON, TEXAS CL File No: 57151-18618 Date: February 3, 1998 Analysts: LonglKosterlMcEIroy CMS-300 PLUG ANALYSIS , i , , Sample Depth Reeervoir Pore Porosity Permeabi!ity Grain b(He) Beta Alpha Number Net Overburden Volume Klinkenberg J Kair ' Density ft pe;g cm3 % md glcm3 psi ft(-1 ) microns , 67 14398.50 800 9.12 11.3 0.853 1.073 2.68 16.28 1.25E+11 3.26E+02 67 14398.50 3700 8.21 10.3 0.157 0.226 28.00 1.58E+ 12 8.22E +02 68 14399.50 800 8.84 11.0 1.044 1.299 2.65 15.21 8.21E+ 10 2.69E+02 68 14399.50 3700 7.99 10.1 0.331 0.434 19.30 1.27E+ 11 .1.35E+02 69 14400.50 800 7.28 10.7 0.883 1.130 2.65 17.59 8.19E+ 10 2.27E +02 69 14400.50 3700 6.62 9.8 0.335 0.446 20.88 1.56E+ 11 1.67E+02 70# 14401.60 ............. '~ .......................... 71 14402.10 800 9.71 11.8 0.950 1.204 2.65 16.79 1.41E+11 4.19E+02 71 14402.10 3700 8.83 10.8 0.315 0.422 21.18 2.76E+ 11 2.81E+02 72 14435.90 800 4.99 6.7 0.547 0.589 2.68 5.01 4.50E +08 7.62E-01 72 14435.90 3700 4.76 6.4 O. 186 0.268 28.41 .......... 73 14438.90 800 6.56 8.3 0.017 0.041 2.69 113.16 1.39E+ 13 7.62E+02 73 14438.90 3700 5.91 7.5 0.008 0.013 54.20 7.13E+ 14 1.82E+04 74 14447.50 800 2.80 3.4 0.002 0.006 2.71 161.53 2.72E+ 16 1.84E+05 North Foreland Sand 75 14972.50 800 7.02 8.4 0.017 0.037 2.68 97.87 6.26E+ 13 3.37E+03 75 14972.50 2000 7.30 8.7 0.013 0.028 92.73 1.01E+14 4.24E+03 76 14973.40 800 6.51 7.8 0.024 0.035 2.67 37.20 2.25E+ 15 1.71E+05 76 14973.40 2050 6.13 7.3 0.007 0.015 87.31 1.42E+ 15 3.27E +04 77 14974.40 800 6.62 7.8 2.077 2.217 2.63 4.02 3.17E + 11 2. IOE + 03 77 14974.40 2050 6.20 7.4 0.249 0.270 5.09 1.22E + 11 9.69E + 01 78 14975.50 800 6.96 9.8 0.077 0.127 2.67 48.32 3.46E+ 10 8.35E+00 FINAL REPORT Page 6 CORE LABORATORIES, INC. HOUSTON, TEXAS Company : PHILLIPS PETROLEUM COMIPANY ~ Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location : Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: LonglKosterllVlcEIroy CMS-300 PLUG ANALYSIS 'Sample Depth 'Reservoir Pore Porosity Permeability Grain b(He) Beta Alpha Number Net Overburden Volume Klinl~enberg I Kal,r, Density ft peig cra3 % md glcm3 psi ft(-1 ) microns , 78 14975.50 2050 6.59 9.4 0.037 0.066 59.78 1.05E+ 13 1.25E+03 79 14976.50 800 8.37 10.0 0.034 0.069 2.70 81.24 9.10E+ 11 9.59E+01 79 14976.50 2000 8.06 9.7 0.021 0.040 72.10 1.59E+13 1.09E+03 80 14977.50 800 8.81 10.5 0.114 0.181 2.67 41.71 3.55E+ 12 1.29E+03 80 14977.50 2050 8.40 10.1 0.055 0.098 55.44 1.03E+ 13 1.81E+03 81 14978.50 800 7.65 9.1 0.073 0.127 2.68 54.98 1.66E+ 12 3.76E+02 81 14978.50 2050 7.28 8.7 0.035 0.066 66.38 2.61E + 13 2.85E + 03 82 14979.40 800 3.19 4.0 0.033 0.048 2.69 33.29 1.49E+ 15 1.54E +05 82 14979.40 2050 2.98 3.7 0.008 0.019 100.99 8.78E + 13 2.32E + 03 83 14980.50 800 2.53 3.0 <0.001 0.002 2.76 303.19 .......... 84 14981.50 800 2.44 2.9 0.002 0.006 2.71 162.16 2.76E+ 16 1.87E+05 85 14982.50 800 2.52 3.0 0.003 0.007 2.70 154.16 7.14E+ 16 5.84E +05 86 14983.50 800 .1.78 2.6 0.009 0.013 2.69 38.51 1.53E+ 16 4.21E+05 86 14983.50 2050 1.63 2.3 0.002 0.005 131.46 7.69E + 14 4.97E + 03 87 14984.50 800 7.42 10.6 0.226 0.328 2.67 30.97 7.03E + 09 5.05E + 00 87 14984.50 2000 7.21 10.4 0.141 0.216 36.97 1.17E+ 12 5.34E+02 88 14985.50 800 9.18 11.0 0.246 0.333 2.68 24.22 6.66E+ 11 5.14E+02 88 14985.50 2050 8.82 10.6 0.133 0.197 33.06 7.46E+ 11 3.15E+02 89 14986.50 800 9.66 11.6 0.588 0.716 2.65 14.06 3.50E+ 12 6.51E+03 89 14986.50 2050 9.29 11.2 0.314 0.419 21.48 3.65E + 11 3.68E + 02 90 14988.50 800 3.72 4.4 1.839 1.974 2.79 4.40 5.41E+ 11 3.18E+03 90 14988.50 2050 3.55 4.2 0.482 0.526 5.59 4.09E+ 11 6.32E+02 91 14989.40 800 2.03 2.4 0.006 0.009 2.74 48.44 1.99E+ 16 3.80E+05 91 14989.40 2000 1.89 2.2 0.003 0.004 57.97 7.81E+ 16 7.17E+05 FINAL REPORT Page 7 CORE LABORATORIES, INC, HOUSTON, TEXAS Company :. PHILLIPS PETROLEUM COMPANY Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location · Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: LonglKoster/McEIroy CMS-300 PLUG ANALYSIS Sample Depth Reservoir Por'e PoroSity ' . Permeability Grain b(He) Beta Alpha Number Net Overburden Volume Kli~kenberg I Kair,, Density ft psig cm3 % md glcm3 psi ft(-1 ) microns , , , 92 14990.50 800 7.02 8.6 0.140 0.193 2.67 27.02 1.33E+ 12 5.94E+02 92 14990.50 2050 6.61 8.2- 0.056 0.088 40.71 8.92E+ 12 1.63E+03 93 14991.50 800 7.59 9.3 0.444 0.569 2.65 18.54 2.11E+ 10 3.01E+01 93 14991.50 2050 7.11 8.7 0.203 0.279 24.77 3.64E+ 11 2.40E +02 94 14992.50 800 7.18 8.6 0.237 0.309 2.67 20.78 4.45E+ 11 3.36E+02 94 14992.50 2000 6.83 8.2 0.109 0.159 31.25 1.30E+ 12 4.59E+02 95 14993.50 800 5.83 8.5 0.449 0.546 2.67 14.19 3.26E+ 12 4.65E +03 95 14993.50 2050 5.48 8.0 0.189 0.261 25.06 6.32E+ 11 3.84E+02 96 15008.70 800 5.24 6.5 0.009 0.017 2.68 75.72 1.16E+15 3.36E+04 96 15008.70 2050 4.94 6.2 0.004 0.008 98.00 3.92E + 15 5.20E + 04 97 15009.50 800 6.56 8.0 0.014 0.026 2.68 70.58 8.58E+ 1.4 3.88E+04 97 15009.50 2050' 6.14 7.6 0.006 0.013 91.97 2.01E+ 15 4.06E+04 98 15010.50 800 7.60 9.0 0.019 0.037 2.68 78.98 5.36E+ 14 3.13E+04 98 15010.50 2000 7.28 8.7 0.010 0.020 91.06 3.98E+ 13 1.26E+03 99 15011.50 800 9.23 11.4 0.593 0.755 2.65 17.70 2.25E+ 12 4.25E +03 99 15011.50 2050 8.79 10.9 0.307 0.430 25.84 2.64E + 11 2.63E + 02 100 15012.50 800 8.10 10.0 0.050 0.092 2.67 63.96 8.64E+ 12 1.36E+03 100 15012.50 2050 7.69 9.5 0.026 0.049 65.59 3.91E+ 13 3.37E +03 101 15013.50 800 8.97 11.0 0.134 0.208 2.67 39.14 1.76E+ 12 7.50E +02 101 15013.50 2050 8.57 10.6 0.067 0.115 51.40 7.31E+ 12 1.58E+03 102 15014.50 800 8.31 10.0 0.041 0.081 2.68 75.14 9.08E+ 12 1.16E+03 102 15014.50 2000 8.00 9.7 0.026 0.049 70.55 1.89E+ 13 1.59E+03 103 15015.10 800 6.64 9.7 0.045 0.082 2.68 62.84 1.10E+ 13 1.55E+03 103 15015.10 2050 .6.31 9.3 0.023 0.044 71.23 5.26E+ 12 3.88E +02 FINAL REPORT Page 8 CORE LABORATORIES, INC. HOUSTON, TEXAS Well : North Cook Inlet Unit B-01 Field · Cook Inlet Location : Alaska CL File No: 57151-18618 Date: February 3. 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS Sample DePth Resewoir Pore ' Porosity " Permeability ' Grain b(He) Beta Alpha Number Net Overburden Volume Klinkenberg I Kair Density , ft p.ig . cra3 % md 9/cm3 psi ft{-1) . microns 104 15016.50 .800 8.92 10.7 0.125 0.205 2.68 46.01 2.34E+ 12 9.22E+02 104 15016.50 2050 8.48 10.2 0.0,53 0.100 63.53 8.13E+12 1.40E +03 105 15017.50 800 4.97 7.0 0.348 0.468 2.57 23.14 .......... 105 15017.50 2050 4.85 6.9 0.218 0.307 27.28 .......... 106. 15018.50 800 8.76 10.6 0.133 0.205 2.67 39.01 4.91E+11 2.06E +02 106 15018.50 2000 8.42 10.2 0.076 0.128 49.72 2.88E+ 11 7.06E +01 107 15019.40 800 8.53 11.5 0.730 0.980 2.65 21.90 2.46E + 11 5.73E +02 107 15019.40 2050 8.12 11.0 0.574 0.706 14.73 3.75E+ 12 6.97E+03 108 15020.50 800 7.52 9.0 0.152 0.231 2.66 36.31 3.47E+ 11 1.67E+02 108 15020.50 2050 7.08 8.5 0.073 0.123 47.91 4.71E+ 12 1.12E+03 109 15021.50 800 3.76 4.4 0.043 0.074 2.68 56.95 2.76E+ 14 3.72E +04 109 15021.50 2050' 3.46 4.1 0.015 0.031 87.25 1.08E+15 5.25E +04 110 15022.50 800 1.97 2.3 0.001 0.003 2.71 83.89 1.53E+ 16 6.82E +04 111 15023.50 800 5.05 6.3 0.025 0.046 2.69 66.64 4.73E+ 14 3.78E+04 111 15023.50 2050 4.67 5.8 0.008 0.017 96.20 2.69E+ 14 7.11E+03 112 15024.50 800 6.95 8.5 0.033 0.064 2.67 74.30 7.43E+ 13 7.75E+03 112 15024.50 2050 6.56 8.1 0.015 0.031 78.96. 9.59E+13 4.91E+03 113 15025.50 800 7.63 9.5 0.076 0.126 2.68 49.53 8.27E+ 12 1.98E +03 113 15025.50 2050 7.19 9.0 0.032 0.061 68.28 2.45E+ 13 2.54E +03 114 15026.50 800 8.17 9.8 0.123 0.196 2.68 42.49 1.15E+12 4.48E +02 114 15026.50 2000 7.81 9.4 0.067 0.118 53.86 1.75E+11 3.83E +01 115 15027.50 800 6.08 9.0 0.113 0.174 2.68 39.35 3.17E+ 12 1.13E+03 115 15027.50 2050 5.74 8.5 0.047 0.085 57.15 1.21E+11 1.84E+01 116 15028.50 800 4.96 7.3 0.331 0.449 2.61 24.00 .......... FINAL REPORT Page 9 CORE LABORATORIES, INC, HOUSTON, TEXAS Company .'-PHILLIPS PETROLEUM COMPANY Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location : Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: LonglKosterlMcEIroy CMS-300 PLUG ANALYSIS Sample Depth Reservoir Pore Porosity Permeability Grain b(He) Beta Alpha Number Net Overburden Volume Klinkenberg I Kair Density ft , peig cm3 ,% md g/cm3 psi ft(-1) microns 116 15028.50 2050 4.85 7.1 0.211 0.299 28.08 .......... 117 15029.50 800 7.80 9.3 0.095 0.152 2.69 43.53 3.88E+ 12 1.17E+03 117 15029.50 2050 7.39 8.8 0.043 0.077 58.26 1.29E+ 13 1.79E+03 118 15030.50 800 7.45 8.9 0.263 0.368 2.68 27.16 6.00E+ 11 5.05E+02 118 15030.50 2000 6.83 8.2 0.105 0.167 41.28 2.84E+ 12 9.71E+02 119 15031.50 800 7.36 8.7 0.138 0.205 2.67 34.45 1.79E+ 12 7.81E+02 119 15031.50 2050 6.95 8.3 0.066 0.110 47.44 6.03E+ 12 1.29E+03 120 15032.50 800 8.08 9.6 0.240 0.326 2.67 24.79 8.75E+ 11 6.66E+02 120 15032.50 2050 7..64 9.2 0.120 0.179 33.95 3.36E+ 12 1.30E+03 121 15033.30 800 9.35 11.6 0.718 0.941 2.65 19.86 3.42E + 11 7.83E + 02 121 15033.30 2050 8.91 11.1 0.540 0.656 13.80 4.42E + 12 7.72E+03 122 15034.50 800 5.45 6.5 0.037 0.061 2.70 50.94 .......... 122 15034.50 2000 5.10 6.1 0.007 0.014 85.25 .......... Vertical Plugs 1v* 14309.80 1.61 2.9 <0.001 <0.001 0.00 .......... 2V + 14283.60 ........................................ 3v + 14284.50 ........................................ 4V 14293.70 800 6.06 7.7 0.016 0.030 2.70 74.83 2.40E + 16 1.21 E + 06 4V _ 14293.70 3700 4.66 6.0 0.003 0.006 122.11 2.40E + 17 1.99E + 06 5V* 14275.50 3.82 4.8 <0.001 <0.001 ............... 6V 14295.90 800 1.44 4.8 0.001 0.002 2.69 134.20 1.73E + 17 5.37E + 05 7V 14297.50 800 4.33 6.3 0.003 0.006 2.70 99.73 2.52E+ 16 2.51E+05 FINAL REPORT Page fO CORE LABORATORIES, INC. HOUSTON, TEXAS Company :. PHILLIPS PETROLEUM COMPANY Well : North Cook Inlet Unit B-01 Field · Cook Inlet Location : Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: Long/KosterlMcEIroy CMS-300 PLUG ANALYSIS Sample Depth Reeervoir Pore Porosity Permeability Grain b(He) Beta 'Alpha , Number Net Overburden Volume Klinkenberg I Kair Density ft, , peig cm3 % md glcm3 psi ft(-1) microns 7V -14297.50 3700 3.20 4.7 0.001 0.002 142.70 1.46E+ 18 4.20E +06 8V 14300.80 800 12.22 15.8 3.896 4.851 2.65 14.07 2.46E+ 10 3.09E+02 8V 14300.80 3700 11.61 15.1 3.030 3.772 14.07 4.45E+ 10 4.38E+02 9V 14304.70 800 2.09 2.6 0.002 0.006 2.69 158.05 1.65E+ 16 1.24E+05 IOV . 14307.30 800 3.77 4.7 0.003 0.006 2.68 102.69 .......... IOV 14307.30 3700 3.03 3.8 < 0.001 0.002 338.39 .......... 11V* 14309.40 0.93 1.2 <0.001 <0.001 ............... 12V 14319.90 800 3.69 4.6 0.036 0.066 2.68 62.98 1.35E+ 13 1.54E+03 12V 14319.90 3700 3.09 3.9 0.005 0.012 107.19 2.37E+ 14 3.75E+03 13V 14323.20 800 2.74 4.6 0.001 0.002 2.70 147.81 .......... 14V + 14330.00 ........................................ - 15V + 14332.10 ........................................ 16V 14334.20 800 2.85 3.5 0.003 0.005 2.67 94.22 5.98E+ 15 4.97E+04 17V 14337.20 800 4.18 6.0 0.682 0.770 2.68 8.26 1.48E+12 2.68E+03 ~ 17V 14337.20 3700 3.44 5.0 0.013 0.026 61.83 5.47E+ 14 2.42E+04 18V 14348.80 800 7.72 9.5 0.146 0.214 2.69 33.30 1.06E+ 12 4.75E +02 18V 14348.80 3700 6.78 8.4 0.023 0.041 57.22 3.02E+ 13 2.17E+03 19V 14354.70 800 9.19 11.6 0.641 0.849 2.66 20.80 2.47E+ 11 4.97E+02 19V 14354.70 3700 8.37 10.6 0.224 0.311 24.83 4.08E + 11 2.92E + 02 20V 14359.80 800 9.26 11.6 0.279 0.384 2.66 25.50 3.95E+ 11 3.47E+02 20V 14359.80 3700 8.41 10.6 0.075 0.121 41.01 5.53E+ 12 1.32E+03 21V 14365.30 800 8.52 10.8 0.207 0.295 2.69 29.27 2.72E+ 11 1.70E+02 21V 14365.30 3700 7.71 9.9 0.042 0.075 53.15 1.82E+ 13 2.46E+03 22V 14371.20 800 7.95 9.8 1.047 1.339 2.68 17.41 3.60E + 10 1.16E + 02 FINAL REPORT Page ff CORE LABORATORIES, INC, HOUSTON, TEXAS Company :- PHILLIPS PETROLEUM COMPANY Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location : Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS Sample Depth Reeervoir Po~e Porosity Perme'ab!lity , Grain b(He) Beta 'Alpha Number Net Overburden Volume Klinkenberg I Keir Density , ft peig cm3 % , md glcm3 psi ft(-1 ) microns 22V 14371.20 3700 7.09 8.8 0.191 0.275 27.19 1.35E+ 12 8.16E+02 23V 14377.20 800 5.02 6.6 0.516 0.637 2.67 5.33 2.82E+ 12 4.38E+03 23V 14377.20 3700 4.17 5.5 0.042 0.073 49.89 1.09E+ 13 1.53E+03 24V 14383.20 800 3.28 4.0 0.033 0.059 2.76 61.80 5.99E + 14 6.08E + 04 24V 14383.20 3700 2.77 3.4 0.006 0.013 95.42 9.66E + 15 1.88E + 05 25V 14389.30 800 7.31 9.0 0.174 0.258 2.68 33.69 1.64E+ 12 8.75E+02 25V 14389.30 3700 6.45 8.0 0.030 0.060 69.33 1.33E + 13 1.26E + 03 26V 14395.70 800 9.27 11.5 0.794 1.018 2.68 17.94 1.17E+11 2.82E+02 26V 14395.70 3700 8.39 10.5 0.114 0.173 33.12 3.25E+ 12 1.17E+03 27V 14401.30 800 9.78 12.2 0.907 1.169 2.66 18.15 1.88E+ 11 5.25E+02 27V 14401.30 3700. 8.93 11.3 0.307 0.409 20.99 4.03E+ 11 3.94E+02 -28V + 14402.80 ........................................ 29V + 14409.10 ........................................ 30V + 14414.30 ........................................ 31V 14421.60 800 3.65 4.5 0.001 0.002 2.79 140.88 .......... 32V 14427.50 800 7.15 9.1 0.784 1.019 2.66 18.97 3.92E+07 9.36E-02 32V 14427.50 3700 6.18 8.0 0.085 0.139 40.09 4.31E+ 11 1.16E+02 33V 14432.50 800 4.11 5.9 0.006 0.011 2.67 70.40 1.20E+ 15 2.28E+04 33V 14432.50 3700 3.35 4.9 0.001 0.002 108.96 2.69E + 16 7.69E + 04 34V 14438.50 800 4.39 6.7 0.006 0.012 2.71 97.99 5.74E+ 15 1.04E+05 34V 14438.50 3700 3.45 5.3 0.001 0.003 145.77 2.42E + 17 7.55E + 05 35V 14444.40 800 7.48 9.1 0.043 0.079 2.68 62.77 1.84E+ 13 2.45E+03 35V 14444.40 3700 6.63 '8.2 0.010 0.018 59.09 1.46E+ 14 4.78E+03 36V 14449.30 800 2.18 8.7 0.011 0.022 2.68 84.08 6.96E+ 14 2.37E+04 FINAL REPORT Page f2 CORE LABORATORIES, INC. HOUSTON, TEXAS Company Well Field Location :' PHILLIPS PETROLEUM COMPANY : North Cook Inlet Unit B-01 Cook Inlet : Alaska CL File No: 57151-18618 Date: February 3, 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS Sample Depth Re=ervoir Pore' Porosity 'Permeability Grain b(He) Beta Alpha Number Net Overburden Volume Klinkenberg I ,Kair Density ft p=ig cm3 % md glcm3 psi ft(-1 ) microns , 36V 14449.30 3700 1.74 7.1 0.002 0.006 197.68 2.63E+ 15 1.45E+04 37V 14972.30 800 7.53 9.2 0.025 0.038 2.67 43.71 4.33E+ 13 3.36E+03 37V 14972.30 2050 7.12 8.8 0.015 0.018 15.30 6.62E+ 13 3.25E +03 38V 14978.20 800 8.05 9.9 0.039 0.073 2.68 65.80 2.24E+ 13 2.77E+03 38V 14978.20 2050 7.65 9.5 0.018 0.033 61.37 6.50E+ 13 3.90E +03 39V 14984.80 800 9.26 11.5 0.601 0.730 2.66 13.88 3.56E+ 12 6.84E+03 39V 14984.80 2050 8.87 11.1 0.311 0.424 23.57 1.71E+11 1.70E+02 40V 14990.30 800 7.09 8.8 0.146 0.202 2.66 27.41 1.99E+ 12 9.05E+02 40V 14990.30 2050 6.68 8.3 0.050 0.083 46.78 1.39E + 13 2.22E + 03 41V + 14998.60 ........................................ 42V + 14999.30 ........................................ 43V + 15000.40 ........................................ 44V 15001.50 800 3.35 4.1 0.002 0.004 2.64. 113.78 .......... 45V 15002.30 ........................................ 46V 15003.50 800 2.83 3.6 0.001 0.003 2.67 102.14 1.33E + 16 5.73E + 04 47V 15005.30 800 2.78 3.5 <0.001 0.002 2.70 320.94 .......... 48V 15006.30 800 3.48 4.3 0.002 0.004 2.70 112.20 .......... 49V 15007.20 800 2.95 3.8 0.001 0.002 2.69 280.46 .......... 50V 15009.10 800 4.00 6.2 0.007 0.014 2.68 87.68 5.92E+ 15 1.33E+05 50V 15009.10 2050 3.68 5.7 0.002 0.006 135.56 9.02E+ 15 6.66E +04 51V 15016.00 800 8.74 10.9 0.082 0.135 2.67 47.63 2.48E+ 11 6.43E+01 51V 15016.00 2050 8.32 10.5 0.035 0.065 60.71 8.46E+ 12 9.83E +02 52V 15021.30 800 5.04 6.3 0.027 0.053 2.67 75.65 1.42E + 13 1.22E + 03 52V 15021.30 2050 4.66 5.9 0.011 0.022 86.30 1.19E+14 3.96E + 03 FINAL REPORT Page f3 CORE LABORATORIES, INC, HOUSTON, TEXAS Company Well Field Location :' PHILLIPS PETROLEUM COMPANY : North Cook Inlet Unit B-01 : Cook Inlet : Alaska CL File No: 57151-18618 Date: February 3. 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS SamPle Depth Re=ervoir Po~e Porosity Per. meability Grain ' b(He) ~eta AlPha Number Net Overburden Volume .. Klinkenberg I . Kair .. Density ft psig cm3 % ~d g/cm3 psi ft{-1 ) microns , , , 53V 15027.10 800 7.77 9.6 0.170 0.245 2.67 30.79 1.47E+ 12 7.95E+02 53V 15027.10 2050 7.35 9.1 0.070 0.119 48.08 1.38E+ 12 3.17E+02 54V 15033.10 800 8.26 11.5 0.828 1.079 2.65 19.16 2.30E+ 11 6.08E +02 54V 15033.10 2050 7.86 11.0 0.748 0.826 6.58 6.43E+ 12 1.55E+04 55V 15035.20 800 4.55 6.8 0.004 0.009 2,75 125.39 6.96E+ 14 7.97E+03 56V + 15039.30 ........................................ 57V + 15040.70 ........................................ 58V + 15045.70 ........................................ * Sample permeability < 0.001. Ambient porosity reported. + Sample failed during cleaning. No analysis performed. # No sample available for analysis. FINAL REPORT Page f4 CORE LABORATORIES, INC. HOUSTON, TEXAS Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location : Alaska CL File No · 57151-18618 Date: February 3, 1998 Analysts: Long/Koster/McEIroy CMS-300 PLUG ANALYSIS (Humidity Oven Dried Subset) Sample Depth Reservoir Pore Porosity Permeability, , b(He} Beta Alpha Number Net Overburden Volume Klinkenberg I Kair ft psig cm3 % md psi ft(-1 ) microns , ~ 75 14972.50 800 7.02 8.4 0.017 0.037 97.87 6.26E+ 13 3.37E +03 75 14972.50 2000 6.76 8.1 0.009 0.021 117.82 1.75E+ 14 4.98E+03 79 14976.50 800 8.37 10.0 0.034 0.069 81.24 9.10E+ 11 9.59E+01 79 14976.50 2000 8.06 9.7 0.021 0.040 72.10 1.59E+ 13 1.09E+03 83 14980.50 800 2.07 2.5 0.000 0.001 365.60 0.00E +00 0.00E +00 87 14984.50 800 7.42 10.6 0.226 0.328 30.97 7.03E +09 5.05E +00 87 14984.50 2000 7.21 10.4 0.141 0.216 36.97 1.17E+12 5.34E+02 91 14989.40 800 1.80 2.1 0.002 0.005 185.98 1.37E+ 16 7.44E +04 94 14992.50 .800 7.18 8.6 0.237 0.309 20.78 4.45E+ 11 3.36E+02 94 14992.50 2000 6.83 8.2 0.109 0.159 31.25 1.30E+ 12 4.59E+02 98 15010.50 800 7.60 9.0 0.019 0.037 78.98 5.36E+ 14 3.13E+04 98 15010.50 2000 7.28 8.7 0.010 0.020 91.06 3.98E+ 13 1.26E+03 102 15014.50 800 8.31 10.0 0.041 0.081 75.14 9.08E+ 12 1.16E+03 102 15014.50 2000 8.00 9.7 0.026 0.049 70.55 1.89E+ 13 1.59E+03 106 15018.50 800 8.76 10.6 0.133 0.205 39.01 4.91E+11 2.06E +02 106 15018.50 2000 8.42 10.2 0.076 0.128 49.72 2.88E+ 11 7.06E+01 110 15022.50 800 1.68 2.0 0.001 0.002 256.15 2.49E+ 16 5.14E+04 114 15026.50 800 8.17 9.8 0.123 0.196 42.49 1.15E+12 4.48E +02 114 15026.50 2000 7.81 9.4 0.067 0.118 53.86 1.75E+ 11 3.83E +01 118 15030.50 800 7.21 8.6 0.195 0.284 31.70 5.09E+ 11 3.17E+02 118 15030.50 2000 6.83 8.2 0.105 0.167 41.28 2.84E+ 12 9.71E+02 122 15034.50 800 5.30 6.3 0.012 0.022 74.06 0.00E + 00 0.00E + 00 122 15034.50 2000 5.06 6.0 0.004 0.009 100.33 0.00E +00 0.00E +00 FINAL REPORT Page CORE LABORATORIES, INC. HOUSTON, TEXAS Company · PHILLIPS PETROLEUM COMPANY Well : North Cook Inlet Unit B-01 Field : Cook Inlet Location · Alaska CL File No ' 57151-18618 Date · February 3, 1998 Analysts · LonglKoster/IVlcEIroy CMS-300 PLUG ANALYSIS (Convection Oven Dried Subset) Sample Depth Reservoir Pore Porosity Permeability b(He) Beta Alpha Number Net Overburden Volume Klinkenberg I Kair ft peig cm3 % md psi ft(-1 ) microns 75 14972.50 800 7.72 9.1 0.030 0.059 76.75 3.04E+ 13 2.88E+03 75 14972.50 2000 7.30 8.7 0.013 0.028 92.73 1.01E+ 14 4.24E+03 79 14976.50 800 8.97 10.7 0.052 0.099 66.50 1.14E+ 13 1.89E+03 79 14976.50 2000 8.60 10.3 0.027 0.051 69.59 3.24E+ 13 2.83E+03 83 14980.50 800 2.53 3.0 0.000 0.002 303.19 0.00E +00 0.00E+00 87 14984.50 800 7.87 11.2 0.307 0.430 27.17 3.24E+ 11 3.13E+02 87 14984.50 2000 7.58 10.8 0.166 0.255 36.01 6.19E+11 3.27E +02 91 14989.40 800 2.03 2.4 0.006 0.009 48.44 1.99E+ 16 3.80E+05 91 14989.40 2000 1.89 2.2 0.003 0.004 57.97 7.81E+ 16 7.17E+05 94 14992.50 800 7.90 9.4 0.329 0.419 18.29 2.20E + 11 2.32E + 02 94 14992.50 2000 7.50 9.0 0.138 0.198 28.90 1.00E+ 12 4.41E+02 98 15010.50 800 8.23 9.7 0.022 0.047 90.34 5.00E+ 13 3.58E+03 98 15010.50 2000 7.85 9.3 0.013 0.026 76.40 1.11E+14 4.70E +03 102 15014.60 800 8.99 10.8 0.064 0.116 60.65 4.80E+ 12 9.50E +02 102 15014.60 2000 8.60 10.3 0.033 0,062 66.92 7.76E+ 12 8.08E+02 106 15018.50 800 9.36 11.2 0.207 0.296 29.75 2.21E+ 10 1.43E+01 106 15018.50 2000 8.94 10.7 0.096 0.158 44.99 2.21E+ 12 6.69E+02 110 15022.50 800 1.97 2.3 0.001 0.003 83.89 1.53E+ 16 6.82E +04 114 15026.50 800 8.61 10.2 0.167 0.256 37.18 1.37E+ 12 7.24E+02 114 15026.50 2000 8.16 9.8 0.079 0.135 49.02 7.20E+ 12 1.85E+03 118 15030.50 '800 7.45 8.9 0.263 0.368 27.16 6.00E+ 11 5.05E+02 118 15030.50 2000 6.95 8.4 0.113 0.180 40.05 2.48E+ 12 9.10E+02 122 15034.50 800 5.45 6.5 0.037 0.061 50.94 0.00E +00 0.00E +00 122 15034.50 2000 5.10 6.1 0.007 0.014 85.25 0.00E + 00 0.00E +00 FINAL REPORT Page f6 TOTAL CORE GAMMA LOG ('' Phillips Petroleum North Cook Inlet Unit B-01, Cook Inlet Field, Alaska File No.: 57151-18618 Date: February, t998 TOTAL CORE GAMMA (APl) 20 40 60 80 100 120 140 160 180 200 14270 Vertical Scale: 5': 100 feet Core Laboretorlas, Inc. ,. TOTAL CORE GAMMA LOG Phillips Petroleum North Cook Inlet Unit B-O'I, Cook Inlet Field, Alaska ~ 20 File No.: 57151-18618 Date: February, 1998 TOTAL CORE GAM~ {APl) 40 60 80 100 120 140 160 180 200 Vertical Scale: 5': 100 feet Core Laboretor/as, Inc. TOTAL CORE GAMMA LOG Phillips Petroleum North Cook Inlet Unit B-IH, Cook Inlet Field, Alaska ~ 20 TOTAL CORE GAMMA (APl) 40 60 80 100 120 140 160 180 2O0 File No.: 57151.18618 Date: February, 1998 Vertical Scale: 5': qO0 feet Core Laboratories, Inc. [COR I PETROLEUM SERVICES APPENDIX A: QUICK TURNAROUND SUBSET- BAKERSFIELD LABORATORY Core Laboratories, Inc. 5630 Guhn Road, Houston, Texas 77040, (713) 460-8113, Fax (713) 460-8211 Sample Depth Perm Number Feet Ka md 1 14347.5 1 DS 14347.5 1HD 14347.5 0.515 0.322 Pot 12.7 10.1 6.5 Phillips Petroleum Co. "North Cook Inlet Unit*' B-O1 Cook Inlet Field Oil %PV 21.3 31.9 Water O/W %PV Ratio 69.3 0.31 68.0 0.47 Total Liquid ~.6 Grain Den 2.67 2.61 C.L. File: 57111-97419 Location: Sec. 6-Tl IN/R9W AP1 No. : 50-083-20093 IDescription Sst It tan vf-fgr vsIty slty lams It stn wh-bl flu Sst It tan vf-fgr vsity slty lams It stn wh-bl flu Sst gry vfgr v sity no stn no flu IMethod Retort Dean Stark Humidity-controlled drying 2 14353.3 2DS 14353.3 2HD 14353.3 1.248 0.862 16.5 12.1 9.6 17.8 67.5 0.26 85.3 10.6 86.1 0.12 96.7 2.67 2.62 Sst It tan vf-fgr vsIty It stn wh-bl flu SSt It tan vf-fgr vslty It stn wh-bl flu Sst gry vf-fgr v sity no stn no flu Retort Dean Stark Humidity-controlled drying 3 14359.3 3DS 14359.3 3HD 14359.3 1.317 0.824 16.9 12.9 10.0 22.5 68.8 0.33 91.3 11.4 86.7 0.13 98.2 2.66 2.61 SSt It tan vf-fgr vsity slty strk It stn wh-bl flu Sst It tan vf-fgr vsIty sity strk It stn wh-bl flu SSt gry vf-fgr v slty no stn no flu Retort Dean Stark Humidity-controlled drying 4 14365.4 4DS 14365.4 4HD 14365.4 O.575 0.382 14.1 11.0 8.5 24.6 65.2 0.38 89.8 21.4 74.8 0.29 96.3 Sst It tan vf-fgr vsity sity lams It stn wh-bl flu SSt It tan vf-fgr vsIty slty lams It stn wh-bl flu 8st gry vf-fgr v sity no stn no flu Retort Dean Stark Humidity-controlled drying 5 14371.5 5DS 14371.5 5HD 14371.5 1.473 0.800 11.4 8.9 6.0 21.1 64.9 0.32 88.0 31.1 68.7 0.45 99.8 2.67 2.62 Sst It tan vf-mgr vslty cly Incl It stn wh-bl flu SSt It tan vf-mgr vslty cly inol It stn wh-bl flu Sst gry vf-fgr v sity no stn no flu Retort Dean Stark Humidity-controlled drying 6 14376.5 6DS 1 4376.5 6HD 1 4376.5 4.096 2.476 16.5 13.0 8.4 17.7 70.9 0.25 88.6 19.8 80.1 0.25 99.9 Sst It tan vf-cgr vsIty It stn wh-bl flu SSt It tan vf-cgr vsity It stn wh-bl flu SSt gry vf-fgr v slty no stn no flu Retort Dean Stark Humidity-controlled drying 7 14382.5 7D S 14382.5 7HD 14382.5 0.081 0.C~4 4.1 2.6 1.9 13.0 60.9 0.21 73.9 49.2 48.0 1.02 97.2 2.73 2.71 SSt It tan vf-fgr vslty Ig sh lam It stn gld flu SSt It tan vf-fgr vslty Ig sh lam It stn gld flu Sitst gry no stn no flu Retort Dean Stark Humidity-controlled drying 8 14388.5 8DS 14388.5 8HD 14388.5 0.350 0.264 11.2 8.9 20.7 28.4 69.0 0.30 69.5 0.41 7.1 89.7 97.8 2.68 2.61 SSt It tan vf-fgr vslty It stn wh-bl flu SSt It tan vf-fgr vslty It stn wh-bl flu Sst gry vf-fgr v sity no stn no flu Retort Dean Stark Humidity-controlled drying 9 14394.3 9DS 14394.3 9HD 14394.5 2.475 1.284 16.0 13.3 8.8 9.3 81.4 0.11 90.7 9.4 90.4 0.10 99.8 Sst It tan vf-mgr vsIty sh incl It stn wh-bl flu Sst It tan vf-mgr vslty sh incl it stn wh-bl flu Sst gry vf-fgr v slty no stn no flu Retort Dean Stark Humidity-controlled drying Page 17 Core Analysis Results Sample Depth Perm Number Feet Ka md 9HD 14394.5 1.284 Por 8.8 Phillips Petroleum Co. "North Cook Inlet Unit" B-01 Cook Inlet Field Oil %PV Water O/W %PV Ratio Total Liquid Grain Den Description Sst gry vf-fgr v sity no stn no.flu C.L. File: 57111-97419 Location: Sec. 6-T11N/R9W AP1 No. : 50-083-20093 rMethod Humidity-controlled drying 10 14400.5 1ODS 14400.5 IOHD 14400.5 2.598 2.014 18.8 12.4 10.1 19.6 62.7 0.31 82.3 14.6 83.4 0.17 98.0 2.65 2.61 Sst It tan vf-mgr vslty It stn wh-bl flu SSt It tan vf-mgr vslty It stn wh-bl flu Sst gry vf-fgr v sity no stn no flu Retort Dean Stark Humidity-controlled drying Page 18 Core Analysis Results APPENDIX B: LIST OF PROJECT ANALYSTS and PERSONNEL LABORATORY MANAGER LABORATORY COORDINATOR LABORATORY TECHNICIAN SENIOR ANALYST LABORATORY TECHNICIAN TECHNICAL SALES REPRESENTATIVE MICHAEL R. LONG MICHAEL J. KOSTER ROBERTO CABAN JOE WEIR TRACY WUKASCH THOMAS SWISHER APPENDIX C: REPORT DISTRIBUTION PHILLIPS PETROLEUM COMPANY NORTH COOK INLET UNIT NO. B-01 NORTH COOK INLET FIELD ALASKA CL FILE NO. 57151-18618 FINAL REPORT 5 cc 1cc Phillips Petroleum Company 6330 West Loop South Houston, Texas 77401 Attn: Mr. Mark Kingsley Phillips Petroleum Company 130 GB Bartlesville, Oklahoma 74004 Attn: Mr. Jim Hedges Geologic Tops for Rock Unit: Cook Inlet A Cook Inlet 1 Beluga Fm. Tyonek Fm. Sunfish SS. N.Forelands SS. NCIU B-1 3,907' 4,187' 4,956' 9,250' 14,280' 14,967' ~q Oil Shows: None Zones of Abnormal Pressure: North Forelands SS. RECEIVED FF'B 0 9 1999 Alaska Oil & Gas Cons. Commissior~ Anchorage 4.5 lb/gal ,Mud 14.5 lb/gal Mud TOC O 14.5 lb/gal Mud .'iNG CASING & CEMENT 30" Q 407 BPV(Mak~,Type,OD) ABB Vetco-Gray Tbg. Hsr.(Make,Type) ABB Vetco-Gray Annulus Fluid: 14.5 lb/gal mud IRS(B-MSL: 132.00 TOC: Tagged TOC ~. 10,270' in 9 $/8" Casing iWater Depth 130.00 OD I Top B°n°m':'"l ~ I C~a~' I C°=' I Bm'~, Coil' i Team'.' Structural Casing: DHve Pipe 20"(~257~ _. ,AGRAM 2 Strings 2 3/8' 1~ 3663' 13 3/8 · (~ 376~ Lower Beluga, Tyonek ~ 9 5/8 · ~ 1037~ MGS "C" Sand Sunfish Sand 14273 - 14453 TOC ~ 14850' '? ..... North Forelands Sam ~14972 - 15056 Total Depth ¢~ 155oo 30" ~ 20" ' l~ ~/g- I 9 5/8" I Intermediate Tie-Back String 95/s- I 531 3,55sI 53.51b/ttI P-ilO I BT&C I 87101 Production Line~ Not Scl 7' I I I 3~,~I P-~o I ~&c I ~o~7ol Cuttings Dis~ Tubin~ (2 strings) 23/8" I S~I 3~6631 4.7 lb/R I N-80 I CSH~d,, I S910~ CEMENTING PROGRAM ~s 571 4071 I I ; Conductor Casing: PPCo. Allowable Ratings 571 ~5791 133.0 Ib/fl I K-$5 I BT&C I 28601 1410 Surface Casing: 571 3,7~01 7~..O~b/n I ~--so ! SL/X I 47301 Intermediate Liner:. 35881 10,3761 53.SIb/ffI P-II0 [ BT&C I STI0[ 1700 2520 761 7500 1159 20" Conductor 8/04/97 7500 1159 10150{ 688 102401 Cemented with 1690 sx ITburton Premium Cement with 3% gel + 0.50 % CFR-3 plus 1.0 % CaCl2 followed with 700 sx H'btmon Premium + 2.0 % CaCI2 + 0.2 % CFR-3. Cement circulated to surfacc. 13 3/8" Surface Cemented with 1234 sx H"ourton Premium Cement with 3% gel + 0.25 % CFR-3 8/09/97 plus 1.0 % CaCI2 followed with 672 sx H"ourton Premium + 2.0 % CaCI2 + 0.1% CFR-3. Ccment circulated to surface. 9 5/8" Intermediate Liner Lead Cemented with 2400 sx Halliburton Premium Cement with 3% gel + 0.5% CFR-3 + 0.2 % HR-5. TOC Cement with 704 sx II'burton Premium Cement with 0.20 % CFR-3 Tail '0.13gai/sxHalad344L+0.13 % HR-5. TOC (~ 9,400'. 9/06/97 650' cement plug from 15,500' to 14,850'. Not required to Tag. 261 sx Class "G" plus 0.2% CFR+0.08% tlR-5 ~ 15.~ lb/gaL 410' cement plug from 14560' to 14,150'. Tagging Required. 282 ax Class "G" plus 0.2% CFR+0.08% HR-5 ~ 15.8 lb/gal. Tagged Plug l~ 13,564'. 530' cement plug from 10800' to 10,270'. Tagging Plug Required. :535 ax Class "G" plus 0.2% CFR+0.08% HR-5 ~ 17.0 lb/gaL Tagged Plug li~ 10,029'. (Sidetrack Plug). Plug No. I Plug No. 2 Plug No. 3 The wellhead will be capped with a Vetco-Gray 10M blanking flange with 10M valve. PBTD: 10,270 ISupv: S'm~on; Bab'n'culTbg Wt: Well: . North Cook Inlet Unit "B" No. I Location: T}~onek Platform? Cook Inlet, A!,~tta_ IDate: October 16, 1997 Field: North Cook Inlet PRD PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING February 3, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: Mr. Robert Crandall Rc: Well Information Tyonek Deep Project Cook Inlet, Alaska Gentlemen: Phillips Petroleum hereby delivers two boxes containing the well information as described on the attached schedule. This information covers the four wells (North Cook Inlet Unit wells B-1, B-2, B-1 ST and B-3/B-3 ST1/B-3 BP1) which have been drilled to date as part of the captioned project. Some of the material included in this package may be redundant with information that was provided to you earlier. Please contact the undersigned at 713-669-2942 if you have any questions. cc: J. W. Lachenmaier Sincerely, Robert N. Welch Landman SCANNED SEP ! ~ 200~. General: Folder B-1: Folder B-I ST: Folder B-2: Folder B-3: 99-021.doc _TYONEK DEEP WELL INI( }/3/99) Core Sample Report (B-l, B-IST, B-2, B-3, B-3BP1, B-3ST) Geologic Tops (B-l, B-1ST, B-2, B-3) Operations Summary Report Well Completion/Re-completion Report and Log Schlumberger LIS Tape Verification Listing Blueline Logs: Fluid Comp. Cement Bond Phasor Induction w/GR Repeat Formation Tester- 32 Pressure Stations Comp. Neutron Litho-Density & Microlog w/GR/Calipers Comp. Neutron Litho-Density CrVD) Comp. Neutron Litho-Density (MD) CDR frVD) CDR (MD) Repeat Formation Tester 14-Oct- 1997 Array Induction (TVD) Array Induction (MD) Dipole Shear Sonic (MD) Dipole Shear Sonic (TVD) Gamma Ray CCL Formation Evaluation 2" MD Drilling Data Log 2'' MD MWD 2'' MD Operations Summary Report Well Completion Report Directional Survey Permit to Drill Scan Well Test (Prod. Test #1) Logs: CDR (TVD) Comp. Neutron Litho-Density w/GR (TVD) and (MD) Pressure Data Log Film: ADNR (TVD) Vellum: Pressure Data Log 1":250' Sepia: Pressure Data Log 1":250' Operations Summary Report Well Completion or Recompletion Report Well Test Results = Short & Long String Diskette: Surveys Diskette: Scan Data NF. ASC and SUN. AS Logs: Array Induction 2" MD Array Induction 5'' = 100' MD Comp. Neutron Litho - Density W/GR Digital Sonic Tool - Long Array Dipole Sonic Relabelled Delta 'Ps Formation Evaluation 2" TVD Drilling Data Log 2" MD Formation Evaluation 2" MD MWD Integrated Formation Evaluation 2" TVD MWD Integrated Formation Evaluation 2" MD Blueline Logs: G/R Collar Log Perf. Record 6-Feb-1998 G/R Collar Log Perf. Record 23-Jan-1998 Mechanical Sidewall Coring Tool Completion Repons SCANNED SEP ! 2002 Folder B-3ST: .F,,older B-3 BP1: rations Summary Report ermit to Drill; Sundry Approvals Blueline Logs: Film: Sepias: Vellums: Platform Express Three-Detector Litho-Density Comp. Neutron/GR Caliper/GR MWD Integrated Formation Evaluation 2.' TVD MW Integrated Formation Evaluation 2# MD Formation Evaluation 2.' MD Formation Evaluation 2.' TVD Drilling Data 2'' MD Caliper Log/GR Formation Evaluation 2'' TVD ' Drilling Data Log 2" MD MWI) 2'' TVD Formation Evaluation 2'' MD Pressure Data MWD 2°' MD Formation Evaluation 2" MD Pressure Data Log MW2) 2" TVD Formation Evaluation 2" TVD Drilling Data Log 2" MD MWD 2'' MD Blue Line Logs: Diskette: 4MM Tape: Film: Vellums: Blueline Logs: Sepias: Direction Survey 0-17864' Formation Evaluation 2.' TVD Formation Evaluation 2.' MD MWD 2' TVD Pressure Data Log 8918' TVD-12332' TVD Pressure Dta Log 9134' TVD-13368' TVD Drilling Data Log 2.' MD Impulse TVD Impulse MD ADN4 MD ADN4 TVD Resistivity TVD 1:600 & 1:240 ResistiviD, MD 1:600 & 1:240 B3-STI.LAS and Survey. TXT-Dir. Survey MD & TVD LAS Files (f'mal data) Survey Files Resistivity 1:600 & 1:240 MD ADN4 MD Resistivity 1:600 & 1:240 TVD Formation Evaluation 2' MD Formation Evaluation 2.' TVD Drilling Data 2" MD MWD Integ. Formation Evaluation 2" MD MWD Integ. Formation Evaluation 2" TVD Pressure Data Log Formation Evaluation 2' TVD MWD 2' TVD Pressure Data Log Formation Evaluation 2" MD Drilling Data 2" MD MWD2' MD Pressure Data Log Drilling Data Log 2.' MD Formation Evaluation 2" TVD MWD 2" TVD Formation Evaluation 2'~J~D SEP 1 2 2002 99-021.doc ! (i _TYONKK DEEP WELL t/ ~_f2/3/99) General: Folder B- 1: Core Sample Report (B-l, B-1ST, B-2, B-3, B-3BP1, B-3ST) Geologic Tops (B-l, B-1ST, B-2, B-3) /Operations Summary Report Well Completion/Re-completion Report and Log Schlumberger LIS Tape Verification Listing Blueline Logs: Fluid Comp. Cement Bond Phasor Induction w/GRe' _'_~_ -'~- Repeat Formation Tester- 32 Pressure Stations ~ ~ ~.~'~" Comp. Neutron Litho-Density & Microlog w/GR/Calipers Comp. Neutron Litho-Density (TVD).~ Comp. Neutron Litho-Density (MD)." CDR (TVO) ~ CDR (MD) ~' Repeat Formation Tester 14-Oct- 1997 Army Induction (TVD) .. , Array Induction (MD) Dipole Shear Sonic (MD)., Dipole Shear Sonic (TVD)." Gamma Ray CCL., v <-- Vormation .val.ation 2" MD.- Drilling Data Log 2" MD MWD 2" TVD MWD 2" MD., Folder B- 1 ST: Folder B-2: Folder B-3: Diskette: Logs: Operations Summary Report Well Completion Report Directional Survey Penuit to Drill Scan Well Test (Prod. Test #1) Logs: CDR (TVD) j Comp. Neutron Litho-Density w/GR" (TVO) and (ivy), Pressure Data Log Film: ADNR (TVD) .-" Vellum: Pressure Data LOg 1":250' Sepia: Pressure Data Log 1":250'-~ Operations Summary Report Well Completion or Recompletion Report Well Test Results = Short & Long String Diskette: Surveys Scan Data NF. ASC and SUN.AS Array Induction 2" MD Array Induction $" = 100' MD '~ Comp. Neutron Limbo - Density W/GR '~ Digital Sonic Tool - Long Array / Dipole Sonic Relabelled Delta 'Is ,' Formation Evaluation 2" TVD Drilling Data Log 2" MD .,~ Formation Evaluation 2" MD ~' MWD Integrated Formation Evaluation 2" TVD MWD Integrated Formation Evaluation 2" MD Blueline Logs: G/R Collar Log Perf. Record 6-Feb-1998 G/R Collar Log Perf. Record 23-Jan-1998 .,' Mechanical Sidemfll Cofine_Taol ~t;AN~-S~p 1 ~ 200~. Completion Reports 99-021.doc , Folder B-3ST: Folder B-3 BP1: ?erations Summary Report ,~rmit to Drill; Sundry Approvals Blueline Logs: Film: Sepias: Vellums: Platform Express Three-Detector Litho-Density Comp. Neutron/GR Caliper/OR MWD Integrated Formation Evaluation 2' TVD MWD Integrated Formation Evaluation 2' MD Formation Evaluation 2* MD Formation Evaluation 2' TVD Drilling Data 2" MD Caliper Log/OR Formation Evaluation 2" TVD Drilling Data Log 2" MD MWD 2" TVD Formation Evaluation 2" MD Pressure Data MWD 2" MD Formation Evaluation 2" MD Pressure Data Log MWD 2" TVD % Formation Evaluation 2" TVD Drilling Data Log 2" MD MWD 2" MD Blue Line Logs: Diskette: 4MM Tape: Film: Vellums: Blueline Logs: Sepias: Direction Survey 0-1786# Formation Evaluation 2" TVD Formation Evaluation 2" MD MWD2" MD MWD 2" TVD Pressure Data Log 8918' TVD-12332' TVD Pressure Dta Log 9134' TVD-1336g' TVD Drilling Data Log 2" MD Impuls~ TVD Impals~ MD ADN4 MD ADN4 TVD Resistivity TVD ]:600 & ]:240 Resistivity MD ]:600 & ]:240 B3-STI.LAS and Survey. TXT-Dir. Survey MD & TVD LAS Files (final data) Survey Files Resistivity 1:600 & 1:240 MD ADN4 MD ~' Resistivity 1:600 & 1:240 TVD Formation Evaluation 2" MD Formation Evaluation 2" TVD~" Drilling Data 2. MD .,' MWD Integ. Formation Evaluation 2" MD MWD Integ. Formation Evaluation 2" TVD Pressure Data Log .. Formation Evaluation 2" TVD MWD 2" TVD Pressm-e Data LOg Formation Evaluation 2" MD MWD2" MD Drilling Data 2" MD ~' MWD2"MD Pressure Data Log Drilling Data Log 2" MD ' Formation Evaluation 2" ~wo 2" tvo ~GANNED SEP 1 ~ 2002 Formation Evaluation 2" MD 99-021.doc , PERMIT 9 7-115 PHILLIPS Log Data Sent Reeieved 7864 ~ SCHLUM AIT/DSI/DITE/LDT/CNT/ML 12/5/1997 11/21/1997 AIT-MD L LGR.(C) 10200-15590 10/31/1997 11/3/1997 AIT-TVD L LGR(C) 8600-12870 10/31/1997 11/3/1997 CDR.-MD L LGR. 2575-15463 12/16/1997 12/18/1997 CDR-TVD L LGR. 2500-12853 12/16/1997 12/18/1997 CN/LDT-MD L LGR.(C) 10375-15500 10/31/1997 11/3/1997 CN/LDT-TVD L LGR.(C) 8710-12870 10/31/1997 11/3/1997 CN/LDT/MIRCO L 3700-9984 2/3/1999 2/9/1999 COR.E ANALYSIS R CORELAB 14298.10-I 5034.50 2/22/1999 2/22/1999 DDL-MD L BL 2646-155000 11/13/1997 11/13/1997 DIR SRVY R SCHLUM 0-15498 12/16/1997 12/18/1997 DSS-MD L LGR.(C) 10375-15445.80 10/31/1997 11/3/1997 DSS-TVD L LGR.(C) 8850-12825 10/31/1997 11/3/1997 FLUID COMP CBL L 1500-3760 9/6/1997 9/6/1997 GR/CCL PERF L 3400-3650 2/3/1999 2/9/I 999 MWD-FET-MD L LGR(C) 2646-15500 11/13/1997 11/13/1997 MWD-FET-TVD L BL 2565-12880 11/13/1997 11/13/1997 PIL/GR. L 3700-9984 2/3/1.999 2/9/1999 REC. CDR.-TVD L BL 2400-12400 2/3/1999 2/9/1999 RFT L LGR(C) 14313-14498 10/31/1997 11/3/1997 RFT-32 PR.ES STA L 4225-6284 2/3/1999 2/9/1999 Box Friday, October 08, 1999 Page 1 of 2 10=407 Completion Date .................. Daily well ops ...................................... Are dry ditch samples required? i ". ii.' yes i. '...no And received? -.. yes ..... no ............... Was the well cored? ........ yes ......... no Analysis description recieved? ........ yes ....... no Are tests required? i.'~.....'...i yes i'-'... ~ no Received? ...... yes . no Well is in compliance ................................. Initial Comments Friday, October 08, 1999 Page 2 of 2 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION November 25, 1998 N P Omsbcrg North American Drilling Manager Phillips Petroleum Company 6330 W. Loop South Bellaire, TX 77401 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dear Mr. Omsberg: The Alaska Oil and Gas Conservation Commission ("Commission") learned that you only recently ceased annular disposal operations in the North Cook Inlet Unit CNCIU") B-1 w_ell. The Commission issued an aquifer exemption order and a disposal injection order for the A-12 well on September 29, 1998 to facilitate injection of the oil-based muds, cuttings and produced waters from ongoing and future operations. Disposal operations in the B-1 well should have ceased once disposal in A-12 was approved. Annular disposal is not a long term disposal option and is limited to a disposal volume of 35,000 barrels. Those limitations may only be exceeded with specific approval of the Commission after written application to the Commission under 20 AAC 25.080(d). Phillips' subsequent Permit to Drill approvals for wells NCIU B1ST, NCIU B-2 and NCIU B-3 were not authorization to exceed the 35,000 barrel limitation in the B-1 well. Your staff may be confused with the differences between annular disposal and injection under th,: Underground Injection Control ("UIC") program. Under the uIC program, volumetric limitations are not normally imposed because of the more rigid well construction and monitoring requirements Among these requirements are the need for tubing and packer under 20 AAC 25.412(d), a cement bond log and pressure test under 20 AAC 25.030 and site specific operating, monitoring and reporting conditions under 20 AAC 25.252. The above considerations are clearly not in place in the B-1 well. Please note that some of the wastes authorized for annular disposal max; not be acceptable for UIC disposal. Please feel free to contact our office with any questions. Chairman PERMIT DATA 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 97-115 AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 11/25/98 T DATA PLUS .......................................... RUN RECVD FLUID COMP CBL L ~ 1500-3760 , i 09/06/97 AIT-~'~ L ~_3C~8600-1~870,~ i 11/0~/97 AIT-~ L~U~¢C)10=00-15590 ~ i 11/0~/97 · CN/LDT-TVD L .... C) 8710-12870 ~ ! i 11/03/97 CN/LDT-MD L ~Cl 10375-15500.~, ~ ~/0~/~ oss-~ ~ ~(c~ ~0-~ -~ , ~ ~/o~/~ 7864 T~.CHLUM AIT/DST/DITE/LDT/CNT/ML 1,2W"~/21/97 · DmR S~vY ~/~C~L~ 0-15~98 ~,',i)~ ~/~8/~7 DAILY WELL OPS R / / / TO / / / / / / Are dry ditch samples required? ~no ~d received? yes no Was the well cored? ~.no ~alysis &~~received? yes no ~e well tests required? %~s ~ Received? ~. I~lk73, OS~lfl,~- , PHILLIPS PETROLEUM CO Page 1 of 29 c't Oil & Gas Cons. Commissl.Qn Anchorage Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000001 - Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: . Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase code Description of Operations · 06/06/97 12:00 - 06:00 18.00 MV t 00MMIR Rig 428 released by Unocal to PPCO. Accepted dg @ 1200 hrs. 6/5/97. Boat Agreement still did not show up. being tracked down. First load out scheduled 0600 hrs 6/6/97. SeCorp Medic sent to Tyonek Platform to begin orientation and duties. Unocal completed inspection of turbine. Unit to be partially dismantled due to weight. Unocal to have Solar Turbine rep install mother board in control panel. 06/07/97 06:00 - 06:00 24.00 MY t 00MMIR Pool continuing to Demob dg. SCR house sent to Anchorage for modifications for cuttings grinding adaptation. First boat arrived @ 1000 hrs with rig down equipment. Boat contract started 0600 hrs 6/06/97 06/08/97 06:00 - 06:00 24.00 MY t 00MMIR Continue dgging down and demob from Unocal platform. 06/09/97 06:00 - 06:00 24.00 MV t 00MMIR Continue dgging down and demob from Unocal Platform. First boatload to dock 0600 hrs 6/8. Utilizing an additional crane operator on Demob for more efficient load out of boats. One constantly running from one crane to the other. 06/10/97 06:00 - 06:00 24.00 MV t 00MMIR Continue rigging down and demob from Unocal Platform. Second boatlo~U to dock 0800 hrs 6/9. 10 boxes of radio equipment ardved. Material for pin rail extensions to arrive today. Platform stiffening project completed. 06/11/97 06:00 - 06:00 24.00 MV t 00MMIR Continue rigging down and demob from Unocal Platform. Lowering and rigging down the derdck. Increased work'force to assist in dgging down. Billy Hayes and radio pemon.nel installing radio and communications equipment on both workboats. 06/12/97 06:00 - 06:(J0 24.00 MY t 00MMIR Continue rigging down and demob from Unocal Platform. .~. 06/13/97 06:00 - 06:00 24.00 MV t 00MMIR Continue dgging down and demob from Unocal Platform. 6 man Pool crew ~arrived with Gary Smith. MN Monamh arrived with 1st load of crane beams. Unloaded Same. !06/14/97 06:00 - 06:00 24.00 MV t 00MMIR Continue rigging down and demob from Unocal ~latform. Rigging up Baker Marine Crane. Unload boat. 06/15/97 06:00 - 06:00 24.00 MV t 00MMIR Continue rigging down and demob from Unocal Platform. Continue dgging up Baker Marine Crane. Eight more Pool personnel arrived at 1.5:00 hrs. 06/16/97 06:00 - 06:00 24.00 MV t 00MMIR Continue rigging up Baker Madne Crane. APC crews dgging up scaffolding for pinrail extensions. Test run crane. Boat arrived at 20:00 hrs with first load of substructure. Clear deck for skidding crane. 06/17/97 06:00 - 06:00 24.00 MY t .00MMIR ~=inish skidding lower section of BMC. Clamped down and secured same. APC continue to RU skid beam extensions. Unable to use Manitowoc crane due to cable winding. Order new Diaform 18-HSLR non rotating . cable. Fabricate clamps to skid upper portion of BM Crane. Have crane inspected by Crane and Lift Inspections, Inc.. 06/18/97 !06:00 - 06i00 24.00 MV t 00MMIR Unload substructure from. MN Champion. Continue rig up of substructure. Rig now two levels high. 1st = Substructure. 2nd = Trip Tank and Water Tank. Next comes the rig floor. ,... 06/19/97 06:00 - 06:00 24.00 MV t 00MMIR Unload dg floor sections from work boat. RU sup.,.port beams, then rig floor. Two pin rail extensions installed. Moved transformers from area where quarters deck cantilever beams will be. installed. All "black iron" substructure base beams up. All doors hung, BOP trolley installed. 06/20/97 06:00 - 06:00 24.00 MV ~t 00MMIR Rig up floor. Standpipe and Koomey Unit installed. Offioad drawworks and other dg floor equipment to platform and rig up same. Three pin rail extensions finished. Working on new communications tower placement beam. Base oil pump stand done, cement room all cleaned out. 06/21/97 06:00 - 06:00 24.00 MY t 00MMIR Finish installing drawworks, installing wind wall panels. Rigging down the utility module on Unocal platform. 06/22/97 06:00 - 06:00 24.00 MV t 00MMIR Attached traction motors to drawworks, hooked up electdc brakes. Set ' choke manifold / gas buster mezzanine in place over drawworks. Set Nask Printed: 16/27/98 3:01 :.54 PM KI-LI- I v L) l, )V 2 ]998 - PHILLIPS PETROLEUM CO Page 2 of 29 I~ Gas Cons. Commission Anchora Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 06/22/97 06:00 - 06:00 24.00 MV t 00MMIR starting legs of derrick in place and bolted down same. Set ODS dog house. Unit crane pedestal ready for removal. 06/23/97 06:00 - 06:00 24.00 MV t 00MMIR Tighten derrick bolts, pulled electrical cables. Hooked up chain on drawworks. Installed wind walls and roof caps. Offioad workoboat and set up welding shop. Modify stairs to rig floor. Crown section of derrick being examined by DRECO for repairs. Baker crane and auxiliary generator hours, and fuel consumption being tracked. 06/24/97 06:00 - 06:00 24.00 MV t 00MMIR Derrick dolley is up and waiting on crown section. Windwalls installed. Continue to pull wiring hamess. Modify stairs and RU rig floor. · . One crew on Unocal Baker Platform continuing to rig down p(~wer module. 06/25/97 06:00 - 06:00 24.00 MV t 00MMIR Continue working on stairway / handrail modifications. Offload Baker Crane =ieces. String new line on Manitowoc crane. Connect steam and water to rig floor and survey deck. Connect driller's console / drawworks with air, electrical, and hydraulic lines. Continue to rig down and offload power / utility module from Baker Platform. 06/26/97 06:00 - 06:00 24.00 MV t 00MMIR Continue working stairway / handrail modifications. Install Dril.locks on skid rams. Re-arrange equipment on all decks to facilitate rig up of Baker Crane No. 2 and utility / power module. Connection lines in substructure and rig floor. Offioad trusses for Baker Crane. Continue to rig down and offload pwer / utility module from Baker Platform '06/27/97 06:00 - 06:00 24.00 MV t 00MMIR Continue working welding projects. Offioad workobat. Set crane uprights and brace same. Offload 2nd workboat with remainder of crane pieces. Set and pin spreaders for crane. Halliburton cement unit ready for shipping. 06/28/97 06:00 - 06:00 24.00 MV t 00MMIR Continue working on welding projects. Baker crane installed. Set and bolt top crane supports, strongbacks, walkways, and crane pedestal. Install and torque all bolts. Continue to rig down and offload power / utility module from Unocal Baker platform. Sent in two more boatloads. 06,~.9/97 06:00 - 06:00 24.00 MV 6 00MMIR Continue working on welding projects. Tie substructure to platform power. Complete torqueing 3" bolts on crane structure. Install handrails and stairs. Set king post, crane cab, and gant~ for No. 2 Baker crane. Bolt boom sections together. Install boom camera, connect cables, hoses between sections & inspect boom. Set and pin boom. Stringing up at report time. !Boat loaded with derrick sections enroute to platform. Work completed and last piece of rig equipment shipped from Baker =lafform. All work completed on Baker. Unaware of any problems. 06/30/97 06:00 - 06:00 24.00 MV 6 00MMIR Finish RU Baker Crane No. 2. Check all fluid levels & re-inspect crane. Offioad / load workboat. Set derrrick crown section & crown, raise same. Set and raise u~3per intermediate d~rrick section. Set middle section & prep for raising. Continue welding projects. Working on loading stations at each end of platform for barite, cement, water, & diesel. Prepare to rig down Unit crane at report time. Boat will offioad at OSK dock at 1100 hrs this AM. Printed: 10/27/98 3:01:54 PM N 3v 2 3 998 PHILLIPS PETROLEUM CO Page 3 of 29 Operations Summary Report Naska 0il & ~as Cons. Commission Le~°~ Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations =, 07/01/97 06:00 - 06:00 24.00 MV 6 00MMIR Continue welding projects. Work on raising derrick. Install middle section & raise same. Install lower middle section & bolt up same. Rig down boom = on Unit crane. Skid Baker crane #2 on pipe rack to offload boat. Offload Halliburton cement unit, 550 cu/ft bulk tank, 60 cu/ft tear drop tank. All this ;equipment set on decks in preparation to set in pump room for installation. . Offloading Unit crane to boat as dismantling. Present operation taking "A frame off Unit cra, ne & also puffing extra boom section in Baker crane #1 to handle installing board on derrick. 07/02/97 06:00 - 06:00 24.00 MV 6 00MMIR 24 hrs Tyonek. Continue welding projects. Finsish installing boom section on #1 Baker crane for 100' boom. Raise derrick 15' install derrick board & one windwall. Loadout boom section on workboat. Rig down Unit crane cab & set on workboat. Cut off Unit crane pedestal, laydown on production deck with two cranes. Offload to workboat. Unit crane complete on workboat for shipment to Osk dock. Workboat offloaded 0300 hrs & backloaded w/traveling blocks-hook & 1st Ioad'of utility module. Installed bottom section 'of derrick & raised same. 07/03/97 06:00 - 06:00 24.00 MV 6 00MMIR Continue welding projects. Install Halliburton pump skid,bulk tank, & tear .drop tank in platform pump room. Unstring Lantec winch used to raise !derrick. Inspect derrick. Ru derrick ladder. Rig down dolley system used to rig up derrick sections. Removed 20' boom section from Baker #1 crane to handle heavy loads of power module. Skidding #2 Baker crane in postion !to offioad workboat. Clearing deck to offload power module pieces. 07/04/97 06:00 - 06:00 24.00 MY 6 00MMIR Continue welding projects. Order piping & fittings to hookup Halliburton equipment. Finish skidding Baker crane in position. Install boom poles in derrick & hang windwalls around derrick board. Install floor windwalls Continue clear deck to offload boat. Set traveling blocks & hook on rig floor. Set power module skid beams - 2 for support complex. Set in center pump deck, deck with work bench, & mud pump deck. Backload boat & send to dock. 07/05/97 06:00 - 06:00 24.00 MV 6 00MMIR Continue welding projects. Hookup suction lines in pump room of rig, hook up utility lines under power module. Set floor for mud pits, tighten bolts. Set both mud pumps & mud pits. Backload workboat & send to dock. Set traction motors for mud pumps & bolt down same. Workboat at dock . @0300 hrs for next load. 07/06/97 06:00 - 06:00 24.00 MV 6 00MMIR TIGHTEN BOLTS ON HEAT EXCHANGER AND RU DUCK WORK TO SAME. SET SCR HOUSE AND AIR COND. UNIT. HOOK UP CENTRIFICAL PUMPS AND LINES. WORK BOAT HOOK UP LIN ES IN PIT ROOM. WORK BOAT.SET MCC BLDG. 07/07/97 06:00 - 06:00 24.00 MV 6 00MMIR RU HEAT EXCHANGER AND UDCK WORK TO SAME. HOOK UP DISCHARGE ENE ON CENTRIFICAL PUMPS. SET SCR HOUSE. SET A/C UNIT. HOOK LINES TO MUD PITS. INSTALL DRIP PAN ON CRANE. CONTINUE WELDING PROJECTS. OFF LOAD BOAT THIS AM. Printed: 10/27/98 3:01:54 PM ... RECEIVED (' 10v 2 3 3998 PHILLIPS PETROLEUM CO Page 4 of 29 }il & ~as Cons. Commission Operations Summary Report Anchoraqa Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date J From - To Hours Sub Co Phase Code Description of Operations 07/08/97 06:00 - 08:00 24.00 MV 6 00MMIR FINISH OFF LOAD BOAT. SET CAT 399 IN PLACE. SET BOILERS, TURBINE, AND RADIATOR BUILDING IN PLACE AND BEGIN HOOK UP. HOOK UP FLOW TO SHALE SHAKERS, HOOKUP UTILITY LINES IN MOTOR COMPLEX AND CLEAN WORK AREA, BEGIN UP LIGHTS. BEGIN WORK IN PIT AND PUMP ROOM. SKID CRANE AND BEGIN HOOK UP OF PORCH ON RADIATOR BUILDING. 07/09/97 06:00 - 06:00 24,00 MV 6 00MMIR SET STRONG BACKS AND SET EXHAUST IN PLACE ON #1 BOILER. INSTALL WIND WALLS AROUND BOILER AND MOTORS. RIG UP MUD DOCK. HOOK UP GAS LINE TO SOUTH SIDE OF MOTOR COMPLEX. !SET WlNDWALLS AROUND MOTOR COMPLEX. SET AND WORK ON TURBINE GENERATOR. BEGIN HOOK UP OF EXHAUSTS ON CAT 399'S, HOOK UP GEN ON SAME.PULL WIRES AND WORK IN PUMP ROOM ON SUCTION LINE HOOK UP. SET WALK WAY AT MOTOR ROOM. 07/10/97 06:00 - 06:00 24.00 MV 6 00MMIR REMOVE EXHAUST STACKS FROM MECHANIC SHOP AND SET SHOP IN PLACE, RU STA IRS FRAME SURVEY DECK TO DRK. SET GRASSHOPER WiRE TRAY INPLACE, PULL ELECTRICAL WIRES IN MOTOR COMPLEX. RAISE CABLE TRAY UP BACK OF DERRICK. INSTALL EI'ECTRICAL AND HYDRALIC SERVICE LOOPS. RU STAND PIPE, KELLY HOSE AND TBG BOARD. WORK IN MOTOR ROOM. 07/11/97 06:00 - 08:00 24.00 MV 6 00MMIR RU DOLLY ON BLOCKS, RU RBS IN DRK. SET TURBINE AIR INTAKES IN PLACE. HOOK TURBINE AIR EXHAUST TO HEAT EXCHANGER. RU STAIRS AND LNDG ON NORTH SIDE OF MOTOR COMPLEX. RU LNDG ON SOUTH SIDE OF MOTOR COMPLEX. SET 3 PIPE RACKS IN 'PLACE, BOLT DWN SAME. WORK BOAT, HANG STAIRS PUT CROWN LIGHT ON, WORK ON TURBINE GENERATOR. WORK ON MUD END OF PUMP #2. 07/12/97 06:00 - 06:00 24.00 MV 6 00MMIR SKID BMC #9 TO MIDDLE OF SUPPORT BEAMs. SKID CRANE STRUCTURE AND TIGHTEN CLAMPS SKID CRANE TO OPERATING POSITION AND TIGHTEN BOTLS. SKID RIG FLOOR OVER WELL AND ;SECURE SAME. PULL ELECTRICAL CABLES. WORK ON TURBINE ;EXHAUST. CONTINUE WELDING AND ELECTRICAL PROJECTS. 07/13/97 08:00 - 06:00 24.00 MV 8 00MMIR 'PULL WIRE TO UTILITY MODULE, INSATLL UPPER SUB BASE CLAMPS. PLUMB DIESEL LINE FROM PRODUCTION TO UTILITY MODULE. INSTALL ACTUATOR ON DIVERTER LINE KNIFE VALVE. HOOK UP PLUMBING TO MOTOR ROOM. RU TRIP TANK VALVES. PLUMB AIR LINES TO 399;S, PULLED DC WIRES TO DRWKS. TEST DRWKS MOTORS. STRUNG DRLG LINE. WORK ON TURBINE EXHAUST. 07/14/97 - 06:(X) - 06:00 24.00 MV 6 00MMIR INSTALL MUD LINE, PUMP AND CEMENT MANIFOLD. HOOK UP BLEED OFF MANIFOLD, INSTALL SMT HOSE AND STANDPIPE HOSE, PICK UP HOOK. MOVE STAIRS TO RIG FLOOR. HOOK UP GAS BUSTER VENT LINE UP DERRICK LEG. PU SWIVEL AND SI=LINE .SHAFT. PICK UP TOP DRIVE AND MAKE UP SAME. WORK BO/~T. 07/15/97 06:00 - 06:00 24.00 MV 6 00MMIR SKID CRANE AND PEDESTAL. INSTALL FLOWLINE TO GAS BUSTER. INSTALL COUNTERBALANCE CYLINERS AND BLOWER DUCTS ON TOP DRIVE. OFF LOAD CAMP SUPORTS FROM WORK BOAT. RU LINK TILT ON TOP DRIVE. INSTALL IBOP IN TOP DRIVE. SET CAMP Printed: 10/27/98 3:01:54 PM [~,, 0V 2 ~ 19~8 PHILLIPS PETROLEUM CO Page 5 of 29 ti& Gas Cons. 6oitlmlssi0n Operations Summary Report ~n~,hnrRrJ_,~ Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 0.7/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date I'Fr°m' To Hours Sub Co Phase Code Description of Operations 07/15/97 06:00 - 06:00 24.00 MV 6 00MMIR SUPPORTS, 07/16/97 06:00 - 06:00 24.00 MV 6 00MMIR INSTALL KILL LINE, CMT LINE AND CHOKE LINE IN SUBBASE. HANG STABBING BOARD. INSTALL HEATERS AND LIGHTS ON i:{IG FLOOR. INSTALL IRON ROUGHTNECK PREPARE TO HOOK UP HYDRAULICS TO SAME, HELP SET CAMP STRUCTURE IN PLACE. RU RIG STRUCTURE FOR CAMP PREPARE SET SAME, 07/17/97 !06:00 - 06:00 24.00 MV 6 00MMIR ,HOOK UP HYDRAULIC TO IRON ROUGHNECK, WORK ON PLATFORM PITS AND HALLIBURTON UNIT. HOOK UP DRAIN SYS ON OUTSIDE OF UTILITY MODULE. HANG WlNDWALL ON HYDAULIC HOUSE. INSTALL LIGHTS ON OUTSIDE OF RIG, INSTALL SCAFFOLDING SUPPORT IN BOP ROOM. HOOK UP MUD LINE IN CELLAR. PULL WIRE FROM CHARGE PUMPS TO CONTROL PANEL. INSTALL PIPE HANDLER ON TOP DRIVE, HOOK UP HYDRAULIC LINES IN DERRICK. WORK ON MUD PUMPS INSTALL LINERS AND SWABS. SET APOLLO CUTTINGS GRINDER IN PLACE, 07/18/97 06:00 - 06:00 24.00 MV 6 00MMIR HOOK UP LIGHTS ,ON PIPE RACK. WORK ON PUMPS, INSTALL FLOWLINE, MAKE MODIFICATION FOR UTILITY MODULE. WELDERS WORKING TO RIG UP APOLLO CUTTINGS GRINDER. PUT POOL GRAY IRON ON PLATFORM CAMP STRUCTURE, BOLT DOWN SAME, SET WALK ALONG ONE EDGE OF CAMP, WORK BOAT. 07/19/97 06:00 - 06:00 24.00 MV ~6 00MMIR SET MAI=rING BOARDS FOR CAMP. INSTALL EXHAUST EXTENTIONS FOR CATS. INSTALL FLOWLINE SUPPORTS. INSTALL VIBRATING ~HOSE ON MUD LINE. SET CAMP UNITS, BEGIN HOOK UP UTILITIES TO SAME. INSTALL PVT PROBES IN PITS. HOOK UP UTILITY HOSES FROM PLATFORM TO UTILITY MODULE, FINISH INSPECT TOP DRIVE, 07/20/97 06:00 - 06:00 24.00 MV 6 00MMIR INSTALL WlNDWALL ON HYDRAULIC MODULE. SET UP LIGHTS ON UTILITY MODULE PIPE RACK, WORK ON HYDRAULIC SYS OI~ IRON ROUGHNECK. INSTALL BOILER EXHAUST. INSTALL FLUID END ON PUMP #1. SET UP EXTERIOR LIGHTS ON CAMP. FINISH HOOK UP UTILITY MODULE WATER LINES AND FILL WATER TANK. CHECK AND FILL KOOMEY BOTTLES W! NITROGEN. PULL MIDDLE FLUID END OFF PUMP #2, PREPARE TO REPLACE SAME, UNLOAD BOAT. CONTINUE RU UTILITIES TO CAMP AND FINISH INTERIOR TO SAME. 07/21/97 06:00 - 06:00 24.00 MV i6 00MMIR ,SKID CRANE AND CRANE BASE. INSTALL BELT GUARDS ON MUD PUMPS, ASSIST IN RU OF APOLLO CUTTINGS UNIT. WORK BOAT. CLEAN OUT DEGASSER, SET LOWER BEAM IN CRANE PEBESTAL, CLEAN DECKS ON PIPE RACK, SET CONEX'S ON PIPE RACKS, FILL KOOMEY UNIT. SET ONE PIPE PANEL ON CRANE STRONG BACKS. HANG LIGHTS UNDER CRANE. CONTINUE HOOK UP UTILITIES TO CAMP, 07/22/97 06:00 - 06:00 24,00 MV 6 00MMIR INSTALL FLUID END ON PUMP #2. REMOVE SAME. TAP OUT BOLT HOLE INSTALL SAME OK. TEST KOOMEY AND REMOTE STATIONS, OK, HOOK UP KOOMEY HOSES, FIX OIL LEAK ON TURBINE. INSTALL BRACES ON CAT EXHAUSTS, INSTALL GUARDS ON DRWKS. TEST WATER PUMP, OK, UNLOAD CONEX BLDGS. HANG KELLY HOSE 'CLAMPS IN DERRRICK, CHANGE OUT SAVER SUB. OFF LOAD BOAT. BEGIN SET PIPE PANELS ON CRANE PEDESTAL. BEGIN MANIFOLDING CEMENT TANKS TOGETHER AND TEST RUN HALLIBURTON UNIT, ONE AIR VALVE AND ONE HYDRAULIC VALVE INOPERABLE, WILL REPLACE. FAB UP AUGER DISCHARGE TO OVER BOARD LINE, CONTINUE WITH VARIOUS WELDING PROJECTS. ELECTRICAL POWER INSTALLED IN CAMP, SEWER ~a~kaOi Printed: 10/27/98 3:01:54 PM RE CEIVED 2 1998. PHILLIPS PETROLEUM CO Page 6 of 29 & Gas Cons. C0,mmissior~ Operations Summary Report Anch0rags Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date I From - To Hours Sub Co Phase Code Description of Operations i 107/22/97 106:00 - 06:00 24.00 MY 6 00MMIR DRAIN IN PLACE. HOOKING UP POT WATER AND SRINKLER WATER. 07/23/97 06:00 - 06:00 24.00 MV 6 00MMIR INSTALL PANELS ON CRANE STRONGBACK. CLAMP DOWN & INSTALL HANDRAILS. WORK ON MUD PUMP, TOP DRIVE COUNTER BALANCE SYSTEM, BULK BAR SYSTEM. ASSIST APOLLO RIG UP EQUIPMENT. HOOK UP BLOWER HOSES ON SKID UNDER TURBINE. INSTALL HANDRAILS ON BACKSIDE OF TURBINE, RU DERRICK CLIMBER. MAKEUP & INSTALL SERVICE HOSES IN SUB. CONTINUE HOOKUP SERVICE & UTILITY LINES. 06:00 - 00MMIR 07/24/97 06:00 - 06:00 24.00 MV 6 ' 00MMIR INSTALL HANDRAILS ON BMC CRANE PIPE RACK. CLEAN OUT ROD OILER TANK #1 MUD PUMP. HOOK UP BLOWER MOTOR HOSES, INSTALL SAFETY BOLTS ON SOUTH SIDE UTILITY MODULE STAIRWELLS, WORK ON IRON ROUGHNECK. CLEAN UP IN MUD PITS & INSTALL GRATING. DRESSING SHALE SHAKERS. STRING GEOLOGRAPH. INSTALL PIT WALL & MAKE PENETRATIONS FOR LINES. HOOKUP 4' HIGH PRESSURE LINE FROM RIG TO UTILITY MODULE. CHECK OUT #1 & #2 CHARGE PUMPS, MUD CLEANER, DESANDER,MUD GUNS,ETC. UNLOAD WORKBOAT, DIRECTIONAL EQUIPMENT, 160 JTS 5' DP, DCS, HANDLING TOOLS. 07/25/97 06:00 - 06:00 24.00 MV 6 00MMIR PULL WIRE FOR MAIN AUGER, TEST SAME. TRIAL RUN AGITATORS & SHALE SHAKERS. HOOK UP AUTOMATIC GREASE SYSTEM ON AUGER & TEST SAME. INSPECT DUMP LINES ON PITS & UNPLUG OVERBOARD DRAINS IN PITS. CIRCULATE WITH CENTRIFUGAL PUMPS THRU EQUIPMENT & LINES, REPAIR LEAKS. SET ALT-2 WELDHEAD IN WELLROOM. CUTOFF COVER PLATE & DRESS CONDUCTOR PIPE. REBEVEL ALT-2 & PREPARE TO WELD ON SAME. START RIG UP BARITE TANKS, OFFLOAD LOGGING UNIT & MWD BUILDINGS. HOOKUP SENSORS ON MUD MANIFOLD & TEST SAME. . HOOKUP DRAIN SYSTEMS ON BMC CRANE PIPE RACK & IN MOTOR 'ROOM.I 07/26/97 06:00 - 06:00 24.00 MV 6 00MMIR COMPLETE WELDING ON ALT-2 WELLHEAD. CONTINUE HOOKUP CEMENT & BULK BARITE LOADING LINES & MANIFOLDS. WORKING ON MUD PITS. INSTALL SERVICE LINES BETWEEN RIG & UTILITY MODULE. INSTALL AIR EXHAUST DUCT UNDER PIPE RACK FOR ". PLATFORM PITS. FINISH HANGING HOSES FOR NORTH PLATFORM LOADING STATION. CHANGE BRUSHES ON DRAWWORKS TRACTION MOTORS. CLEANING OUT PRODUCTION MUD PITS & WORKING ON · . OVERBOARD DUMP LINES. CIRCULATE BRAKE WATER COOLANT SYSTEM FOR LEAKS. NIPPLE UP 2 30" RISERS & PREPARE TO LOWER IN WELLROOM. Printed: 10/27/98 3:01:54 PM ~:'J 0',J" 2 3 1,9~q8 PHILLIPS PETROLEUM CO Page'7 of 29 ~i; & ~as Cons. Commission Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Ddlling Start: 06/05/97 End: Contractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 07/26/97 06:00- 06:00 24.00 MV 6 00MM!R 07/27/97 06:00 - 06:00 24.00 MV 6 00MUIR CONTINUE RIG UP 30' RISER, DIVERTER SPOOL, 16" KNIFE VALVE, 16' DIVERTER LINE, BELL NIPPLE. INSTALL TURN BUCKLES & A~IGN STACK. WORKING ON WELDING PROJECTS IN PLATFORM PITS. INSTALL MUD TRANSFER LINE FROM RIG MUD PITS TO PLATFORM MUD PITS. RU BARITE SUPPLY LINE TO BARITE TANKS ON PRODUCTION DECK. WORKBOAT OFFLOAD 1350 SXS BARITE. MIX & PRE HYDRATE 400 BBLS BENTONITE IN RIG MUD PITS. WORKING ON ACCUMULATOR LINES TO STACK. 07/28/97 06:00'- 06:00 24.00 MV 6 00MUIR REPAIR LEAKS IN KOOMEY LINE. FUNCTION TEST DIVERTER SYSTEM. FUNCTION TEST FLOW LINE VALVES & TRIP TANK VALVES. SET HALLIBURTON CEMENT AIR COMPRESSOR IN PUMP ROOM. CONTINUE WELDING PROJECTS FOR MUD TRANSFER & OVERBOARD DUMP LINES. CHECK.GAS, LEL, H2S MONITORS. PUT 20' BOOM SECTION IN BAKER CRANE. INSTALL LINE FROM BULK BAR TANKS TO RIG MuD PITS. FILL PRODUCTION PITS WITH WATER, PITS LEAKING. MAKING REPAIRS. PUMP 1000 SXS CEMENT FROM WORKBOAT. RIGGING UP SCHLUMBERGER MWD UNIT. SET MOUSEHOLE. ***CALLED BLAIR WONDZELL ALASKA OIL & GAS. 07/27/97 1200 HRS. NO ONE REQUIRED TO WITNESS DIVETER FUNCTION TEST· ***ETA SPUD WELL 0600 07/30/97. 07/29/97 06:00 - 06:00 24.00 MV 6 00MMIR CONTINUE RIGGING UP SCHLUMBERGER MWD UNIT. SPOT BAKER MUD LOGGING UNIT & RIGGING UP SAME. FINISH INSTALLING STORM CLAMPS ON RIG. PERFORM DERRICK INSPECTION. SERVICE TOP DRIVE. INSTALL QUICK RELEASE ON TOP DRIVE LINK TILT. RIG UP FLOW LINE TO TRIP TANK. RIG UP STAIRS TO CRANE PIPE RACK. FAB DRAINS IN MOTOR ROOM & AROUND TURBINE. MOVE MUD MATERIAL TO MUD ROOMS. OFFLOAD 1000 SXS CEMENT & 55 JTS ,20" CSG. CONTINUE WORKING ON PRODUCTION MUD PITS. HAVING TO MODIFY MUD HOPPER DISCHARGE LINE INSIDE PITS. CLEAR RIG FLOOR. , · 07/30/97 06:00 - 12:00 6.00 MV 6 00MMIR FINISH OFFLOAD 20" CSG FROM WORKBOAT. CONTINUE WELDING PROJECTS. WORKING ON PLATFORM MUD PITS. RIG UP HOSE TO JET FLOW LINE. 12:00 - 18:30 6.50 DR 2 00MMIR PU 153 JTS 5" DP & STD IN DERRICK 18:30 - 20:30 2.00 DR 6 00MMIR TURN KELLY HOSE ON TOP DRIVE & ADJUST SAME. ORIENTATE CAMERAS FOR TOP DRIVE. 20:30 - 03:30 7.00 DR 2 00MMIR PU 24" BIT, MWD, DCS, & HWDP TO CLEANOUT 30". TIH TAG @373' 03:30 - 04:00 0·50 DR 2 00MMIR CLEANOUT 373' - 405' END OF 30" CSG. OPEN HOLE. ' 04:00 - 06:00 2.00 DR I 05ClDR SPUD WELL 0400 HRS. 07/30/97. DRLG 405 - 467' @REPORT TIME. Alaska Printed: 10/27/98 3:01:54 PM RECE!!/ED(' I ! 0 V 2 3 '~9~8 PHILLIPS PETROLEUM CO Page 8 of. 29 ~aska Oi~ & raas '"" ~ ,;:,n,,. Commission Operations Summary Report ~ rtn~nr~,n~ I~ J __ Legal Well N~me: NORTH OOOK INLET UNI%B 000001 Oommon Well N~me: North Oook Inlet Unit B-1 Spud D~te: 07/81/97 Event N~me: Original Drilling 8t~rt: 08/0~/97 End: Oontractor N~me: Unocal/Pool Rig Rig Flele~se: 1012119? Group: Rig N~me: Rig Number: 4~8 ' Dato From - To Hours Sub Co Phaso Godo D~scription of O¢omtion$ 07/31/97 06:00 - 08:00 2.00 DR 1 10C2DR DRLG 487'- 530' 08:00 08:30 0,05 DR I 10C2DR SURVEY W/MWD TESTING TOOL, GETTING MAGNETIC INTERFERENCE 08:30 - 12:00 3,50 DR I 10C2DR POOH TO PU DRLG MOTOR. 12:00 - 16:00 4.00 DR I 10C2DR PU DRLG MOTOR, 2 DEG BENT SUB, 18.5" STABILIZER. MAKING UP TOOLS THREADS GALLED ON SUB & STABILIZER, ATTEMPT BREAK OUT BENT SUB FROM MOTOR, FAILED. LD MOTOR,SUB,STABILIZER. 16:00 - 20:00 4.00 DR 10C2DR TUBOSCOPE THREAD INSPECTOR ARRIVED RIG. CHECKED ALL CONNECTIONS ON EQUIPMENT TO BE RUN IN HOLE, NO DEFECTS OR PROBLEMS FOUND, 20:00 - 00:00 4,00 DR 2 10C2DR PU NEW MOTOR, 2.5 DEG BENT SUB, STABILIZER & MAKEUP SAME WITHOUT ANY PROBLEMS. RIH TO BTM WITH5' OF FILL AT 525', 08/01/97 00:00 - 01:30 1,50 DR I 10C2DR CLEANED OUT 5' OF FILL & DRILLED F/530' TO 545', RU & RUN GYRO. 0.4 DEGREE ANGLE. 01:30 - 03:00 1.50 DR I 10C2DR DRILLED F/545' TO 670'. 03:00 - 03:30 0.50 DR 1 10C2DR :RUN GYRO WITH 0.7 DEGREE ANGLE. TRY MWD WITH GOOD ANGLE READING BUT NO GOOD AZMUTH READING YET, ,. 03:30 - 04:30 1.00 DR 1 10C2DR DRILLED F/670' TO 790'. 104:30 - 05:30 1.00 DR I 10C2DR ATTEMPT SURVEY W/MWD BUT STILL TOO MUCH INTERFERENCE. DRILL TO 820' & RUN GYRO. 1,9 DEGREE ANGLE. 05:30 - 07:00 1.50 DR 1 10C2DR CONTINUE DRILLING F/790' TO 960'. 07:00- 08:30 1,50 DR 4 :10C2DR ClRC OUT & POOH FOR REMAINING HWDP & JARS. PU SAME, 08:30 - 20:00 11.50 DR I 10C2DR DRILL & SURVEY F/960' TO 1775', SURVEYING WITH MWD FROM 1029'. 20:00 - 21:30 1.50 DR ~7 10C2DR REPAIRING POP OFF VALVE ON # 2 MUD PUMP, 21:30 - 00:00 2.50 DR I 10C2DR CONTINUE DRILLING & SURVEYING F/ 1775' TO 1930', BIT WANTING TO WALK RIGHT, HAVING TO HOLD HARD LEFT TO MAINTAIN DIRECTION. LOTS OF GUMBO. SWEEPING HOLE AS NEEDED, 08/82/97 00:00 - 08:30 8,50 DR 1 10C2DR CONTINUE DRLG & SURVEYING 1930' - 2583' TORQUE & DRAG INCREASING, WORK PIPE SEVERAL TIMES, OK, 08:30- 10:00 1.50 DR 5 10C2DR PUMP 50 BBL HI VIS SWEEP & CBU 10:00 - 11:00 1,00 DR I 10C2DR , DRLG & SURVEY 2583' - 2646' TD 20" CSG POINT 11:00 - 12:30 1.50 DR 5 10C2DR PUMP 50 BBL HIVlS SWEEP/CBU 12:30 - 13:30 1.00 DR 1 10C2DR SD PUMPS. MONITOR WELL. WORK PIPE CHECKING HOLE FOR FILL, NONE, 13:30 - 16:00 2.50 DR 5 10C2DR CBU. SPOT 100 BBL HIVIS PILL ON BOTTOM. 16:00 - 17:30 1,50 DR 4 10C2DR POOH 12 STD SHORTTRIP. DRAG INTERMITTENT TO 60000# 17:30 - 19:30 2,00 DR p 10C2DR TIH WASH DOWN LAST 3 STDS WHILE ROTATING. OK, NO FILL. 19:30- 00:00 4.50 DR p 10C2DR BACK REAM OUT OF HOLE. OK TO 1400'. HAD TO WASH & REAM TIGHT HOLE FROM 1400' TO 1200'. OK. HAD TO CHANGE SHAKER SCREENS DUE TO MUD LOSSES' FROM THICK MuD, BUILDING MORE MUD VOLUME. 08/03/97 00:00 - 05:00 5,00 DR 4 10C2DR FINISH OUT OF HOLE WITH DRLG ASSEMBLY, LOTS OF GUMBO ON BHA. 05:00- 08:00 3.00 CS 0 10C2RC RU WEATHERFoRD CSG EQUIPMENT & Printed: 10/27/98 3:01:54 PM [~i0V 2 ~. 1,9'~8 PHILLIPS PETROLEUM CO Page 9 of 29 ~:[ Oil & Gas Cons. Commission Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling . Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date I From - To Hours Sub Co PhaseJ Code Description of Operations _ 08/03/97 05:00 - 08:00 3.00 CS 0 10C2RC HAVE PRE JOB SAFETY MEETING. 08:00 - 09:00 1.00 CS 1 10C2RC PU VETCO HANGER JOINT. BREAK CONNECTION & CHECK OUT SAME. LD HANGER JT. 09:00- 10:00 1.00 CS I 10C2RC MAKEUP SHOEJT&2NDJTOF20"CSG. 10:00 - 11:00 1.00 CS 7 10C2RC ~WEATHERFORD CSG TONGS BROKE DOWN. REPLACE TONGS & POWER UNIT. 11:00 - 22:30 11.50 CS 1 10C2RC FINISH RUNNIN.G 20", 133#, K55, BT&C CASING TO 2579'. RAN 62 JTS TOTAL PLUS HANGER JT & PUP. INSTALLED CENTRALIZERS AS PER PROCEDURE. LANDED CSG ON WELL HEAD HANGER. 22:30 - 23:30 1.00 CS 1 10C2RC REMOVED FILL UP TOOL. INSTALLED PUMP IN SWEDGE & MU HOSE. 23:30 - 00:00 0.50 CE 5 10C2RC PU HANGER 2' & START CIRCULATING 08/04/97 00:00 - 01:30 1.50 CE 5 10C2RC FINISHED CIRC BU AT 8.0 BPM W/150 PSI. NO LOSSES. 01:30 - 02:00 0.50 CS I 10C2RC HUNG OFF CSG ON HANGER W/310,000 LBS. DRAINED & FLUSHED BETWEEN CSG & RISER FOR VIEWING PROPER BACK OFF OF LANDING JT THROUGH WELLHEAD VALVE. 02:00 - 03:00 1.00 CS I 10c2Rc BACK OFF & LAY OUT LANDING JTS, 03:00 - 04:00 1.00 CS 6 10C2RC RD ALL CASING TOOLS FROM FLOOR. 04:00 - 06:00 2.00 CE 4 10C2RC MU CEMENT SUB/STINGER & RIH ON DP W/BTM JOINT STABILIZED. 06:00 - 07:30 1.50 CE 1 10C2RC ~PU PUP JT & MU ClRC HOSE. BREAK ClRC AT 5 BPM W/60 PSI. STING INTO FC AT 2534'. TEST HB LINES & PUMP 50 BBL FW SPACER AT 8 BPM W/468 PSI. TOOK RETURNS OUT TWO 4" LINES FROM WELLHEAD. SHUT DOWN & HELD PRE JOB SAFETY MEETING. 07:30 - 13:30 6.00 CE 1 10C2RC TESTED LINES & PUMPED 50 BBLS OF WATER SPACER. MIXED & PUMPED 1690 SX OF LEAD CMT AT 12.0 PPG, FOLLOWED WITH 700 SX OF TAIL AT 15.8 PPG. DISPLACED DP W/39 BBLS OF MUD. DETAILS AS PER CMT RPT. FULL RETURNS WITH GOOD CEMENT TO THE SURFACE. 13:30- 14:30 1.00 CE 5 10C2RC ~CIRC DP CLEAN. SLUG PIPE. 14:30.16:00 1.50 CE 4 10C2RC POOH. 16:00 - 22:00 6.00 DR 1 20SFDR RD DIVERTER LINES & SUPPORTS TO DIVERTER & PAN UNDER FLOOR. 22:00 - 00:00 2.00 DR 1 20SFDR PU RISER & DIVERTER. CLEANED UP HANGER TOP & INSTALLED PACK OFF W/RING GROOVE PROTECTOR. SET RISER & DIVERTER BACK DOWN. 08/05/97 00:00 - 05:00 5.00 DR I 20SFDR CONTINUE NU DIVERTER & RISER. FUNCTION TEST DIVERTER. 05:00 - 09:00 4.00 DR 2 20SFDR MU BHA W/18.5" BIT 09:00 - 10:00 1.00 DR 4 20SFDR TEST KELLY VALVES, FLOOR VALVES, SAFETY VALVES 250/5000# 10:00 - 12:00 2.00 DR z 20SFDR TEST BULK BARITE SYSTEM. MIX DRY JOB TO TEST SYSTEM. ALL WORKING OK. _ Nask~ Printed: 10/27/98 3:01:54 PM RECE!\!r-D (' [,10¥ 2 3 1~9~ PHILLIPS PETROLEUM CO Page 10 of 29 0il & Gas Cons. C0mmissl=n Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations ., 08/05/97 12:00- 14:00 2.00 DR 4 20SFDR TIH TAG CMT O2518' 14:00 - 16:00 2.00 DR q ~20SFDR DRLG SOFT CMT 2518' - 2535' FLOAT COLLAR, DRI~G HARD CMT 2535' - 2567' 16:00 20SFDR CIRCULATE & CONDITION MUD. MUD RUN OVER BELL NIPPLE & 17:30 1 .50 DR 5 SPILL INTO BOP ROOM. CLEAN SPILLAGE & SLOW DOWN PUMP RATE. 17:30 - 00:00 6.50 DR q 20SFDR DRILL OUT SHOE AT 257g'. CONTINUE DRILLING & SURVEYING F/2579' TO 3013'. 08/06/97 00:00 - 02:30 2.50 DR q 20SFDR CONTINUE DRILLING & SURVEYING F/ 3018' TO 3285'. 02:30 - 04:30 2,00 DR 4 20SFDR POOH TO CSG SHOE & REPAIR LEAK IN UNION ON GOOSE NECK. RUN BACK TO BTM. SLICK HOLE, 04:30 - 16:30 12.00 DR q 20SFDR CQNTINUE DRLG F/3285' TO 3770' TD. 16:30- 18:00 1.50 DR 5 20SFDR ClRC HOLE CLEAN W/SWEEP. 18:00 - 20:30 2.50 DR p 20SFDR BACK REAMED TO CSG SHOE AT 2579 FT W/NO PROBLEMS. !20:30- 21:30 1.00 DR 5 20SFDR .CIRC BU F/SHOE. 21:30 - 00:00 2.50 DR 4 20SFDR .POOH & LD BHA. 08/07/97 00:00 - 02:00 2.00 DR 2 .20SFDR FINISHED LAYING DOWN BHA. 02:00- 08:00 6.00 CS I 20SFRC RU WEATHERFORD & HELD PRE JOB SAFETY MEETING. 08:00 - 00:00 16.00 CS I 20SFRC RUNNING 13 3/8' CSG W/DUAL 2 3/8" INJECTION STRINGS. 34 JTS OF 13 3/8' 72#, L80, SLX CASING W/ATTATCHED 2 3/8", 4.7#, N80, BTS TBG RUN BY RPT TIME. 08/08/97 00:00 - 17:30 17.50 CS I 20SFRC CONTINUE IN HOLE W/13 3/8' CASING WITH A'i'TATCHED 2 3/8' INJECTION STRINGS TO 3760'. 17:30 - 20:30 3.00 CE 5 20SFRC CIRC BU. 20:30 - 21:30 1.00 CE 0 20SFRC I RU HALLIBURTON & HELD SAFETY MEETING. 21:30 - 00:00 2.50 CE I 20SFRC PUMPED 50 BBL FW SPACER & TEST LINES TO 3000 PSI. STARTED CEMENT JOB BY PUMPING LEAD. 00:00 - 20SFRC 08/09/97 00:00 - 04:00 4.00 CE I 20SFRC FINISHED CEMENTING 13 3/8" CASING WITH 115 BBLS OF 12.0 pPG CEMENT RETURNED AT SURFACE. BUMPED PLUG W/CALCULATED AMOUNT OF MUD & TESTED CASING TO 2000 PSI FOR 30 MIN. OK. CIP AT 0315 HRS. CEMENTING DETAILS AS PER CEMENT REPORT. 04:00 - 06:00 2.00 CS e 20SFRC BACK OFF AT RUNNING TOOL & LD SAME W/LANDING JOINT. RD RUNNING TOOLS & CLEAR FLOOR. 06:00 - 08:00 2.00 CE I 20SFRC !PU STD OF DP W/TOP DRIVE & WASH 'CEMENT F/TOP OF HANGER. 08:00 - 15:00 7.00 DR .2 3011DR ND BELL NIPPLE & DIVERTER SYSTEM 15:00 - 22:30 7.50 DR z 3011DR RIG WELDER MODIFIED INJECTION STRING OUTLETS ON WELLHEAD TO ACCOMMODATE WIRELINE ENTRY. , , Nasi~ Printed: 10/27/98 3:01:54. PM :~... '. , m __ ,, · i 0\/ ~ ~' -[~c.j~; PHILLIPS PETROLEUM CO Page 11 of 29 · ', ',,' - Operations Summa~ Report il & ~as Gons. uommls~t{3~ ~nnhnmn.~ Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Dock Inlet Unit B-1 Spud Date: 07/$1/97 Event Name: Original Drilling Start: 06/05/97 End.' Oontractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Go Phase Code Description of Operations 08/09/97 15:00 - 22:30 7.50 DR z 3011 DR INSTALLED SEALS & MADE OUTS TO TBG TOPS. 22:30 - 00:00 1.50 DR 2 8011DR INSTALL & NU ABB VETCO-GRAY MULTI-BOWL WELLHEAD. INJECTED SEALANI' & TESTED SEALS & VOID. 08/10/97 00:00 - 05:00 5.00 DR 2 30~1 DR TROUBLE GEl-rING TEST ON VOID SECTION OF MULTI-BOWL WELLHEAD, MANAGED TO GET SEAL COMPRESSED & GET A TEST. 05:00 - 06:30 1.50 DR 2 3011DR MADE UP FLANGED OUTLETS ON INdEOTION STRINGS, MADE UP TUBING RISER FOR WIRELINE WORK. 06:30 - 21:30 15.00 DR ! 3011DR RU SCHLUMBERGER & AI-I'EMPT TO RIH W/DUMMY-GAMMA RAY W/NO SUCCESS. UNABLE TO GET PAST 1076' ON ONE STRING & 1930' ON THE OTHER STRING. TRIED DIFFERENT HOOK UPS W/NO SUCCESS. RU SLICK LINE & A'ri'EMPT TO GET DOWN WITH 1 1/2" TOOLS W/NO SUCCESS. TRIED .DIFFERENT HOOK UPS INCLUDING IMPRESSION BLOCK W/NO OBVIOUS INDICATIONS OF TBG DAMAGE. TBG APPEARS TO BE CORK SCREWED IN THAT JAR ACTION IS NOT EVIDENT AS LINE PULL INCREASES. SLICK LINE PROGRESS = 1768' & 1538'. UNABLE TO GET ANY DEEPER. 21:30 - 00:00 2.50 DR 6 3011DR CHANGING OUT RIG 5000 # CHOKE MANIFOLD WITH 10,000 # MANIFOLD. ALSO, HOOKING UP 3RD BARITE TANK, PRESENTLY ATTEMPTING TO LOCATE 1" TUBING FOR CLEAN OUT OF 2 3/8". 08/11/97 00:00 - 08:00 8.00 DR 6 3011 DR CONTINUE RU OF 10,000# CHOKE MANIFOLD & 3RD BARITE .TANK. 08:00 - 13:30 5.50l DR 9 3011DR RD SLICKLINE & RU SCHLUMBERGER. ATTEMPT 1 3/8" DUMMY RUNS ON BOTH 2 3/8" INJECTION STRINGS W/NO SUCCESS. 2550' & 2600' MAX PROG. 13:30 - 00:00 10.50 DR 12 3011DR CONTINUE BUILDING 10,000# CHOKE MANIFOLD & NU 10,000# BOP STACK. 08/12/97 00:00 - 00':00 24.00 DR 6 3011DR CONTINUE BUILDING 10,000# CHOKE MANIFOLD & NU BOP'S. DRAINED & CLEANED MUD PITS. CHANGED PUMP LINERS FROM 6 1/2" TO 6". 08/13/97 00:00 - 00:00 24.00 DR 6 3011DR ,CONTINUE NU BOP'S & BUILDING 10K 'CHOKE MANIFOLD. 08/14/97 00:00 - 00:00 24.00 DR 6 3011DR BUILDING 1.0,000# CHOKE MANIFOLD WITH RELATED WELDING, ETC. 08/15/97 00:00.13:30 13.50 DR 8 3011 DR CONT. TEST BOPE. INITIAL TEST OF 10 K MANIFOLD, STACK. 13:30 - 15:00 1.50 DR 8 3011 DR SET WEAR BUSHING, R/D TEST EQUIP 15:00 - 17:00 2.00 DR ,z 3011DR CENTER RIG OVER HOLE. 17:00 - 20:00. 3.00 DR 8 3011DR CHANGE OUT & TEST UPPER IBOP ON TOP DRIVE. 20:00 - 22:30 2.50 DR 6 3011 DR INSTALL ROOF CAP OVER CHOKE MANIFOLD & INSTALL STIP-O-MATIC. 22:30 - 23:30 1.00 DR w 3011 DR RAJ & TEST CASING TO 4000 PSI. 23:30 - 00:00 0.50 DR 2 3011DR P/U BHA & RIH 08/16/97 00:00 - 05:30 5.50 DR 4 3011 DR P/U BHA, CHANGE SETTING ON MOTOR, ORIENT, RIH ON HWDP 05:30 - 06:30 1.00 DR 4 3011DR P/U DP, TAG HARD @980', WORK DOWN TO 985' 06:30 - 09:00 2.50 DR 4 13011DR POH, STD BACK MWD & MOTOR, CLEAR FLOOR. .09:00 - 10:00 1.00 DR 4 ' 3011 DR .MAKE UP MILL TOOTH BIT & BIT SUB, RIH TO 932' 10:00 - 10:30 0.50 DR I 3011DR WASH & REAM CMT F/932-1025° Printed: 10/27/98 3:01:54 PM i:.i0,,i_,~p ~. '[~. PHILLIPS PETROLEUM CO Page 12 of 29 si; ~ Gas Cons. C0mnlsslo.~ Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000001 Oommon Well Name: North Oook Inlet Unit B-1 8pud Date: 07/81/g7 I Event Name: Original Drilling 8tart: '08/05/[t7 End: Oontractor Name: Unocal/Pool Rig Rig Release: 10/21/[17 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code. Description of Operations 08/16/97 10:30 - 12:00 1.50 DR 4 3011DR RIH, TAG CMT @3649' 12:00 - 14:00 2.00 DR I 3011DR DRILL HARD CMT F/3649'-THRU FLT CLR & FLT SHOE & 10' NEW HOLE TO 3780' 14:00 - 15:00 1.00 DR 5 3011 DR ClRC & COND MUD 15:00 - 16:00 1.00 DR y 3011DR PERFORM LOT W/HALLIBURTON, 14.46 PPG EQUIV MUD WT 16:00 - 18:30 2.50 DR 4 :3011DR POH F/DRLG ASSY 18:30 - 23:00 4.50 DR 2 3011DR MAKE UP PDC BIT, MOTOR & MWD & TEST SAME, MAKE & BREAK ALL HWDP CONNECTIONS. 23:00 - 00:00 1.00. DR 4 3011 DR CONT. RIH W/BHA, PICKING UP DP SINGLES. 08/17/97 00:00 - 02:00 2.00 DR I 3011 DR LEVEL DERRICK 02:00 - 06:00 4.00 DR 4 3011 DR P/U DP, RIH TO 3760' 06:00 - 06:30 0.50 DR ;d 3011DR !WASH & REAM F/3760-3780' 06:30 - 07:30 1.00 DR q 3011DR 'MOTOR DRLG F/3780-3820' 07:30 - 06:30 1.00 DR 7 3011DR CHANGE SHAKER SCREENS, CIRC SLOW & WORK PIPE ,DRLD F/3820-3823' I08:30 - 09:00 0.50 DR 7 3011DR WORK/CLEAN SHAKER SCREENS 09:00 - 10:30 1.50 DR ' q 3011DR MOTOR DRLG F/3823-3881' 10:30 - 12:00 1.50 DR 7 3011DR CLEAN SHAKER SCREENS 12:00 - 00:00 12.00 DR q 3011DR MOTOR DRLG F/3881-4463' 08/18/97 00:00 - 06:00 6.00 DR q 3011 DR SLIDE F/4463-4644', AST 5 HR 06:00 - 07:00 1.00 DR 5 3011 DR CIRC BTMS UP, MIX DRY JOB 07:00 - 08:00 1.00 DR p 3011 DR BACKREAM TO SHOE, TIGHT OUT FIRST 4 STDS, 60-90K OVERPULL 08:00 - 12:00 4.00 DR 4 3011 DR PUMP DRY JOB, POH, L/D BIT, CHANGE ORIENTATION ON MUD MOTOR & ORIENT, RIH (PORTION OF A BOTTOM BIT BLADE MISSING) 12:00 - 14:00 .2.00 DR 4 3011DR RIH W/MILL TOOTH BITON MOTOR BHA ASSY TO 3683' 14:00 - 15:00 1.00 DR 4 3011 DR SLIP & CUT 100' DRLG LINE 15:00 - 15:30 0.50 DR p 3011DR RIH, REAM F/4620-4644' 15:30 - 18:00 2.50 DR q 3011 DR DRLD F/4644-4847', BACK BRAKE ON TOP DRIVE LOCKED UP. 18:0.0 - 19:30 1.50 DR 4 3011 DR ClRC, MIX & PUMP DRY JOB 19:30 - 20:00 0.50 DR 4 3011 DR POH TO 3683' IN CSG. 20:00 - 00:00 4.00 RM m 3011 DR REMOVE TOP DRIVE MOTOR BRAKE, REMOVE AIR HOSES. 08/19/97 00:00 - 03:00 3.00 RM m 3011 DR CLEAR TOP DRIVE OF PARTS & TOOLS, CLEAR FLOOR, WORK ON PIPE RACK, R/U TO PICK UP DP, INSTALL SHIMS #2 DISCHARGE MANIFOLD. 03:00 - 10:30 7.50 DR 4 3011DR P/U 72 STDS DP & STAND BACK IN DERRICK. 10:30 - 19:00 8.50 RM rn 3011 DR SERVICE RIG, MONITOR WELL AWAITING TOP DRIVE PARTS. 19:00 - 22:30 3.50 RM m 3011DR INSTALL TOP DRIVE BRAKE PADS, HUB AND AIR LINES, TEST SAME. 22:30 - 23:30 1.00 DR 4 3011DR RIH W/DRLG ASSY F/CSG SHOE TO 4847' 23:30 - 00:00 0.50 DR q 3011DR ROTARY DRLD F/4847.4899' 08/20/97 00:00 - 03:30 3.50 DR q '3011DR DRLD F/4899-5081 03:30 - 04:00 0.50 DR q 3011DR SLIDE F/5081-5101' 04:00- 06:30 · 2.50 DR q 3011DR DRLD F/5101-5267' '06:30 - 07:00 0.50 DR q 3011 DR SLIDE F/5267-5307' 07:00 - 08:00 1.00 DR q 3011DR :DRLD F/5307-5360' 08:00 - 08:30 0.50 DR q 3011DR SLIDE F/5360-5400' 08:30 - 09:30 1.00 DR q 3011DR DRLD F/5400-5454' 09:30 - 10:00 0.50 DR q 3011DR SLIDE F/5454-5494' 10:00 - 11:00 1.001 DR q 3011DR DRLD F/5494-5548' 11:00- 11:30 0.50 DR q 3011DR SLIDE F/5548-5578' 11:30 - 14:30 3.00 DR q 3011DR DRLD F/5578-5767' 14:30 - 18:30 4.00 DR p 3011DR POH, BACKREAM TO 4528', PULL TO 3683' 18:30 - 23:30 5.00 DR 4 3011DR PUMP SLUG, POH L/D 10' LEAD CLR & STAB, HEAVY CLAY BALLING ON HWDP, STAB & BIT, CHANGE OUT MWD/CDR BATTERIES , Aiask.z Printed: 10/27/98 3:01:54 PM - , i ir \ '.' ~ 1 J0v 2 o ~9~8 PHILLIPS PETROLEUM CO Page 13 of 29 ~i~ & ~as co,~s. Commissi~r, Operations Summary Report ,'~nchnm, n~ Legal Well Name: NORTH COOK INLb! UNIT-B 000001 - Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Odginal Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code' Description of Operations 08/20/97 '23:30 - 00:00 0.50 DR 4 3011 DR 'MAJ BIT & BH,~ 08/21/97 00:00 - 01:30 1.50 DR 2 3011 DR CLEAR FLOOR. MU BIT. PU STB, MWD - ORIENT SAME. 01:30 - 03:00 1.50 DR 4 3011DR TIH 4000' TEST MWD 03:00 - 04:30 1.50 DR 4 3011DR TIH TO 4296' TEST MWD. OK. 04:30 - 05:00 0.50 DR 4 3011DR TIH TO 5712' 05:00 - 05:30 0.50 DR d 3011DR WASH & REAM 5712'- 5767' 05:30 - 08:00 2.50 DR q 3011DR A'I-TEMPT DRLG. BIT BALLED UP. PUMP 35 #/BBL NUT PLUG SWEEP, PUMPED 30 BBL WTR & THINNER, ATEMPTED TO GET BIT TO DRILL FAILED. DRILLED 5767' - 5787' 08:00 - 09:30 1.50 DR 5 3011DR CIRCULATE & MIX DRY JOB TO POOH FOR BIT CHANGE. 09:30 - 10:00 0.50 DR 4 3011DR POOH 4 STDS. TIGHT COMING OFF SLIPS. TIGHT @5543' SCREW IN TOP DRIVE & BEGIN BACKREAM INTO CSG. 10:00 - 12:00 2.00 DR p 3011DR BACKREAM F/5543-4235' 12:00 - 14:30 2.50 DR 4 3011 DR POH F/4235-3683', PUMP DRY JOB, STOP & TURN'OFF CDR BATTERIES. 14:30 - 18:30 4.00 DR !8 3011 DR PULL WEAR BUSHING, TEST BOPE, INSTALL WEAR BUSHING. 18:30 - 19:30 1.00 DR 2 3011DR M/U BIT, RETRIEVE CDR DATA & REPROGRAM TOOLS, CHECK ORIENTATION. 19:30 - 22:00 2.50 DR 4 3011DR 'RIH TO 5730' 22:00 - 22:45 0.75 DR P 3011DR LOG & REAM F/5730-5787' 22:45 - 00:00 1.25 DR q 3011DR ROTARY DRLD F/5787-5'892' 08/22/97 00:00 - 15:00 15.00 DR q 3011 DR DRILL & SLIDE F/5892-6751', LOST TURBINE POWER 15:00 - 15:30 0.50 DR 5 3011DR CIRC BTMS UP 15:30 - 16:00 0.50 DR 4 3011DR SHORTTRIP PULL F/6751-6383' CAME TIGHT 16:00 - 17:30 1.50 DR p .3011DR BACK REAM @6783' 17:30 - 18:00 0.50 DR 4 3011DR RIH, LOG F/6741-6751' 18:00 - 20:30 2.50 DR q 3011DR DRILL & SLIDE F/6751' 20:30 - 21:15 0.75 DR 7 3011DR CIRC @ SLOW RATE & MOVE PIPE WHILE SOLAR GENERATOR DOWN F/45 MINUTES 21:15 - 22:30 1.25 DR q 3011 DR DRILL & SLIDE TO 6896' 22:30 - 23:15 0.75 DR ~5 3011DR CIRC BTMS UP, PREP TO POH 23:15 - 00:00 0.75 DR 4 3011DR POH F/BHA 08/23/97 00:00 - 00:30 0.50 DR 4 3011 DR POOH TO 5687'-TIGHT. 00:30 - 02:00 1.50 DR 4 3011DR BACKREAM OUT 5687 - 4422'. 02:0b - 05:00 3.00 DR 4 3011DR FINISHED POOH. 05:00 - 11:00 6.00 DR 2 3011DR REMOVE BLADE FR/MUD MOTOR, LD MOTOR, BIT & .XO. PU NEW BIT & MTR. INST STAB ON MOTOR. SET MTR @ 1.15 DEG & ORIENT SAME. TIH W/HWT & PU 5 MORE JTS HWT. 11:00 - 13:30 2.50 DR 4 !3011DR RIH TO 6826' 13:30- 14:00 0.50 DR P 3011DR REAM F/6826-6896' 14:00 - 00:00 10.00 DR q 3011DR !SLIDE & DRILL Fn'350~7640' 08/24/97 00:00 - 13:00 13.00 DR q 3011 DR SLIDE & ROTARY DRILL F/7350-7640', ERRATIC TORQUE & LOSS OF PENETRATION. 13:00 - 13:30 0.50 DR 5 3011DR CIRC BTMS UP. 13:30 - 18:30 5.00. DR '4 3011 DR POH, L/D STAB & BIT, TIGHT @ 7292-6730',4772-4491'. 18:30 - 22:00 3.50 DR 2 3011 DR DRESS BIT, P/U ANDERGAUGE ADJUSTABLE STAB & XO, ORIENT & RETRIEVE CDR DATA, TEST MWD. 22:00 - 00:00 2.00 DR 4 3011 DR RIH TO 3746' 08/25/97 00:00 - 01:00 1.00 DR q 3011DR SLIP & CUT DRILLING LINE. 01:00 - 02:30 1.50 DR q ~3011DR RIH W/NEW BIT. 02:30 - 03:30 1.00 DR q 3011DR LOG W/CDR F/7500-7640' _ ., Printed: 10/27/98 3:01:5~ PM RE { 2 ~. tcJ~ PHILLIPS PETROLEUM CO Page 14 of 29 Operations Summary Report ilts Cons. ~Legal'Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Odginal Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 08/25/97 03:30 - 00:00 20.50 DR q 3011DR SLIDE & ROTARY DRILL F/7640-8375',5.5 HR SLIDING 11.75 HR ROTATING. 08/26/97 00:00 - 12:30 12.50 DR .q 3011DR ROTARY & SLIDE DRILL F/8375-8678 12:30 - 13:30 1.00 DR 7 3011DR MUD PUMP DOWN, ClRC & WORK PIPE, REPLACE SWABS. 13:30 - 14:30 1.00 DR q 3011DR ROTARY DRILL F/8678-8701', HIGHER PUMP PRESSURE AND TORQUE. 14:30 - 15:30 1.00 DR 5 3011DR ClRC BTMS UP. 15:30 - 22:00 6.50 DR p 3011DR , BACK REAM TO SHOE. 22:00 - 00:00 2.00 DR 4 3011DR 'PUMP DRY JOB AND POH F/BIT & BHA. 08/27/97 00:00 - 03:00 3.00 DR 2 3011 DR RACK BACK DC'S, LD MOTOR, NM PONY DC'S & ANDERGUAGE ADJ STABILIZER. PU 9 1/2" EXP MOTOR & PDC BIT. 03:00 - 05:00 2,00 DR 4 3011 DR DOWN LOAD CDR TOOL, TEST MWD & TIH TO 13 3/8" SHOE. 05:00 - 05:30 0,50 RM 3 3011DR ADJUST BRAKES AND SERVICE RIG. 05:30 - 07:30 2.00 DR 4 3011DR FINISHED TIH. 07:30 - 08:30 1.00 DR 5 3011 DR CIRCULATE AT REDUCED RATE - SHAKERS OVERLOADED. 08:30 - 10:30 2.00 DR q 3011DR DRLG (RTRY) FR/8701 TO 8727 FT. 10:30 - 11:30 1.00. RM m 3011 DR ClRC & WORK PIPE WHILE CHANGE SWAB IN MP #2. 11:30 - 00:00 12.50 DR q 3011 DR DRLG (RTRY) FR/8727 FT TO 9006 FT. 08/28/97 (J0:00 - 00:30 0.50 DR q 3011DR DRLG 9006' - 9039' 00:30 - 02:00 1.50 DR q 3011DR SLIDE 9039'- 9054' '02:00 - 15:00 13.00 DR q 3011DR DRLG 9054'- 9245' 15:00 - 16:00 1.00 RM m 3011DR RIG REPAIR. CHANGE SWAB MP #2. 16:00 - 16:30 0.50 DR :q 30IIDR DRLG 9245' - 9257' 16:30 - 17:00 0.50 RM m 3011 DR RIG REPAIR. CHANGE SWAB MP#1. 17:00 - 19:30 2.50 DR q' 3011DR DRLG 9257'- 9296'. 19:30 - 20:30 1.00 RM m 3011DR RIG REPAIR. CHANGE SWAB MP #2. 20:30 - 00:00 3.50 DR q 3011DR DRLG 9296'- 9357'. 08/29/97 00:00 - 14:00 14.00 DR q 3011 DR DRILLED (RTRY) FR/9357 - 9576'. 14:00 - 16:00 2.00 DR q 3011DR DRILLED (SLID) FR/9576 - 9581' 16:00 - 20:00 4.00 DR q 3011 DR DRILLED (RTRY) FR/9581 - 9641'. 20:00 - 21:00 1'.00 DR 5 13011DR ClRC BOTTOMS UP. 21:00 - 00:00 3.00 DR p '3011DR BACKREAM OOH. BIT DEPTH @ MIDNIGHT 8576'. 08/30/97 00:00 - 05:00 5.00 DR 4 3011 DR CONTINUE POOH W/TOP DRIVE 8670' - 3780' TO JUST BELOW CSG SHOE. 05:00 - 06:00 1.00 DR 5 3011 DR CBU @3780' - CK FLOW NONE. PUMP SLUG POOH 06:00 - 09:00 3.00 DR 4 3011DR POOH LD BIT. DOWNLOAD MWD. CHECK BIT, NO DAMAGE. NORMAL WEAR. 09:00 - 13:30 4.50 DR 8 3011DR PULL WEAR BUSHING. SET TEST PLUG. WEEKLY BOP TEST, ALL OK. :PULL PLUG & SET WEAR BUSHING. '**NOTE: BLAIR WONDZELL STATE OF ALASKA OIL & GAS WAIVED WITNESS OF TEST. 13:30 - 14:00 0.50i DR .0 . 3011DR SAFETY MEETING AFTER CREW CHANGE 14:00 - 17:00 3.00 DR 2 3011 DR CHANGED OUT MWD TOOL. P/UP ANDERGUAGE ADJUSTABLE STABILIZER ON TOP OF MOTOR & MU NEW PDC BIT. PROGRAM MWD & FLOW TESTEI~ SAME. 17:00 - 21:30 4.50 DR 4 13011 DR TIH TO 9526 FT (HOLE SLICK). 21:30 - 23:00 1 .§0 DR 5 3011 DR WASH & REAM .TO BOTTOM. CIRC B/UP. 756 UNITS TRIP GAS. .,. _ Pdnted: 10/27/98 3:01:54. PM PHILLIPS PETROLEUM CO Page 15 of 29 Operations Summary Report Legal ~~e: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05~97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 08/30/97 23:00 - 00:00 1.00 DR q 3011 DR BREAK BIT IN W/LOW WT. DRILL (RTRY) FIE 9641 TO 9648 FT. 08/31/97 '00:00 - 04:30 4.50 DR q 3011DR DRLG 9648' - 9707' 04:30 - 05:00 0.50 DR 5 3011DR CIRCULATE. CLEAN SUCTION SCREEN ON #1 MUD PUMP. 05:00 - 07:00 2.00 DR q 3011 DR A'I-I'EMPTING TO SLIDE 9707' - 9715' 07:00 - 11:00 4.00 DR q 3011 DR DRLG 9715'- 9727' SLOW PENETRATION RATE, UNABLE TO GET ANY DIFFEREN.'I'IAL ON MUD MOTOR. PUMPED SWEEP & TRIED VARIOUS WEIGHTS & ROTARY SPEEDS. 11:00 - 18:30 7.50 DR p 3011 DR BACKREAM OOH TO 13 3/8 SHOE. 18:30 - 19:30 1.00 DR :5 3011DR CIRC AT SHOE & PUMP DRY JOB. 19:30 - 21:30 2.00 DR :4 3011DR FINISHED POOH. 21:30 - 23:00 1.50 DR '2 3011DR DOWNLOAD CDR. LD ANDERGUAGE STAB & EXP MOTOR. PU USED LOW SPEED MUD MOTOR. 23:00 - 00:00 1.00. DR 4 3011 DR MU NEW BIT #11, ORIENT MWD/MTR & ST. ART TIH. 09/01/97 00:00 - 01:00 1.00 DR 4 3011DR MU BHA. TEST MWD,OK. 01:00 - 02:00 1.00 DR 4 !3011DR TIH TO CSG SHOE. 02:00 - 03:00 1.00 DR z 301'~DR SLIP & CUT 101' DRLG LINE 03:00 - 05:30 2.50 DR 4 '3011DR TIH FILL DP {~7172'. CONTINUE TIH TO 9630' 05:30 - 06:00 0.50 DR d 3011DR WASH 9630' - 9727' +.LOGGING W/MWD 06:00 - 00:00 18.00 DR q 3011 DR DRLG (RTRY) FIE 9727 - 10115 FT. 09/02/97 00:00 - 01:00 1.00 DR q 3011DR DRLG 10115'- 10143' 01:00 - 01:30 0.50 DR 7 3011DR CHANGE SWAB IN #1 MUD PUMP 01:30 - 05:30 4.00 DR q 3011 DR DRLG 10143' - 10227' 05:30 - 17:00 11.50 DR 5 3011DR CIRCULATE OUT GAS FROM DRLG BREAK @10185'- 10215'. BG GAS INCREASED FIE 80 UNITS TO 3000. MUD BELCHING OVER BELL NIPPLE, SD PUMPS, CLOSE HYDRIL, NO SI PRESSURES. ClRC 2000 STKS THRU CHOKE WHILE WORKING PIPE IN ANNULAR. SD PUMP, . NO FLOW. OPEN HYDRIL CIRCULATE DOWN FLOWLINE. CONTINUE 'ClRC WITH BG GAS DROPPING TO 100 UNITS. SD PUMP FOR 20 MINUTES CHECKING FOR FLOW, NONE. CBU, GAS INCREASED TO 900 UNITS. INCREASE MUD WT TO 10.2#. WHILE CIRCULATING BG GAS INCREASED TO 2900 UNITS. 10.2# IN & OUT BG GAS DROPPED TO 2200 UNITS & STABILIZED. INCREASED MUD WT TO 10.5# W/BG GAS DROPPING TO 500-600 UNITS. DECIDED TO DRILL AHEAD MONITORING BG GAS. 17:00 - 18:30 1.50 DR :q 3011DR DRLG 10227'- 10254' 18:30 - 19:00 0.50 DR 15 3011DR CIRCULATE & WORK PIPE PRIOR TO MAKING CONNECTION. NO PROBLEM. 19:00 - 00:00 5.00 DR q 3011DR MADE CONNECTION @ 10254'. DRILL (RTRY) TO 10399'. RAISE MW TO 10.7 PPG - 10.6 PPG OUT. BGG STABILIZED @ 300 -'400 UNITS. CONNECTION GAS FIE 10254' - 860 UNITS. 09/03/97 00:00 - 07:00 7.00 DR q 3011 DR DRILLED (RTRY) FIE 10327 TO 10378 FT BGG RUNNING 450 - 500 UNITS WITH 10.7 PPG MUD. 07:00 - 10:00 3.00 DR 5 3011DR CIRCULATE AND RAISE MW FIE 10.7 TO 11.O PPG. BGG DECREASED TO 300 ITO 400 UNITS & STABILIZED. 10:00 - 12:00 2.00 DR P 3011DR iBACKREAM FIE 10378 TO 9696.FT. 12:00- 13:00 1.00 DR 4 3011 DR TIH TO TD (SLICK). Printed: 10/27/98 3:01:54 PM ; !0";" £ ,,~. ']9.~ PHILLIPS PETROLEUM CO Page 16 of 29 .. Gas C0 s. comm[ss[0r Operations Summa Repo Anch0ra~ Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: No~h Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Sta~: 06/05/97 End: Contractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date J From- To Hours Sub Co Phase Code Description of Operations 09/03/97 13:00 - 18:00 5.00 DR 5 3011DR CIRC & COND MUD. TRIP GAS 3170 UNITS. PUMP HIVIS ~'D SWEEP AROUND. RAISED MW TO 11.2 PPG. age DECR'D TO APPROX 200 UNITS & STABILIZED. 18:00 - 00:00 6.00 DR p 3011DR BACKREAM OOH F/LOGS. 09/04/97 :00:00 - 02:00 2.00 DR 4 3011DR FINISHED BACK R~MING T0 SHOE. 02:00 - 03:30 1.50 DR g 3011 DR OBSERVE WELL FOR FLOW. OK. CBU WITH 460 UNITS GAS, BRIEFLY. 03:30- 04:30 1.00 DR 4 3011DR POOH. 04:30 - 07:30 3.00 DR 2 3011DR STD BACK HWDP. DOWNLOAD CDR. ~Y OUT MWD & MOTOR. BIT SHOT W/ ~O LOOSE CONES. 3/8' UNDERGAUGE 07:30 - 09:30 2.00 LG 6 301lEV HELD PREJOB SAF~ MEETING AND RU SCHLUMBERGER. NOTE: NOTIFIED MR. B~IR WANDZELL W/AOGCC OF OUR INTENTION TO RUN 9 ~8' CSG AT 09:30 HRS 9~97. 09:30 - 16:30 7.00 LG 1 301lEV RIH W/DITE-CNL-LDL-LSS-MICROLOG- GR-AMS TO 9680'. UNABLE TO GET BELOW 9680' BUT NO HANGING WHEN PICKING UP. OPEN CALIPER & LOG UP TO CSG SHOE. POOH W/LOGGING TOOLS. 16:30 - 18:00 1.50 LG 2 3011EV LD OPEN HOLE LOGGING TOOLS, PU CBT TOOLS. 18:00 - 20:00 2.00 LG I 3011EV RAN CBT FR/3762' TO 1300 ~. 20:00 - 20:30 0.50 LG 2 3011EV . LD CBT TOOLS & PU R~ TOOLS. 20:30 - 00:00 3.50 LG I i3011EV RUN ~3 R~S. RIH W/R~OOL. TOOK 12 PRESSURE READINGS IN THE COOK INL~ SANDS B~EEN 4225 ~ & 4850 ~. 09/05/97 00:00 - 03:30 3.50 LG 1 3011EV CO~INUE R~ PROGRAM. TOOK 20 MORE PRESSURE POINTS IN THE COOK INL~ AND BELUGA SANDS. EXPERIENCED CONSIDERABLE OVER- PULL ON THE ~ST PRESS POINT. DECIDED TO CUT R~ PROGRAM SHORT. POOH W/R~ TOOLS. 03:30 - 04:00' 0.50~ LG .6 301lEV RD SCHLUMBERGER. 04:00 - 08:00 4.00 CS 4 3011RC TIH W/BIT ~ 12. FILL PIPE ~ 13 3/8". CONTINUE IN HOLE TO 9429'. 08:00.12:00 4.00 RM m 3011RC CIRCUITED OUT GAS FROM 9429' WHILE WORKING ON EL-MAGGO BRAKE. ROTATED WHILE CIRC. MAX GAS 730 UNITS WITH MUD CUT FROM 11.2 PPG TO 9.3 PPG. CIRC GAS OUT & BA~NCED. EL-MAGGO BRAKE LOCKED IN. HUNTING PARTS. 12:00- 13:00 1.00 CS 4 3011RC FINISHED IN HOLE TO 10,278' W~O PROBLEMS. MU TOP DRIVE & WASHED & ROTATED 100' TO BTM FOR SAF~ W~O PROBLEMS. NO FILL. 13:00 - 16:00 3.00 CS . 5 3011RC CIRC HIGH VISC SWEEP AROUND W/ LOTS OF FILTER CAKE OVER SCREENS MAX GAS 1100 UNITS W~UD CUT TO 9.5 PPG. GAS 500 UNITS. Printed: 10/27/98 3:01:54 PM ; :~-; ...~ .~: !c~-5 PHILLIPS PETROLEUM CO Page 17 of 29 ,., 4' ,- ~.~ Operations Summa Report Cons. Commission Legal we. Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: No~h Cook Inlet Unit B-1 Spud Date: 0W31/97 Event Name: Odginal Ddlling Sta~: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co'Phase Code Description of Operations 09/05/97 16:00 - 17:00 1,00 cs 5 3011RC CONTINUE CIRCUITING TO REDUCE GAS WHILE LOWERING YIELD FOR CSG ~RUNNING. 17:00 - 00:00 7,00 CS 4 3011RC :BACKREAM TO 6533'. PULL TIGHT :COMMING OFF SLIPS, HOLE HAD BEEN SLICK. PU SINGLE & WORKED PIPE FREE, WORK OUT TIGHT SPOT A~EM~ TO STAND BACK STAND TIGHT AGAIN, MU STAND ESTABLISH ROTATION & ClRCU~TION WORKED OUT TIGHT SPOT AGAIN. PREPARE HI-VIS SWEEP. 09/06/97 00:00 - 01:30 1,50 CS 4 3011RC ClRCU~TE & REAM TIGHT SPOT AT SSSa'. MIX & PUMP A 35BBL HIGH VISC SWEEP & CIRC HOLE CLAN. 01:30 - 04:00 2.50 CS 4 3011RC BACK R~M TO 13 3/8" SHOE AT 3760' 04:00 - 05:00 1.00 CS 5 3011RC OBSERVE WELL FOR FLOW, OK, CBU W/83 UNITS OF GAS MAX. CHECK FOR 'FLOW & SLUG. 05:00 - 07:00 2.00 CS 4 3011RC POOH & STAND BACK BHA, 07:00 - 09:00 2,00 CS 1 ,3011RC PU, DRIP, STRAP, & STAND BACK 30 JTS OF HWDP & PULL WEAR BUSHING. 09:00 - 12:00 3.00 CS 6 3011RC RU W~ERFORD CSG TOOLS, 12:00 - 12:30 0,50 CS 0 3011RC HELD PR~OB SAFE~ MEETING. NOTE: B~IR WONDZELL W/AOGCC GRA~ED ~ENSION TO BOP TEST REQUIREMENT UNTIL LINER SET & CMTD., 11:15 HRS 9/5/97. 12:30 - 00:00 11,50 CS 1 3011RC RAN LINER. RAN 146 JTS 9 5/8" 53.5~ P-110 BR&C CSG. RD CSG TOOLS & CONT'D RUNNING LINER ON 5" HWDP. DEPTH AT MIDNIGHT 6900 ~. 09/07/97 00:00 - 03:30 3.50 CS 1 3011RC , FINISHED IN HOLE W/A TOTAL OF 148 JTS OF 9 5/8"- 53,5~ - Pl10 - BTC CSG FOR 6790' INCLUDING FLOATS & HGR. WASHED ~ST STAND DN, A~EMPT TO PU W/NO SUCCESS. MAX 500K, :03:30 - 07:30 4,00 CE 5 3011RC ClRC & COND MUD FOR CEMENTING, MAX GAS 2200 UNITS, FULL R~URNS. 07:30 - 08:00. 0.50 CE '0 3011RC HELD PRE JOB SAFE~ ME~NG. 08:00 - 09:30 1.50 CE 1 3011RC DROPPED & PUMPED DOWN BALL TILL SEATED. PRESSURED UP TO 1800 PSI & SLACKED OFF 20,000 LBS. BLEW BALL SEAT W/4000 PSI & REESTABLISHED ClRCU~TION, ROTATED & RELEASED RUNNING TOOL & CHECKED FOR FREE TRAVEL. OK. SET BACK DOWN & CIRC. .09:30 - 11:00 1,50 WO s 3011RC CO~INUE ClRC WHILE WAITING ON TIDE TO CHANGE SO BOAT CAN COME , Printed: 10/27/98 3:01:54 PM ~'"'V' 2 ~ 1,~4~ PHILLIPS PETROLEUM CO Page 18 of 29 Operations Summary Report ,',A~; Legal ~'~e(ll'~ame: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Ddlling Start: '06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10121/97 Group: Rig Name: Rig Number: 428 Date I From -To Hours Sub Co Phase Code Description of Operations I 09~07~97 09:30 - 11:00 1.50 WO s 3011RC IN WITH NEEDED CEMENT FOR JOB. RIG CMT TANKS FULL, BUT CMT ON BOAT NEEDED TO FINISH JOB. 11:00 - 15:00 4.00 CE 1 3011RC TIED UP MV MONARCH & HOOKED UP CMT HOSE. TESTED LINES TO 5000 PSI & PUMPED 10 BBLS F'W. MIX & PUMP 822 BBLS ( 2400 SX ) OF LEAD CMT AT 12.5 PPG, FOLLOWED WITH 144 BBLS (704 SX) OF TAIL CMT AT 15.8 PPG. NOTE: AT 300 BBLS OF LEAD PUMPED, RETURNS STARTED PHASING IN & OUT. AT.500 BBLS OF LEAD PUMPED, LOST ALL RETURNS. SLOWED PUMP FROM 5.5 BPM TO 3.0 BPM TO REGAIN CIRC. NO SUCCESS. CONTINUED PUMPING AT 5.0 BPM DUE TO THICKENING TIME CONSTRAINTS. 150 PSI PUMP PRESS. NO RETURNS. 15:00 - 16:30 1,50 CE 1 30ilRC DROPPED DART & PUMPED 10 BBLS OF F'W BEHIND. DISPLACED DART W/RIG PUMP NOTICING SAME LAND IN LINER WIPER PLUG. CONTINUED DISPLACING W/RIG PUMP. DID NOT BUMP PLUG. 16:30 - 19:30 .3.00 CE 5 3011RC BLED OFF & CHECKED FLOATS, PULL OUT RUNNING TOOL. ClRC BU. ClRC OUT 50 BBLS CMT CONTAMINATED MUD. 19:3.0 - 22:00 2.50 CE 4 3011RC PUMP DRY JOB & POOH. 22:00 - 22:30 0.50 CE 2 3011RC LD BAKER 2 RH RUNNING TOOL. 22:30 - 00:00 1.50 CE 4 3011RC TIH W~ DOG SUB TO SET LINER TOP PKR. NOTE: 21:30 HRS 9~6/97 NOTIFIED BLAIR WONDZELL W/AOGCC OF OUR INTENTION TO PERFORATE AND ESTABLISH INJECTION THROUGH THE 13 3/8" CSG. 09/08/97 00:00 - 00:30 0.50 CE 4 3011RC FINISH TIH. WASH LAST STD TO LINER TOP. SET 65000# ON TIE BACK EXTENSION. OBSERVED w'r IND JUMP INDICATING PKR SET. 00:30 - 02:00 · 1.50 CE 5 3011RC ClRC BOTTOMS UP, RECOVERED SOME CMT CONTAMINATED MUD.. . PUMPED DRY JOB. 02:00 - 03:00 1.00 RM lc 3011RC POOH W/2 STDS. SLIP & CUT 105' OF DRLG LINE. 03:00 - 04:30 1.50 CE 4 3011RC 'POOH W/DOG SUB. 04:30 - 09:30 5.00 WC 8 3011RC TEST BOP'S FOR WEEKLY & SET WB. 109:30 - 13:00 3.50 RM m 3011RC RIG REPAIR: FRONT BRAKE BAND BOLTS VIBRATED OFF OPPOSITE THE DRILLER. REMOUNTED SAME & THREAD LOCKED BOLTS. 13:00 - 15:00 2.00 DR 4 3011RC RIH W/12 1/4" BIT & CLEANED OUT TO TOP OF LINER PKR AT 3588'. OK. , AJask;. Printed: 10/27198 3:01:54 PM ('~0~,:' 2 ~ lcJ~ PHILLIPS PETROLEUM CO Page 19 of 29 .... Operations Summary Report ~.o~.~ u;, ~, Gas Cons. Commission Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 09/08/97 13:00- 15:00 2.00 DR 4 3011RC 15:00 - 16:00 1.00 DR 5 3011RC ClRC BU. 16:00 - 18:00 2.00 DR 4 3011RC POOH W/BIT. 18:00 - 19:00 1.00 DR 4 3011RC MU PBR MILLS & RIH. 19:00 - 19:30 0.50 DR . h 3011RC CLEAN OUT LINER TIE-BACK EXTENSION. 19:30 - 20:30 1.00 DR 5 30ilRC CIRC BU. ;20:30 - 21:00 0.50 DR 9 3011RC CLOSED ANNULAR AND PRESSURE TEST CSG, LINER LAP & LINER TO 3000 PSI - 15 MIN-OK. 21:00 - 22:00 1.00 DR 4 3011RC PUMP SLUG & POOH W/16 STDS DP. 22:00 - 23:00 1.00 RM m 3011RC RIG REPAIR. HUB SPUN ON SHAFT TO DRWKS 'B' TRACTION MOTOR. DISCONNECT "B" TRACTION MOTOR. WILL RUN ON 'A" MOTOR. 23:00 - 00:00 1.00 DR 4 301~ RC FINISH POOH W/PBR MILL 09/09/97 00:00 - 00:30 0.50 CS 1 3011RC L/D PBR MILLS. 00:30 - 01:00 0.50 DR 2 3512DR PULL WEAR BUSHING. 01:00 - 03:00 2.00 DR z 3512DR RU SCHLUMBERGER & HELD PRE JOB SAFETY MEETING. 03:00 - 07:00 4.00 DR z 3512DR RIH W/4.5' CSG GUNS & PERF AT 4 SPF STERLING SANDS FOR DISPOSAL. ON RUN #1 F/3530 TO 3540', RUN #2 F/3520-3530', ALL SHOTS FIRED. 07:00 - 08:0(~ 1.00 DR 4 3512DR MISFIRE ON RUN # 3. POOH & REDRESS FIRING CAP. 08:00 - 09:00 1.00 DR 4 .3512DR RIH WITH GUN RUN RR#3 & PERFORATE : F/3500' TO 3520'. POOH. ALL SHOTS FIRED. OBSERVED RADIO SILENCE. 09:00 - 10:00 1.00. DR 6 3512DR RD SCHLUMBERGER & MONITOR WELL ON TRIP TANK. WELL STATIC. 10:00 - 14:00 4.00 DR 2 3512DR RIH & L/D 6 5/8' HWDP & MONELS. 14:00 - 14:30 0.50 DR y 3512DR CLOSED BLINDS & ESTABLISHED INJ RATE THROUGH STERLING PERFS AS F. OLLOWS: 900 PSI AT 1.0 BPM, 970 PSI AT 2.0 BPM, 985 PSI AT 3.0 BPM, 965 PSI AT 4.0 BPM, 975 PSI AT 5.0 BPM, 990 PSI AT 6.0 BPM, 1000 PSI AT 7.0 BPM, 1000 PSI AT 8.0 BPM. TOTAL OF 45 BBLS INJECTED. 14:30 - 17:(~0 2.50 CS 6 3011RC RIG UP WEATHERFORD.CSG EQUIPMENT 17:00 - 17:30 0.50 CS 0' 3011RC PRE-CASING SAFETY MEETING. 17:30 - 00:00 6.50 CS I 3011RC RUN 77 JTS 9-5/8, 53.5#, P-110 BTC CSG 3585 FT, INCLUDING PUPS AND VETCO MANDREL HANGER, SPACE OUT, LAND CSG, PULL LANDING JTS. '. 09/10/97 00:00 - 01:00 1.00 CS n .3011RC MU HANGER & LANDING JNT. LAND HANGER. IJD LANDING JOINTS. 01:00 - 02:00 1.00 CS 6 3011 RC R/D CASING TOOLS. 02:00 - 04:00 2.00 CS n 3011RC INSTALLED & TESTED PACKOFF SEALS TO 10,000 PSI. OK. 04:00 - 12:00 8.00 CS 9 3011RC ATTEMPT TO TEST CSG W/2500 PSI. OK. CONTINUED UP TO 3300 PSI AND BEGAN TO LEAK OFF. REPAIRED STEM PACKING ON MUD PUMP. ATTEMPT .TEST AS BELOW: TEST PSI: BK SIDE: INJ TBG: VOLUME Printed: 10/27/98 3:01:54. PM 'i 0",/' 2~, ~, ]~}~ PHILLIPS PETROLEUM. CO Page 20 of 29 Operations Summa Report ., ~,:: c~i & Cas Cons. C0.mmissi~a Legal we~ Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Odginal Ddlling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 - To I Hours Sub Co Phase Code Description of Operations Date From 09/10/97 04:00 - 12:00 8.00 CS 9 3011R0 500 PSI 100 PSI 800 PSI 1.5 BBLS 1000 PSI 250 PSI' 700 PSI 2.5 BBLS 1500 PSI 425 PSI 850 PSI 4.0 BBLS 2000 PSI 590 PSI 1000 PSI 6.0 BBLS STOPPED PUMP & BLED OFF TO 1100 PSI IN 10 MIN., 500 BK SIDE, 1050 INJ LINE. 12:00 - 15:00 3.00 CS 9 3011RC ~PRESSURED UP ON 9 5/8' ANNULUS W/ TOP CSG VALVE OPEN. JUST BEGAN TO PUMP W/LOW VOLUME TEST PUMP & GOT FLOW OUT TOP CSG VALVE INSTANTLY. PULL & RERUN NEW PACKOFF. NO DAMAGE FOUND ON THE 1ST PACKOFF. TEST WITH TEST PUMP. AT 1650 PSI TEST PRESSURE & 550 PSI ANNULUS PRESSURE, BLED OFF BACK SIDE. TEST PRESSURE IMMEDIATLY FELL TO 1100 PSI. STOPPED PUMPING & TEST PRESSURE FELL TO 900 PSI IN TWO MIN. STEADY RETURN ON BK SIDE. CLOSED IN BACK SIDE & TEST PRESSURE CONTINUED TO FALL RAPIDLY TO 460 PSI & STABILIZED. 15:00 - 17:30 2.50 CS z 3011RC MONITORED CASING & UNLOADED OIL BASE MUD FROM WORK BOAT WHILE WAITING ON HALLIBURTON REP TO RUN RTTS. PRESSURES STABILIZED AT 460 PSI INSIDE 9 5/8", ZERO ON CSG, 590 INJECTION LINE. 17:30 - 20:00 2.50 CS z 3011RC P/U RTTS TOOL, TESTED 9-5/8 HANGER SEALS TO 2000#, 'WELLHEAD TO 5000# 20:00 - 22:00 2.00 CS z 3011RC RIH W/R'Frs TO 3630' 22:00 - 00:00 2.00 CS z 3011RC TEST CSG BELOW PBR TO 5000#-OK, TEST CSG F/3540'(ABOVE PBR) TEST CSG, IMMEDIATE LEAK THRU SEALS IN PBR. POH W/R'Frs 09/1.1/97 00:00 - 00:30 ~).50 CS 7 3011RC MIX & PUMP SLUG. 00:30 - 02:30 2.00 CS 7 '3011RC POOH & L/D Rq-r's PACKER, 02:30 - 03:30 1.00 CS 7 3011RC PULL HANGER PACKOFF. 03:30 - 05:30 2.00 CS 7 3011RC RU CSG CREW, 05:30 - 09:30 4.00 CS 7 3011RC PU LANDING JTS. MU INTO HANGER & PULL HANGER TO FLOOR. INSPECT HANGER & MAKE SAME BACK UP. STD BACK LANDING JTS & HANGER. 09:30 - 12:30 3.00. CS 7 3011RC PU TWO JTS OF CASING, RIH SPACING OUT TO JUST ABOVE PBR. ENGAGE PUMP, & ENTER PBR TILL PRESSURE INCREASE OBSERVED. SHUT DOWN PUMP. CONTINUED ENGAGEMENT INTO PBR WITH PROPER SPACE OUT, TILL LANDING ON STOP RING. SET DOWN W/ 40,000 LBS, A~I'TEMPTED TO TEST TO 3000 PS! BUT STRING STARTED HYDRAULIClNG AT 2200 PSI. ALLOWED FOR STABILIZATION & PRESSURE CONTINUED TO FALL RAPIDLY. Printed: 10/27/98 3:01:54 PM 'ii.)"v' 2 ~ 1,~j~ PHILLIPS PETROLEUM CO Page 21 of 29 Operations Summary Report Legal Wel~j~~ NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling . Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date I From - ToHoursSub CoPhase Code Description of Operations 09/11/97 09:30- 12:30 3.00 CS 7 3011RC BLED - OFF PRESSURE. PREPARE TO L/D CSG. 12:30 - 20:30 8.00 CS 7 3011RC POOH LAYING DOWN 9 5/8' TIE BACK STRING TO CHANGE SEALS ON SEAL ASSEMBLY. 20:30 - 22:00 1.50 CS 7 3011RC RIG DOWN CASING EQUIPMENT. 22:00 - 00:00 2.00 CS 7 3011RC P/U MILL, WASH. SUB & STABILIZER & RIH, PUMP HI-VIS SWEEP AT LINER LAP. 09/12/97 00:00 - 01:30 1.50 CS 7 !3011RC CLEAN OUT PBR W/MILL & SWEEP. 01:30 - 03:00 1.50 CS 7 3011RC POOH W/MILL. 03:00 - 04:30 1.50 CS 7 3011RC RU WEATHERFORD CSG TOOLS. 04:30 - 11:00 6.50 CS 7 3011RC PU & MU SEAL ASSEMBLY & RIH WITH 9 5/8" TIE BACK STRING. 11:00 - 13:00 2.00 CS 7 3011RC PU LANDING JTS. MU CIRC HOSE & RIH TO TOP OF PACKER W/PUMP IDLING. OBSERVED PRESS INCREASE..BLED OFF PUMP.. PU 2' & CIRC HIGH VISC SWEEP AROUND. NO SEALS TO SURFACE. 13:00 - 14:00 1.00 CS 7 301'i RC SLACK OFF TO 120K SET DOWN WEIGHT & TEST SEALS TO 500 PSI. OK. 14:00 - 15:00 1.00 CS 17 3011Rc !SPACED OUT REPLACING 6' PUP WITH 8' PUP TO LAND 80,000 LBS ON SEALS. 15:00 - 18:00 3.00 CS 7 3011RC WITH HANGER LANDED, BACKED OUT & LAYED OUT LANDING JTS & RUNNING TOOL. RD WEATHERFORD. RUN PACK OFF. 18:00 - 19:30 1.50 CS 7 3011RC PRESS TEST CSG LINER TO 5000K F/30 MINUTES. 19:30 - 00:00 4.50 DR w 3011RC CLEAN PITS, CHANGE PUMP LINERS, PREPARE OIL MUD 09/13/97 00:00 - 00:00 24.00 DR w 50PRDR CHANGED SWABS & LINERS IN MUD PUMPS, CHANGED VALVES & SEATS IN PUMPS, CLEANED RIG PITS INSTALLED DIESEL LINE IN PLATFORM PITS, CHANGED SHAKER SCREENS, PERFORMED INJECTION TEST WITH APOLLO THRU INJECTION TBG: 1/2 BPM @ 1150 PSI, 3/4 BPM @1250 PSI, 1-1/2 BPM @ 1400 PSI. ClRC THRU i STANDPIPE, MANIFOLD AND SOLIDS CONTROL EQUIPMENT, CLEANED OUT DESILTER & POSSUM BELLY, DISCONNECT WATER IN PLATFORM PITS. 09/14/97 00:00 - 09:00 9.00 DR w 3512DR CONTINUED CLEANING PITS & TRIP TANK, PUMP WATER THRU KILL LINE, CMT LINE, PUMP BLEED OFF, & CHOKE MANIFOLD. 09:00 - 16:30 7.50 DR 8 3512DR TEST CHOKE MANIFOLD, FLOOR VALVES, TOP DRIVE VALVES, KELLY HOSE AND STANDPIPE VALVE, TEST BOPE 16:30 - 17:30 1.00 DR 8 3512DR PULL TEST PLUG, INSTALL WEAR BUSHING, R/D TEST JT, BLOW DOWN STAND PIPE & MANIFOLD, TOP DRIVE, CHOKE AND KILL LINES. 17:30 - 18:00 0.50 DR 7 '3512DR PLUG GAP IN RIG FLooR DRIP PAN. 18:00 - 21:30 3.50 DR 2 3512DR PICK UP BHA, CDR WOULD NOT MAKE UP, L/D CDR, TEST MWD W/H20 21:30 - 00:00 2.50 DR 4 3512DR RIH W/HWDP, P/U JARS, RIH W/DP 09/15/97 00:00 - 01:30 1.50 CE h 3512DR CONTINUE IN HOLE TO CMT AT 9757'. 01:30 - 02:30 1.00 CE h 3512DR MOVE MUD AROUND FOR DRLG CMT. 02:30 - 04:00 1.$0 CE h 3512DR CIRC CEMENT OUT OF HOLE. 04:00 - 07:00 3.00 CE h 3512DR , DRILL CEMENT F/9757' TO LC 10,280'. 07:00 - 08:00 1.00 CE h 3512DR 'CIRC BU. 08:00 - 10:00 2.00 CE h 3512DR CLEAN PITS AFTER DRILLING CEMENT. Printed: 10/27/98 3:01:54 PM !.-,'-,: ;~,~.¥ ._5' ~ "i,~.~ PHILLIPS PETROLEUM CO Page 22 of 29 ,~." ;!, Gas C~,,o. Commission Operations Summary Report .~nch~r~ ! , Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/$1/97 Event Name: Odginal Ddllin9 Start: 06/05/9'7 End: Contractor Name: Unocal/Pool Ri9 Rig Release: 10/21/9'7 Group: Rig Name: Rig Number: 428 Date From - To Hours lSub Co Phase Code Description of Operations 09/15/97 10:00 - 10:30 0.50 DR 5 3512DR PUMP 35 BBL WATER & 35 BBL HI VIS PILL 10:30 - 14:00 3.50 DR w 3512DR CLEAN PITS & PREPARE F/OBM 14:00 - 15:00 1.00 DR w 3512DR REMOVE OVERBOARD LINES & PLUG OFF. 15:00 - 21:00 6.00 DR w 3512DR INSTALL APOLLO AUGER F/ACTIVE PITS, INSTALL DRIP PAN ON ACTIVE MAIN AUGER OUTSIDE, PLUG ALL WATER LINES AND F/D ALL DRILL. WATER & SALTWATER LINES TO ACTIVE PITS, WATER TO TEST PUMP, INSTALL SPRING ON BRAKE BAND DRILLERS SIDE, INSTALL CLAMPING CYLINDER ON RAISE BACKUP. 21:00 - 23:00 2.00 DR w 3512DR TRANSFER OBM F/PRODUCTION PLATFORM PITS TO ACTIVE SYSTEM. 23:00 - 00:00 1.00 DR w 3512DR TRANSFER OBM FROM PRODUCTION TANK TO PLATFORM PITS. 0g/16/g7 00:00 - 0g:00 g.00 DR 6 50PRDR CONTINUE WITH TRANSFERRING OIL BASE MUD FROM PLATFORM GIRDER TANK TO PLATFORM MUD PITS. WEIGHT UP & TREAT SAME FOR DRILLING. THIS VOLUME NEEDED TO DISPLACE HOLE. SEALED UP VARIOUS LEAKS IN RUBBER SEALS EFFECTED BY OIL BASE MUD. ALL CONTAINED. ALL PRODUCT TRANSFERRING VERY SLOW. HELD SAFETY MEETING RELATED TO SWAPPING OUT TO OIL BASE MUD. 09:00 - 12:00 3.00 DR 5 50PRDR PUMP HIGH VISC OIL BASE SWEEP & CONTINUE DISPLACING WATER BASE MUD WITH OIL BASE MUD WHILE DRLG FLOAT TRACK. DIVERTED SPACERS TO APPOLLO HOLDING TANKS. 12:00 - 13:30 1.50 DR I 50PRDR CONTINUED DRILLING FLOAT TRACK & NEW HOLE TO 10,386'.' 13:30 - 15:00 1.50 FT 5 50PRDR iCIRC BU & CONFIRM LITHOLOGY. 15:00- 16:00 1.00 FT I 50PRDR :PERFORMED FIT TEST WITH 12.2 PPG MUD. 1700 PSI AT 8850' TVD = 15.9 PPG EMW. USED 5 BBLS. BLED 4.5 BACK. 16:00 - 00:00 8.00 DR q 150PRDR DRILLING AHEAD F/10,386' TO 10495', SLIDING HRS 2.3, ROTATING HRS 6.3 09/17/97 00:00 - 00:00 24.00 DR q 3512DR CONTINUED SLIDING & ROTATING DRILLING F/10,495-10,865', 2.5 SLIDING HRS, 18.3 HRS ROTATING. =09/18/97 ,00:00 - 01:30 1.50 DR 5 3512DR CIRCULATED BO~-I'OMS UP. 01:30 - 07:00 5.50 DR 4 3512DR POH F/BIT & BHA, STOPPED AND MONITORED WELL F/FLOW SEVERAL TIMES.SWABBING UNTIL SHOE. 07:00 - 10:00 3.00 DR 2 3512DR LAY DOWN BIT, CLEAN FLOOR, L/D MUD MOTOR, 2 MONEL LEAD CLRS, NMSTAB. PICKUP CDR, MUD MOTOR, CHANGE BLADE ON MOTOR & CHANGE SETTING TO 1.5, ORIENT, TEST MWD & MOTOR. 10:00 - 11:00 1.00 DR 7 3512DR REPAIR TORQUE WRENCH CYLINDER HEAD. 11:00- 15:00 4.00 DR 4 3512DR RIHTO 10,332' 15:00 - 16:00 1.00 DR I 3512DR SLIP & CUT DRILLING LINE. . 16:00 - 20:30 4.50 DR. 7 3512DR INSTALL NEW KELLY HOSE & TEST TO 250 & 5000 PSI 20:30 - 21:00 0.50 DR 9 3512DR CALIBRATE ANADRILL CDR & BHI 21:00 - 00:00 3.00 DR z 3512DR WASH F/10415'-10707' W/CDR LOGGING TOOL. 09/19/97 00:00 - 01:00 1.00 DR d 3512DR WASH W/CDR TOOL F/10707'-10865' 01:00 - 00:00 23.00 DR q 3512DR !SLIDE AND ROTARY DRILL F/10865'-11528', ACTUAL SLIDING TIME 6.75 HR, ACTUAL ROTATING TIME 12.25 HR, BHA ASSY DROPPING - 1'/100'.. :09/20/97 00:00 - 09:00 9.00 DR q 3512DR SLIDE & ROTATE F/11528'-11660, 8.0 HR ROTATING, .5 HR SLIDING. 09:00- 09:30 0.50 DR 5 3512DR .CIRCULATE. 09:30 - 11:30 2.00 DR 7 3512DR PUMP OUT OF HOLE 15 STDS TO CSG SHOE. ,, Printed: 10/27/98 3:01:54 PM ,-,. ._. PHILLIPS PETROLEUM CO Page 23 of 29 i'; ~-'V · Operations Summary Report '3,. Gas Cons. Commissi0t'l Legal WelT'N,~ie: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 09/20/97 11:30 - 14:00 2.50 DR 17 3512DR REPAIR TOP DRIVE OIL PUMP PLUG & RECEPTACLE. 14:00 - 15:00 1.00 DR .7 3512DR CHANGE OUT SAVER SLiB & PREFILTER ON TURBINE INTAKES 15:00 - 15:30 0.50 DR 4 3512DR RIH TO 11103', TAG SOLID, ALSO TAGGED @ 10675' &1D940' 15:30 - 19:00 3.50 DR d 3512DR WASH & REAM F/11103-11660,, 18' SOLID FILL ON BTM, PUMP HI VIS PILL, VERY LARGE AMOUNT OF COAL RETURNS. 19:00 - 00:00 5.00 DR q 3512DR SLIDE & ROTATE DRILL F/11660-11748' ,.67 HR SLIDING, 4.5 HR ROTATING. 09/21/97 00:00 - 00:00 24.00 DR q 3512DR DRLD, SLIDING & ROTATING F/11,748'-12,113'. ACTUAL ROTATING TIME 16.2 HR, ACTUAL SLIDING TIME 6.0 HRS. 09/22/97 00:00 - 12:00 12.00 DR q 3512DR DRLG & SLIDING 12115' - 12252' ANGLE DROPPING 1 -1.5 DEG/100' WHILE ROTATING. @ 12252' MOTOR STALLED, PU OFF BOTTOM PUMP PRESSURE INCREASED W/LESS PUMP STKS. TAG BOTTOM, !NO DIFFERENTIAL PRESSURE. 12:00 - 13:00 1.00 DR 5 3512DR :CBU - PREPARE POOH FOR BIT & MOTOR. 13:00 * 17:00 4.00 DR p 3512DR =BACK REAM F/12252-10428' 17:00 - 18:00 1.00 DR 5 ~3512DR CBU BELOW SHOE & PUMP DRY JOB. 18:00- 21:30 3.50 DR 4 13512DR POH 21:30 - 22:30 1.00 DR 2 '3512DR DOWNLOAD CDR DATA, LAY DOWN MOTOR, CDR & MWD. 22:30 - 00:00 1.50 DR 7 3512DR TURN KELLY HOSE AWAY FROM DERRICK LEG, PUT SHEATH ON VIBRATOR 4' MUD LINE BETWEEN RIG SUB BASE AND UTILITY UNIT. 09/23/97 00:00 - 01:00 1.00 DR 8 3512DR PREPARING TO TEST BOPE, DRAIN STACK, PUMP TO APOLLO F/INJECTION. 01:00 - 07:00 6.00: DR 8 3512DR TEST BOPE, 250/5000 PSI, ANNULAR 3500, FLOOR VALVES 250/5000 PSI. 07:00 - 10:00 3.00 DR ~2 3512DR PICKUP CDR, MWD, MOTOR & TEST. 10:00- 13:30 3.50 DR 4 3512DR RIH TO 10332' 13:30 - 14:30 1.00 DR I 3512DR CUT DRLG LINE. 14:30 - 15:00 0.50 DR 4 3512DR RIH, TAG SOLID 11030' 15:00 - 19:30 4.50 DR p 3512DR REAM F/11030-12252'. BRIDGES AT INTERVALS, 18' SOLID FILL.TIGHT @ 10870,10970,11030,11331,11474,11505,11584,11657,11852,12054' 19:30 - 00:00 4.50 DR q 3512DR ROTATING DRILLING F/12252-12378' ACTUAL ROTATING TIME 3.25 !HR. 09/24/97 00:00- 22:3O 22.50 DR q 3512DR DRILLED (RTRY) FR/12378 TO 12952'. DRILLED *C' SAND FR/12923 FT MD, (10858 FT TVD) TO 12952 FT MD, (10882 FT TVD).. 22:30 - 00:00 1.50 DR 5 3512DR CIRCULATE FOR SAMPLES. CONFIRMED SAND IN SAMPLES, NO SIGNIFICANT INCREASE IN GAS. 09/25/97 00:00 - 06:30 6.50 DR q 3512DR DRLG FR/12952 TO 13158 FT. 06:30 - 08:30 2.00 DR q 3512DR SLID FR/13158 TO 13158 FT. 08:30.12:30 4.00 DR q 3512DR DRLG FR/13158 TO 13241 FT. 12:30 * 14:30 2.00 DR q 3512DR SLID FR/13241 TO 13258 FT. 14:30 - 23:00 8.50 DR q 3512DR DRLG FR/13258 TO 13460 FT. 23:00 - 23:30 0.50 DR q 3512DR SLID FR/13460 TO 13465 FT. 23:30 * 00:00 0.50; DR q 3512DR DRLG FR/13465 TO 13477 FT. 09/26/97 00:00- 00:30 0.501 DR !q 3512DR DRLG 13473' - 13480' 00:30- 03:00 2.50 DR 'q 3512DR SLIDE 13480' - 13500* 03:00- 03:30 0.50 DR q 3512DR DRLG 13500'. 13508' 03:30 - 04:00 0.50 RM 3 3512DR SERVICE RIG - TOP DRIVE 04:00- 15:30 11.50 DR q 3512DR DRLG 13508'- 13890' 15:30 - 16:00 0.50 DR q 3512DR =ATTEMPTTo SLIDE 13890'- 13895'. 16:00- 16:30 0.50 DR q 3512DR DRLG 13895*- 13900' , ,,, Printed: 10/27/98 3:01:54 PM ~..:,"',,/.. ~= Z: ': ~.:0 PHILLIPS PETROLEUM CO Page 24 of 29 ; · Operations Summary Report Lega~ VVe~ Name: NORTH COOK ~NLET UN~T-B 000001 Oommon VVe~ Name: North Oook ~n~et Unit B-1 Spud Date: 07/$1/97 Event Name: Odgina~ Dd~ing $~a~t: 0~/05/~? End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 09/26/97 16:30 - 17:00 0.50 DR q 3512DR ATTEMPT TO SLIDE 13900 - 13905' 17:00- 17:30 0.50 DR .q 3512DR DRLG 13905- 13930' 17:30 - 20:30 3.00 DR q 3512DR SLIDE 13930' - 13952' 20:30 - 23:00 2.50 DR ,q 3512DR DRLG 13952'- 14037' '23:00 - 00:00 1.00 DR .q 3512DR SLIDE 14037- 14045' 09/27/97 00:00 - 00:30 0.501 DR q 3512DR CONTINUE TO SLIDE TO 14046' 00:30 - 02:30 2.001 DR q 3512DR DRLG 14046'- 14073' 02:30 - 03:00 0.50 DR z 3512DR SERVICE RIG 03:00 - 08:00 5.00 DR q 3512DR DRLG 14073'- 14228' 08:00 - 09:30 1.50 CR 5 3512DR CBU FOR CORE POINT 09:30 - 10:00 0.50 CR q 3512DR DRLG 14228'- 14255' 10:00 - 11:30 1.50 CR 5 3512DR CBU FOR CORE POINT 11:30- 13:00 1.50 CR q 3512DR D. RLG 14255'- 14268' 13:00 - 15:00 2.00 CR 5 3512DR CBU FOR CORE POINT. PLATFORM SHUT DOWN ON RED PAUL KING. STARTED STANDBY ENGINES & CONT. CIRCULATING & WORK PIPE. 15:00 - 15:30 0.50 CR z 3512DR DRLG 14268'- 14273' 15:30 - 17:00 1.50 CR 5 3512DR CBU @CORE POINT. PUMP WEIGHTED HI-VIS SWEEP, HOLE CLEAN. 17:00 - 00:00 .7.00 CR p 3.512DR BACKREAM CCH F/CORES. BIT DEPTH @ REPT TIME 10956'. REAM TO SMOOTH UP TIGHT HOLE @ 12367' & 10956'. 09/28/97 00:00 - 02:30 2.50 CR 4 3512DR FINISH BACKREAMING TO 9 5/8 SHOE. 02:30 - 04:00 1.50 CR 5 3512DR CIRCULATE BOTTOMS UP. PUMP SLUG. 04:00 - 11:00 7.00 CR 4 3512DR POOH. LD JARS, MOTOR & BIT. 11:00- 12:00 1.00 CR 2 3512EV IPU CORE ASSEMBLY. 12:00 - 16:30 4.50 CR 4 3512EV TIH W/CORE ASSY TO SHOE. PU NEW JARS 16:30 - 17:30 1.00 RM m 3512EV CHANGE OUT HYD KNIFE VALVE ON TRIP TANK FLOW LINE. SPOT TANK ON APOLLO SYSTEM FR/RIG FLOOR DRAINS. 17:~30 - 23:00 5.50 CR 4 3512EV CONT TIH TO 12133'. TIGHT. WORK THRU TIGHT SPOT FR/11133 TO 11160'. TIH, TIGHT AGAIN. HAD TO WASH & REAM FR/12137 - 12229'. CONT TIH TO 13922'. TIGHT AGAIN. WASH & REAM FR/13922 - 14089'. WASH FR/14089 TO BTM @ 14273'. NO FILL ON BTM. 23:00 - 00:00 1.00 CR 5 3512EV PUMP HI-VIS SWEEP AROUND PRIOR TO CUTTING CORE. 09/29/97 00:00 - 02:00 2.00 CR 5 3512EV CIRCULATE HI-VIS SWEEP 02:00 - 02:30 0.50 CR 5 3512EV DROP BALL. PREPARE TO CORE 02:30- 06:30 3.00 CR 1 3512EV CORE 14273'- 14333' 60' 06:30 - 08:30 2.00 CR z 3512EV CBU AFTER CORING; MIX SLUG & PUMP SAME. 08:30 - 19:30 11.00 CR 4 3512EV POOH INTO CSG WITH CORE. TIGHT SPOTS AS FOLLOWS 13484, 13253, 13039, 11697, 11664, 10863, 10728, 10698, 10636. SCREWED INTO EACH STD W/TOP DRIVE. WORK THRU TIGHT SPOTS WITHOUT ROTATING & PUMPING IN ATTEMPT TO KEEP CORE INTACT. 19:30 - 20:30 1.00 CR 12 3512DR LD CORE #1. RECOVERED 60FT F/100% RECOVERY. 20:30 - 21:30 1.00 CR ;2 3512DR PU 2ND CORE ASSY. 21:30 - 00:00 2.50 CR :4 3512DR TIH W/SECOND CORE ASSY. 09/30/97 00:00 - 01:00 1.00. CR 4 3512EV TIH TO 9 5/8' SHOE. 01:00 - 02:30 1.501 RM 3 3512EV CUT DRLG LINE AND ADJUST BRAKES. 02:30 - 05:30 3.00' RM m 3512EV REPAIR STABBING GUIDE IRON R/NECK I REPLACE BUSHINGS IN TOP DRIVE i MAKE UP/BREAK OUT SYSTEM. 05:30 - 09:00 3.50 CR 4 3512EV FINISH TIH W/2ND 60' CORE ASSY. Printed: 10/27/98 3:01:54 PM PHILLIPS PETROLEUM CO Page 25 of 29 Operations Summary Reaort Legal ~e~d~a~me: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/$1/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code' Description of Operations 09/30/97 '05:30 - 09:00 3.50 CR 4 3512EV ;OBSERVED DRAG IN SEVERAL SPOTS BUT CONTINUED Till W/OUT ~WORKING PIPE THROUGH THEM. 09:00 - 10:00 1.00 CR I 3512EV DROP BALL & PUMP DOWN SAME. 10:00 - 14:00 4,00 CR I 3512EV 'CUT 2ND 60' CORE IN SUNFISH FORMATION FROM 14333 TO 14393'. 14:00 - 15:30 1.50 CR 5 3512EV CIRCULATE BO3-1'OMS UP. 15:30 - 00:00 8.50 CR 3512EV POOH W/CORE #2. TIGHT IN NUMEROUS PLACES. HAD TO WORK THOUGH TIGHT SPOTS AT 11665' - 11635' & SEVERAL PLACES BETWEEN 10817 & 10630'. 10/01/97 00:00 - 02:00 2.00 CR 4 3512DR POOH W/2ND 60' SUNFISH CORE. 02:00 - 03:00 1.00 CR 2 3512DR LD 2ND CORE. RECOVERED 60' F/100% RECOVERY. 03:00 - 07:00 4.00 CR 8 3512DR TESTED BOPE. RAMS, STACK & MAN VLVS TO 300/8000 PSI. FLOOR VLVS IBOP ETC TO 300/5000 PSI. ANNULAR TO 300/3500 PSI. 07:00 - 08:30 1.50 'CR 2 3512DR PU INNER ALUMINUM CORE BBL & MU NEW CORE BIT. 08:30 - 13:00 4.50 CR 4 3512DR TIH W! 3RD CORE ASSY TO 9 5/8 SHOE. 13:00 - 14:30 1.50 RM m 3512DR REPAIR LEAKING SEALS ON IRON ROUGHNECK. 14:30 - 16:30 2.00 CR 4 3512DR FINISH TIH - NO FILL. 16:30 - 17:3.0 1.00 CR 5 3512DR DROP BALL, BREAK ClRC & PUMP BALL DOWN. 17:30 - 20:30 3.00 CR I 3512DR CUT 3RD SUNFISH CORE FR/14393 TO'14453'. 20:30 - 22:00 1.50 CR 5 3512DR ClRC BOTTOMS UP. SAMPLES FR/BTM STILL SANDY W/GOOD FLOUR & C-1 THRU C-5 DRILL GAS. 22:00 - 00:00 2.00 CR 4 3512DR PUMP SLUG & POOH W/CORE BBL. STILL NUMEROUS TIGHT PLACES BUT HOLE~ MUCH SLICKER THAN PREVIOUS TRIPS ONLY HAD TO ROTATE UP THRU I SPOT @ 11665 FT. 10/02/97 00:00 - 05:30 5.50 CR ,4 3512DR POOH W/3RD SUNFISH CORE. 05:30 - 07:30 2.00 CR s 3512DR BRK DN CORE BARRELS. 57' RECOVERY 07:30 - 10:30 3.00 DR 2 3512DR MU BHA & PROGRAM MWD. START WEIGHTING UP MUD IN PITS. 10:30 - 12:30 2.00 DR 4 3512DR RIH W/DRLG ASSEMBLY, 12:3~3 - 14:30 1,50 RM m 3512DR REPAIRED BROKEN AIR LINE ON HIGH DRUM CLUTCH. ALSO, ADJUSTED BRAKES. 14:30 - 16:30 2.00 DR 4 3512DR i CONTINUE IN HOLE TO SHOE AT 10,378' 16:30 - 18:.30 2.00 DR 4 3512DR CONTINUE IN HOLE TO 14,170' W/ONLY ONE TIGHT SPOT AT 10,680' & WIPED ONLY THROUGH IT. SLICK HOLE OTHERWISE. 18:30 - 23:30 5,00 LG 5 3512DR WASHING & REAMING FROM 14,190' TO 14,453' FOR MWD LOGS. 23:30 - 00:00 0.50 DR q 3512DR DRLG FR/14453 TO 14468'. 10/03/97 00:00 - 00:00 24,00 DR q 3512DR DRILLING (RTRY) FROM 14,468' TO 14,888', 10/04/97 00:00 - 07:00 7.00 DR q 3512DR DRILLING TO 14,936' MD, 12,415' TVD. 07:00 - 08:00 1.00 DR 5 3512DR CIRCULATE BU FOR SAMPLES. 08:00 - 10:30 2,50 DR q 3512DR CONT DRILLING F/14,936' TO 14,972' MD, 12,443' TVD, LOOKING FOR CORE POINT, 10:30 - 11:30 1,00 CR 5 3512EV ClRC FOR SAMPLES. 11:30 - 19:00 7,50 CR p '3512EV BK REAM OUT OF HOLE TO CSG SHOE. 19:00 - 20:30 1.50 CR 5 3512EV CIRCULATE BOTTOMS UP. PUMPED SLUG. 20:30 - 21:30 1.00 RM 3 3512EV SLIP & CUT 114' DRLG LINE. 21:30 - 22:30 1.00 RM m 3512EV RIG REPAIR. REPLACE UMBILICAL CONNECTOR ON TOP DRIVE. 22:30 - 00:00 1.50 CR 4 3512EV POOH FOR CORE BBL. __ Printed: 10/27/98 3:01:54. PM PHILLIPS PETROLEUM CO Page 26 of 29 · :, .... Operations Summary Report ,A~,uh0: ~.:~ ~ Legal Well Name: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31197 Event Name: Original Drilling Start: 06~05~97 End: Contractor Name: Unocal / Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub Co Phase Code Description of Operations 10/05/97 00:00 - 04:00 4.00 CR 1 3SI2EV CONTINUE POOH. :04:00 - 05:30 1.50 CR I 3512EV PLUG MWD PORT & REMOVE SLEEVE F/MOTOR. LD MOTOR. 05:30 - 06:30 1.00 CR 1 3512EV CLEAR & CLEAN FLOOR. 06:30 - 13:30 7.00 CR 2 3SI2EV PU & MU 90' CORE ASSEMBLY & RIH W/SAME. HAD TO WASH & REAM PAST TIGHT HOLE F/10,678' TO 10,7689 CONTINUED WORKING PIPE ONLY WITHOUT WASHING & REAMING THROUGH TIGHT HOLE FROM 10,768' TO 11,078'. CONT IN HOLE. 13:30 - 17:00 ~.50 CR p 3§I2EV WASH & REAM VERY TIGHT HOLE FROM 14,372' TO 14,972' TD. 17:00 - 00:00 7.00 CR 1 3512EV CORE N FORELAND SAND FR/14972 TO 15013'. 10106197 00:00 - 04:00 4.00 CR 1 3§I2EV CONTINUE CORING F/15,013' TO 15,0S6' 04:00 - 06:00 2.00 CR 1 aSlAEV ClRC BU. 06:00 - 08:00 2.00 RM m 3SI2EV MIXED & LOST SLUG THROUGH FAULTY PIT VALVE. REPAIRED I VALVE & REMIXED & PUMPED SLUG. 08:00 - 15:00 7.00 CR 4 13512EV POOH W/CORE ASSEMBLY. WORKED UP THROUGH TIGHT HOLE AT 14,400' & FROM 11,078' UP TO 10,768% CONTINUE OUT OF HOLE W/CORE. 15:00 - 16:30 1.50 CR 2 3512EV LD CORE & CORE BBL. RECOVERED 74' OF CORE FOR 88% RECOVERY. 16:30 - 19:00 2.50 RM m 3512EV RIG REPAIR. REPAIR TOP DRIVE OILER PUMP. 19:00 - 00:00 5.00 DR 2 3512DR PU 1.15 DEC ADJ XP MOTOR, MU BIT #15. MU MWD/CDR TOOLS. ANADRILL UNABLE TO REPROGRAM CDR TOOL. UNABLE TO COMMUNICATE BETWEEN CDR & PC. LD CDR & PU STANDBY TOOL. UNABLE TO COMMUNICATE W/IT TOO. AFTER CONSULTING ANADRILL MWD SUPV THE DECISION WAS MADE TO RUN TOOL AS IS SINCE PREVIOUS PROGRAM SHOULD SUFFICE 10/07/97 00:00 - 00:30 0.50 DR 7 10C2DR FINISH CHANGING OUT CDR TOOL. 00:30-04:00 3.50 DR 4 10C2DR . RIH TO 9 5/8" SHOE AT10,378'. 04:00 - 05:00 1.00 RM c 10C2DR ' SLIP & CUT 76' OF DRILL LINE. 05:00 - 07:00 2.00 DR 4 10C2DR CONTINUE IN HOLE TO 14,912'. HAD TO WORK THROUGH TIGHT SPOT F/10,768' TO 10,968'. 07:00 - 08:30 1.50 DR q !10C2DR WASHED & REAMED & LOGGED CORE SECTION W/MWD TO BTM AT 15,056'. 08:30 - 00:00 15.50 DR q 10C2DR DRLG FR/15056 - 15308'. 10/08/97 00:00 - 23:00 23.00 DR q 3512DR CONTINUE DRILLING F/15,308' TO 15,500' T.D.. 23:00 - 00:00 1.00 DR 5 3512DR CIRCULATE BOTTOMS UP, PRIOR TO POH TO LOG. 1.0/09/97 00:00 - 00:30 0.50 DR 5 3512DR CONTINUE CIRC BOTTOMS UP. 00:30 - 09:00 8.50 DR 4 3512DR BACKREAM F/15,500' TO 14,015'. TIGHT HOLE RELATED TO BACK REAMING. CONTINUED PUMPING ONLY TO CSG SHOE AT 10,378'. 09:00 - 10:30 1.50 DR 5 3512DR ClRC BU & CLEAN FLOOR. 10:30 - 16:30 6.00 DR 4 3512DR CONTINUE POOH & L/D BHA. 16:30 - 19:30 3.00 WC 8 3512DR PULL WEAR BUSHING & TEST BOP'S. STATE WITNESSING WAIVED BY BLAIR WONDZELL W/AOAGC AT 10:00 AM ON 10-07-97, SET WEAR BUSHING. 19:30 - 21:30 2.00 LG I 3512EV RU SCHLUMBERGER. 21:30 - 00:00 2.50 LG 1 3512EV !LOG RUN #1, AIT/DSl/GR/AMS ~10/10/97 00:00 - 09:30 9.50 LG I 3512EV 'FINISHED LOGGING W/AIT, DSI,GR,AMS ,, Printed: 10/27/98 3:01:54. PM .... ,,, ,.~ .~: ~,~:~. PHILLIPS PETROLEUM CO Page 27 of 29 ., . co miss ot; Operations Summary Report ir.-~'-' ;~:i '~ · ~,r, ~, '~'~'~iWe~l~'l~.~;:~ NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: 07/31/97 Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: ~ Rig Name: Rig Number: 428 Date I From - To Hours Sub Co Phase Code Description of Operations 10/10/97 00:00 - 09:30 9.50 LG I 3512EV TO 15,503' WLM. POOH & LB TOOLS. 09:30- 17:30 8.00 LG !1 3512EV MU & RIH W/DEN,NEUTRON FOR RUN #2. TOOL HANGING UP AT VARIOUS DEPTHS. WORKED TOOL INTO CASING & CONTINUED OUT OF HOLE. LiD TOOL. 17:30 - 19:00 1.50 LG 2 3512EV RIG DOWN SCHLUMBERGER 19:00 - 20:00 1.00 LG 4 3512EV LAY DOWN MONEL DRILL COLLARS. 20:00 - 00:00 4.00 LG 4 3512EV RIH F/WIPER TRIP CONDITIONING RUN. 10/11/97 00:00 - 03:00 3.00 LG 4 3512DR RIH F/WIPER TRIP, FILL PIPE @ SHOE, P/U 6 JTS D.P., RIH, BRIDGES ,OR LEDGES @ 10518,10958,11313,RIH 'TO 15427 & REAM TO BTM @ ' 15500', 2' FILL. 03:00 - 05:00 2.00 LG 4 3512DR CIRC BTMS UP & PUMP DRY JOB. 05:00 - 08:30 3.50 LG 4 !3512DR POH TO SHOE, TIGHT @ 12314,12144,11524,11366,11295,11215,10964,10843,10784,10722,1069 1' 08:30 - 12:30 4.00 LG 4 3512DR CONTINUE POH F/SHOE 12:30 - 21:30 9.00 LG I 3512DR R/U.SCHLUMBERGER, LOG RU.N #3 RFT/GR, TOOL STOPPED @ 10486' WLM, POH, RIH LOG RUN #4 DIPMETER/GR, STOPPED @ 10456' WLM, POH RIG DOWN SCHLUMBERGER. 21:30 - 00:00 2.50 WO r .351~DR WAIT ON SCHLUMBERGER TOOLS & PERSONNEL F/DRILL PIPE CONVEYED LOGGING. OFFLOADING MUD MATERIALS, DRILL CLRS, ETC ONTO WORKBOAT. 10/12/97 00:00 - 10:00 10.00 WO r 3512EV WAITING ON SCHLUMBERGER TLC ENGINEER, DELAYED BY INABILITY TO FLY AT NIGHT: PERFORMED GENERAL RIG MAINTENANCE & CUT DRILL LINE WHILE WAITING. 10:00 - 16:00 6.00 FT 6 3512EV SCHLUMBERGER CUT ROPE SOCKET. REHEADED SAME & TESTED. HELD SAFETY MEETING & PU TOOLS. HAD TROUBLE POWERING UP TOOLS. REPAIRED BAD CONNECTION. 16:00 - 22:00 6.00 FT 4 3512EV RIH W/HWDP. LD JARS. FILLED DP AT 3299', 6570', 9372'. CONTINUE IN HOLE W/RI=I- ON DP TO CSG SHOE. 22:00 - 00:00 2.00 FT 2 3512EV PU SIDE ENTRY SUB & RUN INSIDE DP W/WIRELINE. BROKE ClRC & LATCHED UP. 10/13/97 00:00 - 01:30 1.50 LG 7 3512EV ATTEMPTED TO INITIALIZE TOOL & FUNCTION SAME. TOOL NOT PRESSURING UP TO SET. 01:30 - 03:00 1.50 LG 7 3512EV PULL WIRE OUT OF DP & RD SIDE ENTRY SUB. RD SCHLUMBERGER. 03:00 - 07:00 4.00 LG 7 3512EV POOH WITH RFT. 07:00 - 08:00 1.00 LG 2 3512EV L/D TOOLS. SCHLUMBERGER TESTED TOOLS ON SURFACE FINDING !TOOLS TO NOT FUNCTION. VALVES NOT CLOSING TO ALLOW TOOL !TO PRESSURE UP. 08:00 - 13:30 5.50 LG 4 3512EV MU & RIH W/BIT, & STRING REAMER. NOTE: HAD ABANDON PLATFORM DRILL & CREW PERFORMED TRIP DRILL WHILE STILL IN CSG. WELL SECURED W/GOOD RESPONSE TIME. 13:30 - 00:00 10.50 LG 4 '3512EV SCREW IN W/TOP DRIVE AT CSG SHOE. WASH & REAM F/CSG SHOE TO 12,264' W/STRING REAMER. 10/14/97 00:00 - 13:30 13.50 LG 4 3512EV CONTINUE WASHING & REAMING TO BTM AT 15,500' W/STRING REAMER. NO FILL. 13:30 - 14:00 0.50 LG 5 3512EV CIRCULATE CUTTINGS UP HOLE. Printed: 10/27/98 3:01:5,4 PM :...',' .,., ,,. ~:,' .-, lc.':.;:~,~ ~,,, PHILLIPS PETROLEUM CO Page 28 of 29 .... '., :x .... · ....... Operations Summary Report Legal Well Name: NOFI'rH COOl( INLE'T' UNI'r-B 000001 Common Well Name: North Cook Inlet Unit B-1 8pud Date: 07/34/97 Event Name: Original Drilling 8tart: 06/05/9? End: C;ontractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 Date From - To Hours Sub CoIPhase Code Description Operations 10/14/97 14:00 - 21:30 8.00 LG 4 3512EV PUMP OUT OF HOLE TO CSG SHOE. 21:30 - 22:30 1.00 LG 5 3512EV CBU. 22:30 - 00:00 1.50 LG 4 '3512EV POOH TO RUN RFT. 10/15/97 00:00 - 03:00 3.00 LG 4 3512EV FINISH POOH. L/D JARS, STRING REAMER, & BIT. 03:00 - 04:00 1.00 LG 2 3512EV RU SCHLUMBERGER. 04:00 - 12:30 8.50 LG I 3512EV RIH W/RFT ON WIRELINE & LOG W/SAME. UNABLE TO GET PRESSURES. 12:30 - 15:00 2.50 LG 2 3512EV POOH & RD SCHLUMBERGER. 15:00 - 21:00 6.00 PA 4 3512EV MU & RIH W/15 JTS (460.83') OF 2 7/8' CEMENTING STINGER. TIH W/5' DP TO CSG SHOE. '21:00 - 00:00 3.00 PA I 3512EV CLEAN 2 MUD PITS FOR SPACER & CEMENT MIX WATER. 10/16/97 00:00 - 08:00 8.00 PA I 60ABNT CLEANING 2 MUD PITS FOR SPACER & MIX WATER. MIX WEIGHTED SPACER. 08:00 - 12:00 4.00 PA 4 60ABNT TIH TO TD @ 15500' 12:00- 13:00 1.00 PA 5 60ABNT 'CBU O15500' ClRC & CONDTION MUD 13:00 - 13:30 0.50 PA 0 60ABNT SAFETY MEETING PRIOR TO SETTING CMT PLUG. RU HOWCO TEST LINES 3000#. 13:30 - 14:30 1.00 PA I 60ABNT HOWCO PUMPED 20 BBL SPACER, 261 SXS CEMENT + .2% CFR + .08% HR-5 MIXED @15.8# 7 BBLS SPACER DISPLACED W/14.8# MUD FOR BALANCED PLUG 15500'- 14850' 14:30 - 15:30 1.00 PA 4 60ABNT POOH 10 STD TO 14560' 15:30 - 16:30 1.00 PA I '60ABNT BREAK CIRCULATION WITH RIG PUMP. SWITCH TO HOWCO PUMP 2ND CMT PLUG. 20 BBLS SPACER, 282 SXS CMT + .2% CFR + .08% HR-5 MIXED ~15.8#, 7 BBLS SPACER DISPLACED W/14.8# MUD FOR BALANCED PLUG 14560'- 14150' 16:30 - 19:30 3.00 PA 4 60ABNT POOH 10 STDS. PUMP THRU DP TO CLEAR ANY CMT. CON'T POOH INTO CSG @ 10241' 19:30 - 00:00 4.50 PA 5 60ABNT WOC. CBU. CLEAN RIG FLOOR. CUT DRLG LINE 145'. PREPARE TIH TO TAG CEMENT PLUG FOR STATE REQUIREMENT. 10/17/97 00:00 - 02:00 2.00 PA 4 60ABNT TIH TAG 2ND CMT PLUG @ 13564' SET DOWN 20000# 3 TIMES. BREAK CIRC TAG PLUG W/20000#, NO PUMP OFF. TAG PLUG REQUIRED BY ALASKA OIL & GAS COMMISSION. 02:00 - 03:30 1.50 PA 4 60ABNT POOH TO 10800' 03:30 - 04:30 1.00 PA 5 60ABNT CIRCULATE & CONDITION MUD PRIOR TO SE'I'rING CEMENT PLUG ACROSS CSG SHOE. 04:30 - 06:00 1.50 PA I !60ABNT RU HOWCO, TEST LINES 2700#, OK. PUMP 30 BBLS SPACER, 535 SXS CMT +.7% CFR-3 + .1% HR-5 MIXED @17.0# 11 BBLS SPACER DISPLACED W/14.8# MUD FOR BALANCED PLUG 10~00' - 10270'. CSG SHOE @ 10376'. 06:00.07:00 1.00 PA 4 60ABNT POOH 15 STDS TO 9397' 07:00.14:30 7.50 PA 5 60ABNT WOC- CBU, CONDITION MUD FOR TEMPORARY ABANDONMENT. 14:30 - 15:30 1.00' PA 4 60ABNT TIH TAG CMT PLUG @ 10029' SET DOWN 10000# 3 TIMES. TAGGING PLUG REQUIRED BY ALASKA OIL & GAS COMMISSION. PBTD 10029 MD 8605 TVD. 15:30 - 17:30 2.00 PA 4 60ABNT , POOH TO 5" HWDP 17:30 - 18:30 1.00 PA ~2 60ABNT 'CLEAN OIL BASE MUD FROM MOUSE HOLE TO LD 5" HWDP 18:30 - 20:30 2.00 PA 2 60ABNT LD 5' HWDP 20:30 - 22:30 2.00 PA 4 60ABNT POOH TO 2 7/8" CEMENT 'STINGER 22:30 - 00:00 1.50 PA 2 60ABNT · LD 2 7/8"' TBG. 10/18/97 00:00 - 00:30 0.50 PA 2 60ABNT LD 2 7/8' TBG & HANDLING TOOLS 00:30 - 01:00 0.50 PA 2 60ABNT PULL WEAR BUSHING 01:00 - 04:00 3.00 PA z ~60ABNT TRANSFER OIL MUD FROM RIG PITS TO PLATFORM PITS FOR STORAGE. Printed: 10/27/98 3:01:54 PM · ? PHILLIPS PETROLEUM CO Page 29 of 29 Operations Summary Report Legai~ll:N~me: NORTH COOK INLET UNIT-B 000001 Common Well Name: North Cook Inlet Unit B-1 Spud Date: .07/31/97 ~Event Name: Original Drilling Start: 06/05/97 End: Contractor Name: Unocal/Pool Rig Rig Release: 10/21/97 Group: Rig Name: Rig Number: 428 · [ From - To Hours Sub Co Phase Code Description of Operations Date 10/18/97 04:00 - 00:00 20.00 PA I 60ABNT CLEANING OIL BASE FROM RIG & MUD PITS. 10/19/97 00:00 - 08:00 8.00 PA I 80ABNT CLEANING OIL BASE MUD FROM RIG AND MUD PITS. 08:00 - 16:00 8.00 PA 2 60ABNT ND BELL NIPPLE, BOP, RISERS. ND VETCO-GREY NT-~ CONNECTOR, NU NT-2 CONNECTOR W/VALVE. TEST TO 500#,OK. 16:00 - 00:00 8.00 PA 1 60ABNT CONTINUE CLEANING PITS & RIG. 10/20/97 00:00 - 00:00 24,00 MV z 70DMOB CONTINUE CLEANING RIG & PITS, ***ESTIMATE BE DONE CLEANING PITS 1200 HRS. 10/21/97 00:00 - 18:00 18.00 MV z 70DMOB CLEAN PITS, FILLED W/SEA WTR & CIRCULATED THRU MUD PIT SYSTEM, CLEAN OFF RESIDUAL OIL, RU JACKS TO SKID RIG. RD SEISMIC CLAMPS. 18:00 - 23:00 5.00 MV z 70DMOB EMPTY MUD PITS, PUMP SEA WTR TO APOLLO FOR INJECTION. MOP TANK BOTTOMS. 23:00 - 00:00 1.00 MV z 70DMOB SURVEY RIG IN FINAL PREPARATION TO SKID RIG TO A-12. RELEASE RIG FROM NClU B-1 @0000 HRS 10/21/97 Printed: 10/27/98 3:01:54 PM PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY November 10, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING North Cook Inlet Unit "B" No. 1 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Ms. Wendy Mahan Enclosed for your review is a copy of Form 10-404 (Report of Sundry Well Operations). The referenced well has been used for cuttings re-injection. The cuttings were disposed of through the 2-3/8" tubing string attached to the 13-3/8" ' surface casing. This report is submitted as the final report for injection operations into the Sterling Formation via the NCIU B-1 well. The NCIU B-1 well was utilized for disposal operations from September 12, 1997 to November 4, 1998. The report contains the cumulative volume of drill cuttings disposed and other pertinent information. Should you have any questions, concerns or require any additional information, please contact Shonna Boyer at (713) 669-7980. Regards, N. P. Omsberg North America Drilling Manager enc: cc: P. R. Dean S. M. Boyer L. L. Lyon "J. P. Johnson (E)D. K. Taylor '~--!'~0 ~ ~ ~~~~ ~ .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Alter Casing 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South Bellaire, Texas 77401 4. Location of well at surface: 1249' FNL & 980' FWL At top of productive interval: At effective depth: At total depth: 2513' FSL & 1520' FEL 11. Present well condition summary: Total Depth: measured true vertical Plugging Other X {Cuttings Reinjection) Tyonek Platform Leg 1 Slot 4 Sec 6-T11N-RO9W Sec 12-T11N-R1OW Perforate Pull Tubing I5. Datum elevation (DF or RKB) RKB 132 6. Unit or Property Name North Cook Inlet Unit "B" J7' wellNumber N°'l I 8. Permit Number / Approval Number 97-115 I9. APl Number 50-883-20093 10. Field / Pool ICook Inlet 6,650 feet 2,895 feet Plugs (measured) Feet Effective Depth: measured 6,170 feet true vertical 2,580 feet Junk (measured) Casing: Length Size Structural 368' 30" Conductor 2579' 20" Surface 3760' 13-3/8" Intermediate 10376' 9-5/8" Production Liner 6576' 5" Cemented Measured Depth Driven 407' YES 2579' YES 3760' YES 10376' YES 16,650' True Vertical Depth 407' 2571' 3521' 8846' 12,895' Perforation Depth: measured 3500' - 3530' true vertical 3307' - 3337' Tubing (size, grade and measured depth) 2-3/8", 4.7 Iblft, N-80, CS Hydril set at 3600' Packers and SSSV ( type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Cumulative Volume Disposed through Nov. 4, 1998: Average Surface Injection Pressure: Average Surface Injection Rate: ORIGINAL 134,325 bbls 1494 psi 1.4 bpm 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: ne~/'~'~:;~-'~~? "c~ ~z~'';'''' '~"'~" Form 10-404 Rev. 12/01/85 ~ Submit in Duplicate JUL-06-1998 13:19 PHILLIPS PETROLEUM ?136693?55 P.0270~ PHILLIPS PETROLEUM HOUr?ON, TEXAS 77251-1967 BOX 1~? NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY July 6, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLII:~ BUILDING North Cook Inlet Unit "B;' No. 1 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Ms. Wendy Mahan The referenced well has been used for cuttings re4njection. The cuttings are disposed of through the 2-318" tubing string attached to the 13-318" surface casing. These strings are cemented to surface. This update is for the volume of drill cuttings disposed of into this well. As of May 31, 1998, the total volume injected was 80,330 barrels. Should you have any questions, concerns or require any additional information, please contact me at (713) 669-7980. Regards, Shonna Boyer Drilling Engineer 06 1998 Ala~,a0il & Ga~Cons. Commi~on TOTAL P. O2 DATE: OPERATOR: FIEf_n: May 8, 1998 PHILLIPS PETROl ;UM COMPANY North Cook Inlet WEB B NAME: NClU B #1-ST COUNTY: Kenai STATE: Alaska SECTION: 6 TWNSP: 11N RANGE: 9W APl NUMBER: 50-883-20093-01 DISTRIBUTION LIST Well Records-Bartlesville (1), films (1) Technical Records-B-2, Bellaire (1), films (1) Well File-1141, Bellaire (1) Paul Dean (1) ARCO Alaska, Inc. (~1') Alaska Dept of Natural Resources (~1) Alaska O&G Conservation Commission (~1) I ~ I1~ LOGGING DEPTH # OF # OF # OF ROLLED TYPE LOG DATE SCAL_F LOGGED ORIG. PRINTS FILMS VELLUM MUD LOn_$: Formation Eval Log 2" TVD 2/23198 Z' 12942 7 1 MWD Integrated Fm Eval Log 2" TVD 2/23198 Z' 12942 7 1 Formation Eval Log 2" MD 2/23198 2" 16720 7 1 MWD Integrated Fm Eval Log 2" MD 2/23198 2" 1672..~. ..... . 7 1 Drilling Data Log DDL 2" MD 2123138 Z' 1672(~ 7 I Should you have any questions, please contact: Donna Hole Phillips Petroleum Company P.O. Box 1967, Houston, TX 77251-1967' 713-669-3722 PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY February 19, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING North Cook Inlet Unit "B" No. 1 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Gentlemen: Enclosed for your review are two copies of Form 10-404 (Report of Sundry Well Operations). The referenced well has been.used for cuttings re-injection. The cuttings are disposed of through the 2-3/8'" tubing string attached to the 13-3/8" surface casing. This report contains the cumulative volume of drill cuttings disposed and the daily average injection pressure during 1997. Should you have any questions, concerns or require any additional information, please contact Shonna Boyer at (713) 669-7980 or Paul Dean at (713) 669- 3502. Regards, enc: cc: J. W. Konst J. R. Soybel ® W. L. Carrico. P. R. Dean ® S. M. Boyer'® Well File N. P. Omsberg North America Drilling Manager REPORT OF SUNDRY 1. Operations Performed: Operation Shutdown Alter Casing 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South Bellaire, Texas 77401 4. Location of well at surface: 1249' FNL & 980' FWL At top of productive interval: 2830' FSL & 5044' FEL At effective depth: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS'SlON WELL OPERATIONS Stimulate Plugging Perforate Other X {1997 Cuttings Reinjection Summary) Tyonek Platform Leg I Slot 4 Sec 6-T11N-RO9W Sec 7-T11N-R09W At total depth: 2513' FSL & 1520' FEL 11. Present well condition summary: Total Depth: measured true vertical Sec 12-T11N-RIOW 7,480 feet 6,387 feet Plugs (measured) Pull Tubing 5. Datum elevation (DF or RI(B) RKB 132 Feet 6. Unit or Property Name North Cook Inlet Unit "B" 7. Well Number 8. Permit Number / Approval Number 97-115 9. APl Number 50-883-20093 10. Field / Pool Cook Inlet PBTD: 10,430' MD 8,882' TVD Effective Depth: measured 5,500 feet true vertical 2,878 feet Junk (measured) Casing: Length Size Structural 368' 30" Conductor 2579' 20" Surface 3760' 13-3/8" Intermediate 10376' 9-5/8" Production Liner Cemented Measured Depth Driven 407' YES 2579' YES 3760' YES 10376' True Vertical Depth 407' 2571' 3521' 8846' Perforation Depth: measured 3500' - 3530' true vertical 3307' - 3337' Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) 2-3/8", 4.7 Ib/ft, N-80, CS Hydril set at 3600' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Cumulative Volume of Cuttings Disposed through Dec. 31, 1997: Cumulative Volume of Sea Water Disposed through Dec. 31, 1997: Average Surface Injection Pressure: ~.~, .~ ~,~:" ~,!~ C 2 ..-, ,, ~a~... ' "=r ~ ~ r,:.,'C= -'. - ..,. ~'_'~.~.., 8790 bbls 26375 bbls 1593 psi' 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: Signed Title Form 10-404 Rev. 12/01/85 c,- Submit in Duplicate STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY 1. Operations Performed: Operation Shutdown Alter Casing 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South Bellaire, Texas 77401 WELL OPERATIONS Stimulate Plugging Perforate Other .X, {1997 Cuttings Reinjection Summary) 4. Location of well at surface: Tyonek Platform Leg I Slot 4 Pull Tubing 5. Datum elevation (DF or RKB) RKB 132 6. Unit or Property Name North Cook Inlet Unit "B" 7. Well Number 1249' FNL & 980' FWL At top of productive interval: 2830' FSL & 5044' FEL At effective depth: At total depth: 2513' FSL & 1520' FEL 11. Present well condition summary: Total Depth: Sec 6-T11N-RO9W Sec 7-T11N-RO9W Sec 12-T11N-RIOW measured 7,480 feet true vertioal 6,387 feet Plugs (measured) Feet No. 1 8. Permit Number ! Approval Number 97-115 9. APl Number 50-883-20093 10. Field / Pool Cook Inlet PBTD: 10,430' MD 8,882' TVD Effective Depth: measured 5,500 feet true vertical 2,878 feet Junk (measured) Casing: Length Size Structural 368' 30" Conductor 2579' 20" Surface 3760' 13-3/8" Intermediate 10376' 9-5/8" Production Liner Perforation Depth: measured 3500' - 3530' Cemented Driven YES YES YES Measured Depth 407' 2579' 3760' 10376' True Vertical Depth 407' 2571' 3521' 8846' ORIGINAL true vertical 3307'-3337' Tubing (size, grade and measured depth) 2-3/8", 4.7 Ib/ft, N-80, CS Hydril set at 3600' Packers and SSSV ( type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Cumulative Volume of Cuttings Disposed through Dec. 31, 1997: !Cumulative Volume of Sea Water Disposed through Dec. 31, 1997: Average Surface Injection Pressure: 8790 bbls 26375 bbls 1593 psi 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: Signed ~~.- Title "'Form 10-404 Rev. 12/01/ PETROLEUM SERVICES PHILLIPS PETROLEUM COMPANY NORTH COOK INLET UNIT B-01 COOK INLET FIELD ALASKA CORE LABORATORIES FILE NO. 57151-18618 CORE PHOTOGRAPHS BOX FORMAT 14273.0 to 14451.5 14972.0 to 15046.5 Prepared by Core Laboratories 5630 Guhn Road Houston, Texas 77040 January, 1998 Core Laboratories, Inc. 5630 Guhn Road, Houston, Texas 77040, (713) 460-8113, Fax (713) 460-$211 FIELD: North Cook Inlet WELL NAME: NClU B #1 CNTY/PRSH/STATE: Kenai, Alaska APl NUMBER: 50-883-20093 SECTION: 6 TWNSP: 11N RANGE: 9W 1cc: Well File 1cc: Bartlesville File .. DISTRIBUTION LIST 1cc: Arco 1cc: Alaska O&G Cons Comm 1cc: Dept Natl Resources Alaska DEPTH #OF #OF #OF ;ROLLED DATE DATE , . TYPE LOG RUN # DATE SCALE LOGGED ORIG. PRINTS' FILMS VELLUM REC'D DIST. NOTES Core Photographs - Box F ,ormat - Whole Binder 1/1/98 6 2/19/98 2/20/98 , ,, , ,' , , · ,, , ,, , p:\excel\logins\nciu\NClU B #1a.xls/dpo 02/20/98 4:32 PM PHILLIPS PETROLEUM COMPANY North Cook Inlet Unit B-01 Cook Inlet Field Alaska Core Laboratories File No. 57151-18618 Print1 De~h Column Fmm To I 14273.0 14276.0 2 14276.0 14279.0 3 14279.0 14282.0 4 14282.0 14285.0 5 14285.0 14288.0 6 14288.0 14291.0 Print2 De~h Column Fmm To 1 14291.0 14294.0 2 14294.0 14297.0 3 14297.0 14300.0 4 14300.0 14303.0 5 14303.0 14306.0 6. 14306.0 14309.0 Print3 De~h Column Fmm To 1 14309.0 14312.0 2 14312.0 14315.0 3 14315.0 14318.0 4 14318.0 14321.0 5 14321.0 14324.0 6 14324.0 14327.0 Print4 De~h Column Fmm To 1 14327.0 14330.0 2 14330.0 14333.0 3 14333.0 14336.0 4 14336.0 14339.0 5 14339.0 14342.0 6 14342.0 14345.0 Print5 De~h Column From To I 14345.0 14348.0 2 14348.0 14351.0 3 14351.0 14354.0 4 14354.0 14357.0 5 14357.0 14360.0 6 14360.0 14363.0 Print6 De~h Column From To 1 14363.0 14366.0 2 14366.0 14369.0 3 14369.0 14372.0 4 14372.0 14375.0 5 14375.0 14378.0 6 14378.0 14381.0 Print7 De~h Column From To 1 14381.0 14384.0 2 14384.0 14387.0 3 14387.0 14390.0 4 14390.0 14393.0 5 14393.0 14396.0 6 14396.0 14399.0 Print8 De~h Column From To ,1 14399.0 14402.0 2 14402.0 14405.0 3 14405.0 14408.0 4 14408.0 14411.0 5 14411.0 14414.0 6 14414.0 14417.0 Print 9 Depth Column From To ,, 1 14417.0 14420.0 2 14420.0 14423.0 3 14423.0 14426.0 4 14426.0 14429.0 5 14429.0 14432.0 6 14432.0 14435.0 Print 10 Depth Column From To 1 14435.0 14438.0 2 14438.0 14441.0 3 14441.0 14444.0 4 14444.0 14447.0 5 14447.0 14450.0 6 14451.0 14451.5 Print 11 Depth Column From To 1 14972.0 14975.0 2 14975.0 14978.0 3 14978.0 14981.0 4 14981.0 14984.0 5 14984.0 14987.0 6 14987.0 14990.0 Print 12 Depth Column From To 1 14990.0 14993.0 2 14993.0 14996.0 3 14996.0 14999.0 4 14999.0 15002.0 5 15002.0 15005.0 6 15005.0 15008.0 Print 13 Depth Column From To I 15008.0 15011.0 2 15011.0 . 15014.0 3 15014.0 15017.0 4 15017.0 15020.0 5 15020.0 15023.0 6 15023.0 15026.0 Print 14 Depth Column From To I 15026.0 15029.0 2 15029.0 15032.0 3 15032.0 15035.0 4 15035.0 15038.0 5 15038.0 15041.0 6 15041.0 15044.0 Print 15 Depth Column From To I 15044.0 15046.5 Print 1 14273.0- 14291.0 Print 2 14291.0- 14309.0 Print 3 14309.0- 14327.0 14291.0. 14300.0 PHILLIPS PETROLEUM COMPANY "NORTH COOK INLET UNIT" B-01 COOK INLET FIELD ALASKA ~.,~,,, ,..?:,., ~4.~0~ C ?,.';it9.0 ft .. ~: '-... -... '...'.'. ~ ,. · ~_' ; ~; - ii: ! _~-. , !..'. .':.. 143( 143180 PHILLIPS PETROLEUM COMPANY 'NORTH COOK INLET UNIT' B 01 COOK INLET FIELD ALASKA Ii., . 143~7 0 14:~3G Pt41LLIPS PETROLEUM COMPANY ~r "NORTH COOK INLET UNIT' B-01 ; COOK INLEt FIELD i ALASKA - 14:1.36.0, 1434 Print 4 14327.0 - 14345.0 Print 5 14345.0 - 14363.0 PHILLIPS PETROLEUM COMPANY 'NORTH COOK INLET UNIT" B-01 COOK INLET FIELD ALASKA 14372.0 PHILLIPS PETROLEUM COMPANY "NORTH COOK INLET UNIT' B.01 COOK INLET FIELD ALASKA ; 1,1;/ ii1 ii 1 i1,11 i~ ,, :.-, .':,., .,:? ... Print 6 14363.0- 14381.0 Print 7 14381.0- 14399.0 PHILLIPS PETROLEUM COMPANY "NORTH COOK INLET UNIT" B.01 COOK INLET FIELD ALASKA ..... ,:: .,,, ~,.,?,,,f,.~ ~.,,. ~,,..,,,,,,~ ,,!~,.,,,, ........... -:- ..::.,, .. ,; _~'_:-'. _, .~ _ - ~; _ .--_ ~..,, ~;,, _.': -.--....-- _ ;.?,. :- o ?,;' .-; ."r-';__.; -..:. :'; _; ;' _; --- :..--. __ ; _..-; .~ ~ ;:, :~.. . -J ....~-_,.....--.:.';.~--:~. · ;_"'. : ' :;% t"-.- - - - $.~ -~'.---~ ..:.- . . . -,, : ._,;_,.:.~%?:.~:-._.4:¢%-~,;.:~ ~--. ...-_ ;.-~.'-' .~"'-'-', ~.-- ;o ._.::. '; . ,. ,%'--. ._. . '~':'- ' :' · ..'- ~:- ... _ - .... . ,- :.' .-',,,; i .... , ..... ' ;,i,:*;O" ..:...' ,. ..'. "--,:..~ ._;:,- -.:; .,-'.-;.~"'3~:',.--;,-_-'.-;. '::'"'"" '" :,"- . ,,..' :, -%,: .. '-' .-. '5-'"-_";'_:'::¥' Print 8 14399.0 - 14417.0 Print 9 14417.0- 14435.0 14J9~.0. 14408.0 PHILLIPS PETROLEUM COMPANY 'NORI'H COOK INLET UNIT' B,01 COOK INLET FIELD ALASKA 14408 0 - 14417.0 Print 10 14435.0- 14451.5 Print 11 14972.0- 14990.0 ~.1.135 0 14444.0 PHILLIPS PETROLEUM COMPANY "NORTH COOK INLET UNIT" 8.01 COOK INLET FIELD ALASKA ,.,?,. .............. ,. ~!,, ~ ,~ ,~ ~,,, ~,. .. 14444.0 14451.5 14972 0 - 14981.0 t! 'NORTH COOK INLET UNIT" B-01 COOK INLET FIELD ALASKA · ~:---,~.....,--..~ ~ ,., ..~.,.! ~,~ ', 14981.0 · 14990.0 It Print 12 14490.0 - 15008.0 Print 13 15008.0 - 15026.0 149.q0,0. 14999.0 It ..ILU.S .ET.OLEUr~ cor~.^.y j "NORTH COOK INLET UNIT" B-01 COOK INLET FIELD ; ALASKA "· '""' ' ".".....,.. ,.,.. ~,.- ..,-.~ ,m~,~ t . . WC.3 ' 14999.0 -1S008.0 15008.0 - 1,5017.0 f! [, · PHILLIPS PETROLEUM COMPANY "NORTH COOK INLET UNIT" B-01 COOK INLET FIELD ALASKA 15017.0 · 15026.0 It ;..- · - · · · .; Ii· Print 14 15026.0 - 15044.0 Print 15 15044.0 - 15046.5 · t..~, -..-'~ · [.'. -'~. i.~.~! .~...'.-~ ....~.~:.~.~.:......~-_~-?~. .~ ~.':.....[ .. . - . .' ' ..2~..~'r.'_': '":-;n :' i':. ~.?'--'-. .:.(I. : ~.~ ' 7 - .. _ ~:": ,:-.-_,. :.. .... :!.. ,~,,~..,~ - - · ~... . · _ .: ~ .__ .. --. - - :_.':.~i: :~i :!i~'--~..~..· -. PHILLIPS PETROLEUM COMPANY "NORTH COOK INLET UNIT" B-01 COOK INLET FIELD ALASKA .. 15035.0 - 15044.0 I 15044.{3 1.5046,5 It PHILLIPS PETROLEUM COMPANY "NORTH COOK INLET UNIT" B-01 COOK INLET FIELD ALASKA ....... ~.,..=,..,,.,..~.:,ro. ,,~.~ ,~..~,~ I~' I' !1 PETROLEUM FAX TO: Diana g Fleck COMPANY: State of Alaska FAX: 276-7542 FROM: ~ott Kehler COMPANY: CORE LAB PHONE/FAX: g07 349.3~1 DATE: 30.JAN-98 .-" PAGES: t Including cover page SUBJECT: Phillips Petroleum Co. Chip Samples Diana, I have been asked to give you a short note on what we dropped off the other day to act as a document for filing purpeses, We dropped off a total of 5 boxes containing chip samples taken from the two following wells in the Cook 'Inlet. NClU # B-1 Interval range is 2646. 153~ fL NCtU # B-2 Interval range is 9020 - 14537 ff.' Hope this helps. Please sent me a note if you received this or not. You can e-mail me at corear~h@aiaska, net Thanks Scott Kei~ler Lab Supervisor JAN 50 1998 .Naska Oil & Gas Cons. Comm~ ~00'~9Ud HgNU-I~OEAU~ Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Date: Well Name: Company: API#: Location: Field: Rig: Anadrill Personnel: OCT. 10, 1997 B No. 1 PHILLIPS PETROLEUM 50-883-20093 NCIU NORTH COOK INLET Unocal 428 Field Crew: Cell Manager: Steve Kemp / Dave Milton Cell Engineers: Mark BrOwn Steve Barney Field Support: Alaska District Manager: Martin Varco Field Service Manager: Craig Brown SERVICES PROVIDED: Directional Survey Service (DSS) Directional Logging Service (DLS) 7/30/97 to 8/03/97 8/04/97 to 10/10/97 OPERATING STATISTICS: Total MWD Pumping hours: Total MWD runs: JOB PERFORMANCE: 692.8 17 RECE 'V' DEC 1 8 1997 Alasta Oil & Gas Cons. Comai~o. Anchorage Directional: Anadrill's' Directional Survey Service (DSS) was picked up at spud on 7-30-97 providing real-time continuos TFO's and Surveys, and ran until "TD" on 10-7-97. 'CDR was picked up on 8-4-97 providing both real-time and recorded Gamma and Resistivity data for formation evaluation and correlation, and also ran to "TD" on 10-7-97. Shock: Anadrill' s' downhole tools constantly monitor shocks in real-time providing engineers with data to help assess and evaluate drilling conditions. Shocks of moderate to high levels were recorded throughout the well. Washout Detection: Washouts can be detected by monitoring MWD turbine rpm along with pump pressure .and flow rate. No washouts were encountered while drilling B-1. Anadrill appreciates the opportunity to provide Phillips Petroleum with Directional Survey (DSS) and Logging While Drilling (LWD) on the NCIU B-I. Sincerely, Steve Kemp Cell Manager Craig Brown Field Service Manager RF_.CEIV" : DEC 1 8 ~997 Alaska Oil & Ga~ Cons. Comm~ior,'. Anchorage Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) State of Alaska Alaska Oil & Gas conservation Comm. Attn: Lori Taylor 3001 Porcupine Drive Anchorage, alaska 99501 December 16, 1997 Paul Dean with Phillips Petroleum has asked me to submit the enclosed logs and survey's to the state of Alaska. This data represents Well B- I drilled for Phillips Petroleum on the Tyonek Platform in the Cook Inlet. If you have any questions, please feel free to call me. Regards, Craig Brown Alaska District - Field Service Manager DEC ! 8 1997' Alaska Oil & """ Anchor~e Company: Well Name: Core File # STATE OF ALASKA SAMPLE LOG Phillips Petroleum Company NClU # B-1 97-001 Core # I Depth Interval (ft) I Recovery (ft) I Sample #'si Total 1 14273-14333.5 60.5 ~I--62 62 2 14333.5-14395 61.5 63-123 61 3 14395-14451.3 56.3 124-179 56 4 14972-15046.5 74.5 180-254 75 254 RECEIVED DEC Calculations of Sodium Chloride Content in Injection Zone Method 1: Archie's Method Depth 3800 Bulk density 2.1 g/cc Density porosity 30% Rt 20 ~m Rw 1.8 D. Temperature 85 F Method 2: Spontaneous Potential SSP -20 mv @85F Rmf 2.72 .Qm ~ 67 F Rmf 2.22 .Qm (~ 85 F Rmfeq 1.887.0.m Rweq 1.1 D,m Rw 1.8 D.m@85F Using the Schlumberger Chart Interpretation book, a water resistivity of 1.8 .Qm at 85 F results in a sodium chloride content of 2800 ppm. It should be noted however that the electric log responds to chlorides only and is not measuring any other dissolved solids contained in the water. N.C.I.U. #B-1 Proposed Hole Volume water base mud Figure 4. Note:' An expansion factor of 3 is used for WBM and 2 is used for OBM. oil base mud 171/z' hole to 4000' MD 2231 bbl cuttings 12 1/4" hole to 9000' MD 1458 bbl cuttings 8 1/2" hole to 14000' MD 702 bbl cuttings Total volume of cuttings is 7472 bbls. 6" hole to 15800' MD 126 bbl cuttings 2-5-97 Survey report 8-OOT-97 07:52:56 Page 1 of 7 Client ................... : Phillips Petroleum Company Field .................... : NORTH COOK INLET Well .......................... : B-1 APl number ............... : 50-883-20093 Job number ............... : 40001069 Rig ........................... : UNOCAL 428 County/State ............. :NCIU State/Country ............ :ALASKA Spud date ................ : 30-JULY-97 Last survey date ......... : 08-Oct-97 Total accepted surveys...: 166 MD of first survey ....... : 0.00 ft 'MD of last survey ........ : 15498.00 ft RECEtV L DEC 1 8 1997 Alaska 0ii & Gas Cons. Commissi0~ Anchor,~le --- Survey calculation Calc method for positions: Minimum curvature Calc method for DLS ...... : Mason & Taylor Magnetic field strength..: 1109.64 HCNT ..... Depth references ........... Permanent datum .......... : MSL Depth reference .......... : RKB GL above permanent ....... : 0,00 ft KB above permanent ....... : 132,00 ft DF above permanent ...... ',: 132.00 ft Reference Dip ............ : 73,87 degrees ..... Vertical section origin .............. Latitude (+N/S-) ......... : 0.00 ft Departure (+E/W-) ........ : 0.00 ft .... Geomagnetic data ................... Magnetic model ........... : BGGM 1996 version Magnetic date ............ : 13-OCT-1997 Magnetic dec (+E/W-) ..... : 22.30 degrees Magnetic dip ............. : 73.87 degrees .... MWD survey Ref Criteria .............. Reference G .............. : 1002,05 milliG Reference H .............. : 1109,60 HCNT Tolerance of G ........... : (+/-) 3,00 milliG Tolerance of H ........... : (+/-) 7,00 HCNT Tolerance. of Dip ......... : (+/-) 0,30 degrees ..... Platform reference point, Latitude (+N/S-) ......... : 61.07675999N Departure (+E/W-) ........ : 150.94877941W Azim from rotary table to target: 164.40 degrees ..... Correction .......................... Magnetic dec (+E/W-) ..... : 22.30 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 22.30 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth (ft) (deg) (deg) (fi) (ft) Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (fi) (deg) 100f) type 1 0.00 0.00 0.00 0.00 0.00 2 200.00 0.20 31.00 200.00 200.00 3 300,00 0.10 55.30 100.00 300.00 4 400.00 0.20 74.10 100.00 400.00 5 430.00 0,40 9.70 30,00 430.00 0.00 0.00 0.00 0.00 0.00 -0.24 0.30 0.18 0.35 31.00 -0.39 0.50 0.34 0.60 34.41 -0.42 0.60 0.58 0.83 44.27 -0.51 0.71 0.65 0.96 42.29 0.00 TIP 0.10 MWD_M 0,12 MWD_M 0.11 MWD_M 1.21 MWD_M Page 1 ORIGINAL Seq Measured lncl Azimuth Course TVD Vertical Displ Displ Total At DLS Snry # depth . angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (fi) (fi) (ft) (fi) (ft) (ft) (deg) 100f) type 6 557.00 0.70 209.80 127.00 557.00 -0.37 0.48 0.34 0.58 35.32 0.85 MWD_M 7 710.00 1.90 184.40 153.00 709.95 2.67 -2.86 -0.32 2.88 186.40 0.85 MWD_M 8 860.00 3.20 187.60 150.00 859.80 8.86 -9.49 -1.07 9.55 186.40 0.87 MWD_M 9 1029.00 5.15 162.30 169.00 1028.36 20.77 -21.40 0.62 21.40 178.35 1.56 MWD 10 1119.00 6.00 171.30 90.00 1117.94 29.48 -29.89 2.56 30.00 175.11 1.35 MWD_M 11 1214.00 7.11 169.20 95.00 1212.31 40.27 -40.58 4.41 40.82 173.80 1.20 MWD 12 1307.00 7.89 172.80 93.00 1304.52 52.32 -52.56 6.29 52.94 173.18 0.98 MWD 13 1400.00 9.53 173.80 93.00 1396.44 66.23 -66.55 7.92 67.02 173.21 1.77 MWD 14 1493.00 11.12 175.70 93.00 1487.93 82.62 -83.15 9.42 83.68 173.53 1.75 MWD 15 1588.00 12.73 178.70 95.00 1580.88 101.75 -102.75 10.35 103.27 174.25 1.82 MWD 16 1681.00 13.81 179.60 93.00 1671.40 122.39 -124.09 10.66 124.55 175.09 1.18 MWD_M 17 1776.00 15.94 176.60 95.00 1763.21 146.08 -148.46 11.51 148.90 175.57 2.38 MWD 18 1871.00 17.80 177.30 95.00 1854.12 172.99 -175.99 12.97 176.46 175.79 . 1.97 MWD_M 19 1965.00 18.85 177.10 94.00 1943.35 201.81 -205.50 14.41 206.01 175.99 1.12 MWD 20 2059.00 19.87 172.90 94.00 2032.04 232.43 -236.53 17.16 237.15 175.85 1.84 MWD 21 2155.00 21.40 168.60 96.00 2121.88 266.03 -269.89 22.64 270.83 175.21 2.24 MWD_M 22 2248.00 22.42 165.50 93.00 2208.16 300.69 -303.69 30.43 305.21 174.28 1.66" MWD 23 2342.00 22.96 164.90 94.00 2294.89 336.94 -338.75 39.69 341.06 173.32 0.63 MWD 24 2432.00 24.13 163.70 90.00 2377.39 372,89 -373.35 49.43 376.61 172.46 1.40 MWD 25 2527.00 24.95 161.30 95.00 2463.81 412.32 -410.97 61.31 415.52 171.52 1.36 MWD 26 2555.00 25.38 160.60 28.00 2489.16 424.20 -422.23 65.19 427.23 171.22 1.87 MWD 27 2620.00 25.10 162,10 65.00 2547.95 451.88 -448.48 74.06 454.56 170.62 1.07 MWD_M 28 2714,00 26.20 164.90 94.00 2632.69 492.55 -487.49 85.59 494.95 170.04 1.74 MWD_M 29 2807.00 26.64 166.70 93.00 2715.98 533.92 -527.61 95.74 536.22 169.72 0.98 MWD 30 2900.00 27.30 166.70 93.00 2798.86 576.06 -568.65 105.44 578.35 169.50 0.71 MWD 31 2990.00 29.08 164.20 90.00 2878.19 618.56 -609.79 116.14 620.75 169.22 2.37 MWD 32 3083.00 30.18 165.50 93.00 2959.03 664.53 -654.17 128.15 666.60 168.92 1.37 MWD 33 3179.00 31.30 166.60 96.00 3041.54 713.58 -701.79 139.97 715.61 168.72 1.31 MWD 34 3274.26 33.58 165.00 95.30 3121.96 764.68 -751.34 152.53 766.66 168.52 2.56 MWD 35 3370.00 35.20 164.20 95.70 3200.93 818.73 -803.44 166.89 820.59 168.27 1.76 MWD 36 3463.00 35.49 163.40 93.00 3276.79 872.52 -855.11 181.90 874.24 167.99 0.59 MWD 37 3553.00 36.29 162.00 90.00 3349.71 925.26 -905.48 197.60 926.78 167.69 1.27 MWD 38 3648.00 37.87 160.50 95.00 3425.50 982.44 -959.70 216.02 983.72 167.31 1.92 MWD 39 3860.00 36.27 161.20 212.00 3594.65 1i09.98 -1080.41 257.95 1110.78 166.57 0.78 MWD 40 3952.00 35.89 162.10 92.00 3669.00 1164.10 -1131.84 275.01 1164.77 166.34 0.71 MWD Page 2 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool (fi) (deg) (deg) (fi) (fi) (ft) (ft) (ft) (ft) (deg) 100f) type 41 4049.00 35.27 161,70 97.00 3747,89 1220,48 -1185.48 292,54 1221.04 166,14 0,68 MWD 42 4141.00 34,92 158.80 92,00 3823,17 1273,23 -1235,25 310,41 1273,66 165.89 1.85 MWD 43 4235.00 34.58 159,20 94.00 3900,40 1326,57 -1285,27 329,61 1326.87 165,62 0,44 MWD 44 4334.00 34.73 157.10 99,00 3981.84 1382,52 -1337,52 350,56 1382,70 165.31 1,22 MWD 45 4422.00 35.45 158.50 88.00 4053,85 1432,77 -1384.35 369.67 1432.86' 165.05 1,23 MWD 46 4516.00 35,83 158,70 94.00 4130,24 1487,26 -1435.35 389.65 1487,30 164,81 0.42 MWD 47 4605.00 36,91 158,90 89.00 4201,91 1539.79 -1484,56 408,74 1539.80 164.61 1,22 MWD 48 4705.00 36.80 157.70 100,00 4281,92 1599,42 -1540,28 430,91 1599.42 164,37 0,73 MWD 49 4795.00 36,32 158.50 90.00 4354.21 1652.71 -1590,02 450,91 1652.72 164.17 0.75 MWD 50 4888,00 35.95 160,20 93,00 4429,33 1707,33 -1641,33 470,25 1707,37 164,01 1,15 MWD 51 4979.00 35,75 158,00 91.00 4503,09 1760,39 -1691,12 489,26 1760,47 163,86 1,43 MWD 52 5073.00 35,76 159.40 94,00 4579,37 1815,04 -1742,29 509.21 1815,18 163.71 0,87 MWD 53 5167.00 35.40 156.80 94,00 4655,83 1869.40 -1793,03 529,60 1869.60 163,54 . 1.65 MWD 54 5262,00 35,15 157,50 95,00 4733,39 1923,82 -1843,58 550,91 1924.13 163,36 0,50 MWD 55 5356.00 35,94 156,90 94,00 4809,87 1978,03 -1893,96 572,08 1978,47 163,19 0,92 MWD 56 5445,00 37.11 156,10 89,00 4881,39 2030,50 -1942.53 593,21 2031,09 163,02 1,42 MWD 57 5540.00 37.65 158,90 95,00 4956,88 2087,74 -1995,80 615,27 2088,49 162.87 1.88 MWD 58 5633,00 37,48 162,20 93,00 5030,61 2144,29 -2049,25 634,15 2145,13 162,81 2,17 MWD 59 5729.00 36,56 160,10 96.00 5107.26 2202,00 -2103,95 652,81 2202.90 162,76 1,63 MWD 60 5822.00 36,06 159.70 93.00 5182.20 2256,90 -2155,66 671,73 2257.90 162,69 0,59 MWD 61 5914.00 34,72 160,30 92.00 5257,20 2310,02 -2205,73 689,96 2311,12 162,63 1,50 MWD 62 6009,00 36.33 158.40 95,00 5334,52 2364.99 -2257.37 709.44 2366,22 162,55 2,05 MWD 63 6103,00 37.01 157.70 94,00 5409,91 2420,79 -2309,43 730,43 2422,19 162,45 0,85 MWD 64 6197.00 37.21 160.80 94.00 5484,88 2477.26 -2362,46 750.51 2478,80 162.38 2,00 MWD 65 6291.00 37,46 161,60 94,00 5559,62 2534,17 -2416,42 768,88 2535,80 162,35 0,58 MWD 66 6383,00 36.78 159,50 92,00 5632,98 2589,56 -2468,77 787,36 2591,29 162,31 1,56 MWD 67 6475.00 36,63 164,10 92.00 5706.76 2644,46 -2520,97 804,53 2646,24 162,30 2,99 MWD 68 6571.00 36,37 162,70 96.00 5783,93 2701.55 -2575.69 820.84 2703.33 162.32 0.91 MWD 69 6662.00 36,04 162,80 91,00 5857,36 2755,28 -2627,03 836,78 2757,08 162,33 0,37 MWD_M 70 6757.00 34,50 163,60 95,00 5934,92 2810,12 -2679,54 852,64 2811,92 162,35 1,69 MWD 71 6816.00 34,11 165,70 59,00 5983,66 2843,37 -2711,60 861,44 2845.15 162,38 2,11 MWD 72 6908,00 34,33 165,30 92,00 6059,73 2895,10 -2761,69 874,40 2896,81 162,43 0.34 MWD 73 7004,00 33,89 165,90 96,00 6139,21 2948,92 -2813,83 887,79 2950,56 162,49 0.58 MWD 74 7099.00 33.73 167,30 95,00 6218,15 3001,74 -2865,25 900,04 3003,29 162,56 0,84 MWD 75 7190.00 34.64 165.70 91.00 6293.43 3052.83 -2914,96 911.98 3054.29 162.63 1.41 MW[:) Page 3 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +NIS- +E/W- displ Azim (degl tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 76 7282.00 35.39 166.50 92.00 6368.77 3105.60 -2966.20 924.66 3106.99 162.69 0.96 MWD 77 7376.00 36.26 167.00 94.00 6444.99 3160.57 -3019.76 937.27 3161.87 162.76 0.98 MWD 78 7470.00 36.65 166.00 94.00 6520.60 3216.38 -3074.07 950.31 3217.60 162.82 0.76 MWD 79 7563.00 36.84 165.90 93.00 6595.12 3272.00 -3128.04 963.81 3273.16 162.87 0.21 MWD 80 7655.00 35.86 165.10 92.00 6669.22 3326.52 -3180.83 977.46 3327.63 162.92 1.18 MWD 81 7755.00 36.66 164.30 100.00 6749.85 3385.66 -3237.88 993.07 3386.75 162.95 0.93 MWD_M 82 7844.00 37.74 162.40 89.00 6820.74 3439.45 -3289.42 1008.50 3440.55 162.96 1.77 MWD 83 7939.00 38.53 163.10 95.00 6895.46 3498.09 -3345.45 1025.89 3499.21 162.95 0.95 MWD 84 8030.00 38.16 163.90 91.00 6966.84 3554.54 -3399.58 1041.93 3555.66 162.96 0.68 MWD 85 8125.00 37.96 161.80 95.00 7041.64 3613.08 -3455.53 1059.19 3614.22 162.96 1.38 MWD 86 8218.00 37.45 163.30 93.00 7115.22 3669.92 -3509.79 1076.25 3671.10 162.95 1.13 MWD 87 8306.00 37.27 162.70 88.00 7185.16 3723.31 -3560.86 1091.86 3724.49 162.95 0.46 MWD 88 8401.00 38.12 162.70 95.00 7260.33 3781.37 -3616.32 1109.14 3782.58 162.95. 0.89 MWD 89 8493.00 37.87 160.70 92.00 7332.84 3837.93 -3670.08 1126.92 3839.20 162.93 1.37 MWD 90 8589.00 38.23 162.40 96.00 7408.44 3897.03 -3726.21 1145.64 3898.34 162.91 1.15 MWD 91 8683.00 37.51 162.40 94.00 7482.64 3954.69 -3781.21 1163.08 3956.05 162.90 0.77 MWD_M 92 8777.00 37.94 160.80 94.00 7556,99 4012.14 -3835.78 1181.24 4013.54 162.88 1.14 MWD 93 8871.00 38.06 159.80 94.00 7631.07 4069.86 -3890.26 1200.75 4071.36 162.85 0.67 MWD 94 8961.00 38.03 159.30 90.00 7701.95 4125.13 -3942.23 1220.13 4126,73 162.80 0.34 MWD 95 9056.00 37.75 161.70 95.00 7776.92 4183.33 -3997.22 1239.60 4185.02 162.77 1.58 MWD 96 9151.00 37.53 159.10 95.00 7852.15 4241.19 -4051.86 1259.06 4242.97 162.74 1.69 MWD 97 9245.00 37.07 160.30 94.00 7926.93 4297.96 -4105.28 1278.82 4299.85 162.70 0.92 MWD 98 9337.00 37.11 159.80 92.00 8000.32 4353.28 -4157.44 1297.75 4355,28 162.66 0.33 MWD 99 9432.00 36.43 158.20 95.00 8076.42 4409.89 -4210.53 1318.13 4412.03 162.62 1.24 MWD 100 9527.00 36.19 157.60 95.00 8152.97 4465.78 -4262.65 1339.29 4468.09 162.56 0.45 MWD 101 9620.00 35.84 159.40 93.00 8228.20 4520.17 -4313.52 1359.33 4522.64 162.51 1.20 MWD 102 9714.00 34.73 159.10 94.00 8304.93 4574.25 -4364.30 1378.57 4576.85 162.47 1.20 MWD 103 9808.00 35.26 158.80 94.00 8381.93 4627.92 -4414.61 1397.93 4630.66 162.43 0.59 MWD 104 9900.00 35.77 158.80 92.00 8456.82 4681.10 -4464.43 1417.26 4683.99 162.39 0.55 MWD 105 9995.00 35.97 159.20 95.00 8533.80 4736.52 -4516.40 1437.21 4739.56 162.35 0.32 MWD 106 10088.00 35.98 159.20 93.00 8609.06 4790.93 -4567.47 1456.61 4794.11 162.31 0.01 MWD 107 10182.00 36.44 159.00 94.00 8684.91 4846.22 -4619.35 1476.42 4849.56 162.28 0.51 MWD 108 10278.07 36.85 159.60 96.10 8762.01 4903.35 -4673.00 1496.69 4906.84 162.24 0.57 MWD 109 10354.00 37.69 159.60 75.90 8822.42 4949.15 -4716.08 1512.71 4952.75 162.22 1.11 MWD_M 110 10434.00 37.99 162.30 80.00 8885.60 4998.13 -4762.46 1528.72 5001.81 162.20 2.10 MWD Page 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 111 10538.00 38.52 167.20 104.00 8967.28 5062.48 -4824.55 1545.63 5066.09 162.24 2.96 MWD 112 10631.00 38.74 168.90 93.00 9039.94 5120.42 -4881.35 1557.65 5123.85 162.30 1.17 MWD 113 10726.00 38.42 168.90 95.00 9114.20 5179.47 -4939.48 1569.06 5182.70 162.38 0.34 MWD_M 114 10799.00 37.53 168.40 73.00 9171.75 5224.27 -4983.52 1577.90 5227.35 162.43 1.29 MWD 115 10821.00 37.46 168.50 22.00 9189.20 5237.63 -4996.64 1580.58 5240.67' 162.45 0.42 MWD 116 10912.00 36.66 168.60 91.00 9261.82 5292.32 -5050.39 1591.46 5295.21 162.51 0.88 MWD_M 117 11006.00 35.70 168.90 94.00 9337.69 5347.65 -5104.81 1602.29 5350.37 162.57 1.04 MWD_M 118 11099.00 36.80 169.00 93.00 9412.69 5402.47 -5158.79 1612.83 5405.02 162.64 1.18 MWD 119 11192.00 37.67 169.20 93.00 9486.73 5458.55 -5214.04 1623.47 5460.94 162.71 0.94 MWD 120 11288.00 36.42 169.40 96.00 9563.35 5516.18 -5270.87 1634.21 5518.40 162.77 1.31 MWD 121 11380.00 36.66 169.80 92.00 9637.27 5570.73 -5324.75 1644.10 5572.79 162.84 0.37 MWD 122 11475.00 38.46 170.40 95.00 9712.58 5628.35 -5381.79 1654.05 5630.24 162.92 1.93 MWD 123 11571.00 39.41 170.70 96.00 9787.25 5688.33 -5441.30 1663.95 5690.04 163.00 , 1.01 MWD 124 11668.00 38.32 171.40 97.00 9862.78 5748.78 -5501.43 1673.42 5750.31 163.08 1.21 MWD 125 11761.00 38.25 171.30 93.00 9935.78 5805.98 -5558.39 1682.09 5807.33 163.16 0.10 MWD 126 11854.00 36.49 171.70 93.00 10009.68 5861.99 -5614.22 1690.44 5863.19 163.24 1.91 MWD 127 11949.00 35.54 172.20 95.00 10086.52 5917.37 -5669.52 1698.26 5918.41 163.32 1.05 MWD 128 12044.00 36.42 171.70 95.00 10163.40 5972.70 -5724.79 1706.08 5973.60 163.41 0.98 MWD 129 12135.00 37.89 170.80 91.00 10235.93 6027.26 -5779.10 1714.45 6028.05 163.48 1.72 MWD 130 12233.00 36.48 169.90 98.00 10314.00 6086.17 -5837.49 1724.37 6086.85 163.54 1.54 MWD 131 12322.00 36.46 169.10 89.00 10385.57 6138.86 -5889.51 1734.01 6139.47 163.59 0.53 MWD 132 12415.00 37.01 169.20 93,00 10460.10 6194.30 -5944.14 1744.48 6194.84 163.64 0.59 MWD 133 12507.00 37.07 168.70 92.00 10533.54 6249.54 -5998.53 1755.10 6250.02 163.69 0.33 MWD 134 12600.00 37.90 168.40 93.00 10607.33 6305.99 -6054.00 1766.34 6306.41 163.73 0.91 MWD_M 135 12694.00 38.33 168.20 94.00 10681.29 6363.87 -6110.81 1778.10 6364.25 163.78 0.48 MWD_M 136 12787.00 38.87 167.70 93.00 10753.97 6421.78 -6167.55 1790.22 6422.12 163.81 0.67 MWD 137 12882.00 39,22 167.70 95.00 10827.75 6481.53 -6226.02 1802.97 6481.83 163.85 0.37 MWD_M 138 12976.00 39.51 167.00 94.00 10900.43 6541.07 -6284.20 1816.02 6541,33 163.88 0.56 MWD 139 13069.00 40.36 166.80 93.00 10971.74 6600.71 -6342.34 1829.55 6600.95 163.91 0.92 MWD 140 13162.00 39.59 166.80 93.00 11043.01 6660.40 -6400.51 1843.20 6660.62 163.93 0.83 MWD 141 13256.00 36.46 167.00 94.00 11116.03 6719.53 -6458.16 1856.61 6719.73 163.96 1.21 MWD 142 13346.00 38.14 167.30 90.00 11186.66 6775.25 -6512.54 1869.02 6775.43 163.99 0.41 MWD 143 13441.00 39.02 166.10 95.00 11260.93 6834.44 -6570.19 1882.65 6834.60 164.01 1.22 MWD 144 13535.00 37.26 166.20 94.00 11334.85 6892.47 -6626.55 1896.55 6892.61 164.03 1.87 MWD 145 13624.00 38.09 166.10 89.00 11405.30 6946.83 -6679.36 1909.57 6946.97 164.05 0.94 MWD Page 5 Seq Measured Incl Azimuth Course TVD Vertical Disp! Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool (ft) (deg) (deg) (fi) (fi) (fi) (fi) (fi) (fi) (deg) 100f) type 146 13722.01 38.91 166.00 98.00 11481.99 7007.81 -6738.57 1924.28 7007.94 164.06 0.84 MWD 147 13814.00 39.90 165.50 92.00 11553.08 7066.20 -6795.17 1938.66 7066.31 164.08 1.13 MWD 148 13909.00 40.63 165.00 95.00 11625.57 7127.59 -6854.55 1954.29 7127.70 164.09 0.84 MWD 149 14003.00 39.26 165.70 94.00 11697.63 7187.94 -6912.94 1969.56 7188.04 164.10 1.53 MWD 150 14095.00 38.95 164.90 92.00 11769.02 7245.96 -6969.06 1984.28 7246.05' 164.11 0.64 MWD 151 14187.00 39.96 164.50 92.00 11840.06 7304.42 -7025.45 1999.71 7304.51 164.11 1.13 MWD 152 14285.00 40.85 164.10 98.00 11914.68 7367.94 -7086.60 2016.90 7368,03 164.11 0.95 MWD 153 14374.00 40.83 164.20 89.00 11982.02 7426.14 -7142.59 2032.80 7426.23 164.11 0.08 MWD 154 14468.00 40.78 164.30 94.00 12053.17 7487.57 -7201.71 2049.47 7487.66 164.11 0.09 MWD 155 14560.00 39.78 163.40 92.00 12123,35 7547.04 -7258.85 2066,01 7547,14 164.11 1.26 MWD 156 14651.00 39.63 163.40 91.00 12193,36 7605.17 -7314.56 2082.62 7605.27 164,11 0.16 MWD 157 14745.00 38.91 163.10 94.00 12266.13 7664.65 -7371,53 2099.77 7664.76 164.10 0.79 MWD 158 14838.00 38,72 163.10 93.00 12338.60 7722.93 -7427.31 2116.71 7723.04 164.09 . 0,20 MWD 159 14936.00 36,69 162.40 98.00 12416.13 7782.84 -7484.55 2134.48 7782.96 164.08 2,12 MWD 160 15022.00 35.88 162.80 86.00 12485.45 7833.71 -7533.11 2149.70 7833.84 164,07 0.98 MWD 161 15115.00 35.57 162.90 93.00 12560.95 7887.99 -7585.00 2165.71 7888.13 164.06 0.34 MWD_M 162 15211.00 35.14 162.20 96.00 12639.25 7943.51 -7637,99 2182.37 7943.66 164.05 0.62 MWD 163 15303.00 34.28 162.10 92.00 12714.87 7995.86 -7687.86 2198.42 7996.01 164.04 0.94 MWD 164 15397.00 32.08 161.60 94.00 12793.54 8047.25 -7736.74 2214.44 8047.42 164.03 2.36 MWD 165 15430.00 31.43 161.30 33.00 12821.60 8064.59 -7753.21 2219.97 8064.77 164.02 2.03 MWD 166 15498.00 29.90 161.00 68.00 12880.09 8099.21 -7786.03 2231.17 8099.40 164.01 2.26 MWD_M Page 6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 6~'~ Classification of Service Well OIL I---] GAS I-~ SUSPENDED~ ABANDONED ~ SERVICE [~ Suspended (Temporarily Abandoned) 2. Name of Operator ~ 7. Permit Number Phillips Petroleum Co. ,~-~_~'~ 97-115 3. Address . i__~_~v~l,~ ~ 8. APl Number 6330 W. LooP South,. Be!!.aire, TX 77401~ 50-883-20093 4 Location of well at surface, ' '. ".," ~!1,~~ 9. Unit Name At Top Producing Interval ~ 7 '1250' FNL & 980' FWL SEC ~'~"¥T~0"~''~ North Cook Inlet ........... 10. Well Number NCIU B-1 ~..'..,-~...:: 2178' FSL & 2086' FEL SEC 7-T 11N-R09W At Total Depth "- ::: ;. 'i'. ;:. SL & ~0' FEL SEC 7-T 11N-R09W 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Cook Inlet ] Beluga RKB 132 ft. NGIU 12. Date Spudded 13. Date T.D. Reached 14. Date Suspended- 15. Water Depth 16. No. of Completions 07130197 10~08~97 10/17/97 130 17. Total Depth 18. Plug Back Depth (MD+I'VD) 19. Directional Survey 20. SSSV Depth 21. Thickness of Permafrost 15500 10,029(MD) 8,605 (TVD) YES ~] NOD KB 22. Type Electric Logs Run AIT/DSl/GR/AMS; Den/Neutron; RFT/GR; DipmetedGR 23. CASING, LINER AND CEMENTING RECORD Casing Size wt. per ft. Grade Setting Depth (MD) Hole Size Cementing Record Amount Pulled 30" 407 Driven 20" 133 K-55 2,579 24" 1690 sx. None 13 3/8" 72 L-80 3,760 18.5" 1234 sx. None 9 5/8" 53.5 P-110 10,376 12.25 2400 sx. None 9 5/8" 53.5 P-100 3,558 12.25 None None 24. Perforations open to Production(MD+TVD of Top and 25. Tubing Record Bottom and interval, size, and number) Size Depth Set (MD) Packer Set (MD) 2 3/8" 3663' Tubing cemented 13 3/8" casing perforated from 3500-3540 2 3/8" 3663' for cuttings disposal (For purpose of cuttings disposal) 26. Acid, Fracture, Cement Sqeeze, ETC. I I 27. PRODUCTION TEST Date First Production Method of Operation (flowing, gas lift, etc.) NA Temporarily abandoned DateofTest Hours Tested 'Prod. for Oil Gas Water-BBL Choke CdR Test Period FTP Casing Pressure Calculated Oil Gas Water-BBL Choke CdR 24 hr Rate 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Cored from 14,273-14,454 and 14,972-15,056 Core Description Attached RrCU Vrn Ol l tl l Form 10-407 Rev 7-1-80 I: MI~ NOV 2! 1 Igg? Alaska 011 & Gas Cons. Commission Anchorage 29 3O GEOLOGICAL MARKERS FORMATION TESTS Include interval tested, pressure data, all NAME MEAS. DEPTH TRUE VERT. DEPTH fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Directional Survey, Core Description 32 I hereby certify that the foregoing is true and correct to the best of my knowledge ' Signed ~. ~[~1,~ Title ~ Date i I From 10-407 Rev 7-1-80 ,( i'IOV ':'! ,,~Jaska Oil & ....... . ,~ncnora~e * ALASKA COMPUTII~G CENTER * * * RECEIVED ****************************** ............................ * NOV 2 1 199ir, COMPANY NAME : PHILLIPS PETROLEUM CORP. ' WELL NAME : NORTH COOK INLET UNIT "B" NO. 1 FIELD NAME : NORTH COOK INLET BOROUGH : KENAI STATE : ALASKA API NUMBER : 50-883-20093-00 REFERENCE NO : 97437 Alaska 1:)1strict 1~3] East 00th Avenue Anchorageo AK 99518 (997J 349-45l~ Fsx 314-23&0 OIRSCTFOIrAb ~/~L;~'~ d~OL* PH£1~LIP~ PKTROLH(JV4 CX::~0JPAH~ well ......... : Field ........ : ~forch Coolc lnLek UnLb~ ........ : Suc~ace Sucgace Long.: Surface ...... 8U~PISH T~E..: 8fl~ .......... : 3518 331995.?? 2086725.70 333874.37 2579571.32 333983.05 2579358,14 334314.24 2578907.96 P~epared ..... ve. Ft ~ec~ &z.: 164.43 xB eLeva~Aon.: ~32.00 Hagne~Lc DcLn: +22.3~9 (8) ScaLe Convergence..: -0.83040400 mmmmmmmm mm~mf DEPTH Al~.~ 0.00 0.00 · 00.00 0.30 200.00 0.20 300.00 O.LO 400.00 0.20 D$PJICT~ON V~RT[~I,-DHPT~Lq AZII4tF~if TVD ~-SBA O-OQ 0.00 -132.00 LO.8O LO0.OQ -32.00 3L.OO 200.00 68.00 55.30 300.QQ 168.00 74.10 400.00 260.00 mmmmmsmms#mmmm~fu~mmm~ m~f~ mmmm TOOL oL/ FACE 1oo ]IR 0.00 3lB 0.30 SSRO. 13 ~4R 10R O.L~ 430.00 0.40 9.70 430.00 298.00 -0.06 1.08 557.00 0.70 209.80 557.00 42S.00 -O.V2 0.84 ?10.00 1.90 184.40 709.95 577.90 2.32 2.50 960.00 3.20 187.60 859.80 727.90 8.51 9.]3 1029.00 5.20 162.30 LO28.35 896.35 20.S0 21.]0 0.66 g 33L996.44 258672g,77 ISOb L.2! 0.30 B 331996.13 2586726.54 ]761 0.05 0.3] W 331995.42 2586723.23 372L 0.85 1.0& ~ 33L994.58 25867L&.09 362R 0,87 O.gS B 331996.11 2586704.59 52R 1.59 ]119.00 6.00 171.30 1117.92 985.92 29.25 29.64 8 2.60 8 331997.94 2586696.03 131 1.32 :!> ........ ~*fluJr~ ~ O~ 18:09 /~f4 DJ tO If Cl.-gm 8TAT[ON ! OnN? i PI'CAT lC)lq NBASUP. JD INCLN 9ROPOSBD h'HL, L PROF£LR 14 OeL L997 Page 2 DrRHCTIC]fl VHR2'JCAL-DBE'L2i~ S;BCT[ON COORDL'LqATHS-FROH A~S~ Zone 4 TOOb ummm~m wmmmmmmmmm 32L4.00 ?.tO 1~9.20 1232.30 1080.30 40.03 40.31 S 4.4S g 331999.64 2686686.33 32R 2307.00 7.90 ]~2.80 2304.SL L]?2.S~ 52.08 52.30 8 6.33 E 33200].3q 2S86673.32 2400.00 9.SO 373.80 3396.~3 ~26~.43 66.97 66.27 S 7.96 E 332002.77 2493.00 ~.XO 375.70 3487.93 3355.93 82.33 83.83 B 9.46 B 332004.O3 2586642.75 1588.00 12.70 378.70 3580.8P ]44g.89 ~01.42 102.39 8 1O.3l B 332004.67 ~S86623.18 1661.00 13.80 379.60 1671.41 3539.41 122.O3 323.70 S 10.69 B 332004.67 2686603.07 22b 1.20 1776.00 15.90 176.60 1763.24 3631.24 14S.69 248,02 S 11.54 B 332005.16 2S066??.53 6R 2.35 1871.00 L7.60 177.30 18S4.15 2722.15 172.67 27S.52 S 12.OO B 332006.22 2S86650.02 4b 2.01 1965.00 18.80 lIT.LO ]94].40 2812.40 20~.3( 2QS.O0 S 14.44 B 332007.24 2586520.52 S4b 1.0? · 2059.00 ]9.90 372.90 2032.09 3900.09 231.96 236.01 G 17.10 H 332009.53 2586489.49 47b !,09 2166.00 21.40 169.60 2121,93 3989.93 265.59 269.39 S 22.67 H 332014.63 26864S6.03 SIL 2.22 2248.00 22.40 ]65.50 2208.22 2076.22 300.23 303.]8 G 30.46 B 332021.03 2S86422.11 2Lb L.64 2342.00 23.00 ]64.90 2294.93 2162.93 336.S0 338.25 G 39.73 B 332030.69 2686386.93 241 0.68 2432.00 24.~0 163.70 2317.44 2245.44 372.46 312,86 B 49.46 B 332039.82 2586362.10 49b 1.33 2527.D0 2S.OO 361.30 2463.86 2331.85 4]2.90 410.50 B 61.34 8 332061,15 ~S86314.38 37b 1.41 2SSS.00 2S.40 360.(0 2409.T9 23S7.29 423.80 421.77 S 66.24 B 332OS4.88 2586303.06 LLGR 2620.00 2S.~0 162.t0 2547.98 2416.90 4SZ.48 448,03 S 74.10 B 332063.37 2686276.67 4gR 2714.00 26.20 364.90 2632.72 2600.72 492.16 497.04 S 06.64 8 332074.33 2686237,50 64R 1.74 2807.O0 26.60 366.70 2736.02 2684.O2 S33,49 S27.13 B 95.78 B 332083.89 2686197.28 ~ 0.96 2900.00 27.30 166.70 2798.92 2666.92 S76.61 S68.15 8 106.47 B 332092.99 2596156.12 34b 0.?$ 2990.00 29.ZO 364.20 2818.23 2746.23 628.&2 609.29 $ 116.18 B 332103.30 2586114.83 3LR 2.39 3083.00 30.20 165.50 295~.O6 2827.06 664.12 653,70 3179.O0 31.30 166.60 3041.S6 2909.56 733.19 701,34 S X40.O2 S 332X~S.60 2586022.4S 21~ 1.29 3274.OO 33.60 166.00 312~.72 2989.72 764.14 750.74 S 152.54 B 3323_37.41 2585972.88 L6L 2.58 3370.00 35.20 164.20 3200.93 3068.93 838.37 803.03 6 166.96 S 3321SL.06 2595920.39 S?b 3.73 3463.00 35.50 [63.40 3276.78 3344.78 872.~7 854,69 8 ~8~.97 g 332165,32 2685868.62 46b 0.59 3553.00 36.30 162.00 3349.69 3237.69 924.92 905.08 8 ]97.66 g 332~00.28 258S837.92 10b 2.27 3~48.Q0 37.90 L60.SO 342S.46 3293.46 982.13 95~.33 S 2~6.10 · 3323.97.93 2685763.40 LSSR ].~3 .............. 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S 950.48 B 332901.54 2503638.~9 LTL O.71 3127.68 S ~63.97 I 332914,25 2583584.S~ LS3~ 0.22 3180.4~ S 977.62 B 332927.33 2583531.61 3Lb 1-11 3237.58 $ 993.24 B 332941.92 2583474.29 S0~ 0.93 3289.12 S 1008.67 B 332956.60 2583422-53 292 1.71 3245.10 S 1026.05 8 332973.16 2583366.31 12tR 0.06 3299.24 S 1042.09 R 332988.41 2S83312.95 1OOL 0.64 3455.24 8 1059.37 8 333004.00 2583~55.70 1342 3.38 3509.49 S 1076.42 ~ 333021.15 2583201.22 XQGL 1.18 8306.00 3~.30 162.70 7385,05 7053,OS 3723.00 3560.55 S L092,03 · 333036.02 2583145.94 H8 0.43 8401.O0 38.10 ]62.70 7260.22 7128.22 378].07 361~,03 S LL09.3! 2 333052.48 ~583094.24 300b 0.84 9493.00 3?.90 160.79 7333.72 7200.72 3837.64 3669.78 S L1~?.09 B 333065~48 ~583040.22 7SR L.36 858~.00 38.20 163~40 8683.00 37.S0 162-40 7482.54 7350.54 3054,37 3760.89 B 1163.25 B 333104.03 2582028.GL 68~ 0.~4 8777.0~ 37.90 160.80 7556.92 7424.92 4031.79 3835,43 S 1381.40 R 33312%.38 2582873.82 72~ 1.~2 887A.00 38.LO 150.80 76J0*99 7498.99 4069.S0 3899.91 S 1200.91 R 333140.10 ZS82839.06 L08L 8963.00 38.00 ~59.30 77OL.87 7569.87 4324.77 394~,88 · 1220.20 H 333]58.72 2582766.83 L02R C9 (AnaciL,'LL] (c)97 N~£UBXD ].OC 10:09 AM D) ~ JZC]U-BL 1997 Page 5 m mm-~ 8~A?IOI! 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LU I (Afladrl[l ((~)97 HCI:UB2D 3.OC 10~09 AM DJ ~ ..................................................................................................................................................................................................................................................................... ( Operation Summary Thursday, October 30, 1997 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 10/21/97 00:00 18 10~20~97 10/19/97 18:00 5 23:00 I 00:00 24 00:00 08:00 10/18~97 10/17/97 16:00 00:00 0.5 00:30 0.5 01:00 3 04:00 20 00:00 2 02:00 1.5 03:30 I 04:30 1.5 10/16/97 06:00 1 07:00 7.5 14:30 1 15:30 2 17:30 1 18:30 2 20:30 2 22:30 1.5 00:00 8 08:00 4 12:00 1 13:00 0.5 Date: 1997-06-05 to 1997-10-22 CLEAN PITS. FILLED W/SEA WTR & CIRCULATED THRU MUD PIT SYSTEM. CLEAN OFF RESIDUAL OIL. RU JACKS TO SKID RIG. RD SEISMIC CLAMPS. EMPTY MUD PITS, PUMP SEA WTR TO APOLLO FOR INJECTION. MOP TANK BOTTOMS. SURVEY RIG IN FINAL PREPARATION TO SKID RIG TO A-12. RELEASE RIG FROM NCIU B-1 @0000 HRS 10/21/97 CONTINUE CLEANING RIG & PITS. ***ESTIMATE BE DONE CLEANING PITS 1200 HRS. 8 CLEANING OIL BASE MUD FROM RIG AND MUD PITS. 8 ND BELL NIPPLE , BOP, RISERS. ND VETCO-GREY NT-2 CONNECTOR. NU NT-2 CONNECTOR W/VALVE. TEST TO 500#,OK. 8 CONTINUE CLEANING PITS & RIG. LD 2 7/8" TBG & HANDLING TOOLS PULL WEAR BUSHING TRANSFER OIL MUD FROM RIG PITS TO PLATFORM PITS FOR STORAGE. CLEANING OIL BASE FROM RIG & MUD PITS. TIH TAG 2ND CMT PLUG @13564' SET DOWN 20000# 3 TIMES. BREAK ClRC TAG PLUG W/20000#, NO PUMP OFF. TAG PLUG REQUIRED BY ALASKA OIL & GAS COMMISSION. POOH TO 10800' CIRCULATE & CONDITION MUD PRIOR TO SETTING CEMENT PLUG ACROSS CSG SHOE. RU HOWCO, TEST LINES 2700#, OK. PUMP 30 BBLS SPACER, 535 SXS CMT +.7% CFR-3 + .1% HR-5 MIXED @17.0# 11 BBLS SPACER DISPLACED W/14.8# MUD FOR BALANCED PLUG 10800' - 10270'. CSG SHOE @10376'. POOH 15 STDS TO 9397' WOC - CBU, CONDITION MUD FOR TEMPORARY ABANDONMENT. TIH TAG CMT PLUG @10029' SET DOWN 10000# 3 TIMES. TAGGING PLUG REQUIRED BY ALASKA OIL & GAS COMMISSION. PBTD 10029 MD 8605 TVD. POOH TO 5" HWDP CLEAN OIL BASE MUD FROM MOUSE HOLE TO LD 5" HWDP LD 5" HWDP POOH TO 2 7/8" CEMENT STINGER LD 2 7/8" TBG. CLEANING 2 MUD PITS FOR SPACER & MIX WATER. MIX WEIGHTED SPACER. TIH TO TD @15500' CBU @15500' ClRC & CONDTION MUD SAFETY MEETING PRIOR TO SETTING CMT PLUG. RU HOWCO TEST LINES 3000#. Page 1 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 10/16/97 I 0/15/97 10/14/97 10/13/97 10/12/97 13:30 1 14:30 1 15:30 1 16:30 3 19:30 4.5 00:00 3 03:00 1 04:00 8.5 12:30 2.5 1 5:00 6 21:00 3 00:00 13.5 1 3:30 0.5 14:00 8 21:30 1 22:30 1.5 00:00 1.5 01:30 1.5 03:00 4 07:00 I 08:00 5.5 13:30 10.5 00:00 10 HOWCO PUMPED 20 BBL SPACER, 261 SXS CEMENT + .2% CFR + .08% HR-5 MIXED @15.8# 7 BBLS SPACER DISPLACED W/14.8# MUD FOR BALANCED PLUG 15500' - 14850' POOH 10 STD TO 14560' BREAK CIRCULATION WITH RIG PUMP. SWITCH TO HOWCO PUMP 2ND CMT PLUG. 20 BBLS SPACER, 282 SXS CMT + .2% CFR + .08% HR-5 MIXED @15.8#, 7 BBLS SPACER DISPLACED W/14.8# MUD FOR BALANCED PLUG 14560'- 14150' POOH 10 STDS. PUMP THRU DP TO CLEAR ANY CMT. CON'T POOH INTO CSG @ 10241' WOC. CBU. CLEAN RIG FLOOR. CUT DRLG LINE 145' . PREPARE TIH TO TAG CEMENT PLUG FOR STATE REQUIREMENT. FINISH POOH. LID JARS, STRING REAMER, & BIT. RU SHCLUMBERGER. RIH W/RFT ON WIRELINE & LOG W/SAME. UNABLE TO GET PRESSURES. POOH & RD SCHLUMBERGER. MU & RIH W/15 JTS (460.83') OF 2 7/8" CEMENTING STINGER..TIH W/5" DP TO CSG SHOE. CLEAN 2 MUD PITS FOR SPACER & CEMENT MIX WATER. CONTINUE WASHING & REAMING TO BTM AT 15,500' W/STRING REAMER. NO FILL. CIRCULATE CUTTINGS UP HOLE. PUMP OUT OF HOLE TO CSG SHOE. CBU. POOH TO RUN RFT. ATTEMPTED TO INITIALIZE TOOL & FUNCTION SAME. TOOL NOT PRESSURING UP TO SET. PULL WIRE OUT OF DP & RD SIDE ENTRY SUB. RD SCHLUMBERGER. POOH WITH RFT. LID TOOLS. SCHLUMBERGER TESTED TOOLS ON SURFACE FINDING TOOLS TO NOT FUNCTION. VALVES NOT CLOSING TO ALLOW TOOL TO PRESSURE UP. MU & RIH W/BIT, & STRING REAMER. NOTE: HAD ABANDON PLATFORM DRILL & CREW PERFORMED TRIP DRILL WHILE STILL IN CSG. WELL SECURED W/GOOD RESPONSE TIME. SCREW IN W/TOP DRIVE AT CSG SHOE. WASH & REAM F/CSG SHOE TO 12,264' W/STRING REAMER. WAITING ON SCHLUMBERGER TLC ENGINEER, DELAYED BY INABILITY TO FLY AT NIGHT. PERFORMED GENERAL RIG MAINTENANCE & CUT DRILL LINE WHILE WAITING. Page 2 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 10/12/97 10/11/97 10/10/97 1 O/09/97 10/08/97 10/07/97 10:00 16:00 22:00 00:00 3 03:00 2 05:00 3.5 08:30 4 1 2:30 9 21:30 2.5 00:00 9.5 09:30 8 17:30 1.5 19:00 1 20:00 4 00:00 0.5 00:30 8.5 09:00 1.5 10:30 6 16:30 3 19:30 2 21:30 2.5 00:00 23:00 6 SCHLUMBERGER CUT ROPE SOCKET. REHEADED SAME & TESTED. HELD SAFETY MEETING & PU TOOLS. HAD TROUBLE POWERING UP TOOLS. REPAIRED BAD CONNECTION. 6 RIH W/HWDP. LD JARS. FILLED DP AT 3299', 6570', 9372'. CONTINUE IN HOLE W/RFT ON DP TO CSG SHOE. 2 PU SIDE ENTRY SUB & RUN INSIDE DP W/WIRELINE. BROKE CIRC & LATCHED UP. RIH F/WIPER TRIP, FILL PIPE @ SHOE, P/U 6 JTS D.P., RIH, BRIDGES OR LEDGES @ 10518,10958,11313,RIH TO 1 5427 & REAM TO BTM @ 1 5500', 2' FILL. CIRC BTMS UP & PUMP DRY JOB. POH TO SHOE, TIGHT @ 1 2314,12144,11524,11366,11296,1121 5,10964,10843, CONTINUE POH F/SHOE R/U SCHLUMBERGER, LOG RUN #3 RFT/GR, TOOL STOPPED @ 10486' WLM, POH, RIH LOG RUN #4 DIPMETER/GR, STOPPED @ 10456' WLM, POH RIG DOWN SCHLUMBERGER. WAIT ON SCHLUMBERGER TOOLS & PERSONNEL F/DRILL PIPE CONVEYED LOGGING. OFFLOADING MUD MATERIALS, DRILL CLRS, ETC ONTO WORKBOAT. FINISHED LOGGING W/AIT,DSI,GR,AMS TO 15,503' WLM. POOH & LD TOOLS. MU & RIH W/DEN,NEUTRON FOR RUN #2. TOOL HANGING UP AT VARIOUS DEPTHS. WORKED TOOL INTO CASING & CONTINUED OUT OF HOLE. L/D TOOL. RIG DOWN SCHLUMBERGER LAY DOWN MONEL DRILL COLLARS. RIH F/WIPER TRIP CONDITIONING RUN. CONTINUE CIRC BOTTOMS UP. BACKREAM Fl15,500' TO 14,015'. TIGHT HOLE RELATED TO BACK REAMING. CONTINUED PUMPING ONLY TO CSG SHOE AT 10,378'. CIRC BU & CLEAN FLOOR. CONTINUE POOH & L/D BHA. PULL WEAR BUSHING & TEST BOP'S. STATE WITNESSING WAIVED BY BLAIR WONDZELL W/AOAGC AT 10:00 AM ON 10-07-97, SET WEAR BUSHING. RU SCHLUMBERGER. LOG RUN #1, AIT/DSI/GR/AMS 23 CONTINUE DRILLING F/15,308' TO 15,500' T.D.. 1 CIRCULATE BOTTOMS UP, PRIOR TO POH TO LOG. 00:00 0.5 00:30 3.5 04:00 1 FINISH CHANGING OUT CDR TOOL. RIH TO 9 5/8" SHOE AT 10,378'. SLIP & CUT 76' OF DRILL LINE. Page 3 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 10/07/97 10/O6/97 10/05/97 10/04/97 05:00 2 07:00 1.5 08:30 15.5 00:00 4 04:00 2 06:00 2 08:00 7 15:00 1.5 16:30 2.5 19:00 5 00:00 4 04:00 1.5 05:30 1 06:30 7 13:30 3.5 17:00 7 00:00 7 07:00 1 08:00 2.5 10:30 1 11:30 7.5 19:00 1.5 20:30 1 21:30 1 22:30 1.5 CONTINUE IN HOLE TO 14,912'. HAD TO WORK THROUGH TIGHT SPOT F/10,768' TO 10,968'. WASHED & REAMED & LOGGED CORE SECTION W/MWD TO BTM AT 15,056'. DRLG FR/15056- 15308'. CONTINUE CORING F/15,013' TO 15,056' CIRC BU. MIXED & LOST SLUG THROUGH FAULTY PIT VALVE. REPAIRED VALVE & REMIXED & PUMPED SLUG. POOH W/CORE ASSEMBLY. WORKED UP THROUGH TIGHT HOLE AT 14,400' & FROM 11,078' UP TO 10,768'. CONTINUE OUT OF HOLE W/CORE. LD CORE & CORE BBL. RECOVERED 74' OF CORE FOR 88% RECOVERY. RIG REPAIR. REPAIR TOP DRIVE OILER PUMP. PU 1.15 DEG ADJ XP MOTOR, MU BIT #15. MU MWD/CDR TOOLS. ANADRILL UNABLE TO REPROGRAM CDR TOOL. UNABLE TO COMMUNICATE BETWEEN CDR & PC. LD CDR & PU STANDBY TOOL. UNABLE TO COMMUNICATE W/IT TOO. AFTER CONSULTING ANADRILL MWD SUPV THE DECISION WAS MADE TO RUN TOOL AS IS SINCE PREVIOUS PROGRAM SHOULD SUFFICE CONTINUE POOH. PLUG MWD PORT & REMOVE SLEEVE F/MOTOR. LD MOTOR. CLEAR & CLEAN FLOOR. PU & MU 90' CORE ASSEMBLY & RIH W/SAME. HAD TO WASH & REAM PAST TIGHT HOLE F/10,678' TO 10,768'. CONTINUED WORKING PIPE ONLY WITHOUT WASHING & REAMING THROUGH TIGHT HOLE FROM 10,768' TO 11,078'. CONT IN HOLE. WASH & REAM VERY TIGHT HOLE FROM 14,372' TO '14,972' TD. CORE N FORELAND SAND FR/14972 TO 15013'. DRILLING TO 14,936' MD, 12,415' TVD. CIRCULATE BU FOR SAMPLES. CONT DRILLING F/14,936' TO 14,972' MD, 12,443' TVD, LOOKING FOR CORE POINT. CIRC FOR SAMPLES. BK REAM OUT OF HOLE TO CSG SHOE. CIRCULATE BOTTOMS UP. PUMPED SLUG. SLIP & CUT 114' DRLG LINE. RIG REPAIR. REPLACE UMBILICAL CONNECTOR ON TOP DRIVE. POOH FOR CORE BBL. Page 4 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 10/03/97 10/O2/97 10/01/97 09/30/97 00:00 00:00 05:30 07:30 10:30 12:30 14:30 16:30 18:30 23:30 00:00 02:00 03:00 07:00 08:30 13:00 14:30 16:30 17:30 20:30 22:00 00:00 01:00 02:30 05:30 09:00 10:00 14:00 24 DRILLING (RTRY) FROM 14,468' TO 14,888'. 5 0.5 5.5 POOH W/3RD SUNFISH CORE. 2 BRK DN CORE BARRELS. 57' RECOVERY 3 MU BHA & PROGRAM MWD. START WEIGHTING UP MUD IN PITS. 2 RIH W/DRLG ASSEMBLY. 1.5 REPAIRED BROKEN AIR LINE ON HIGH DRUM CLUTCH. ALSO, ADJUSTED BRAKES. 2 CONTINUE IN HOLE TO SHOE AT 10,378' 2 CONTINUE IN HOLE TO 14,170' W/ONLY ONE TIGHT SPOT AT 10,680' & WIPED ONLY THROUGH IT. SLICK HOLE OTHERWISE. WASHING & REAMING FROM 14,190' TO 14,453' FOR MWD LOGS. DRLG FR/ 14453 TO 14468'. 4.5 1.5 2 1 3 1.5 2 POOH W/2ND 60' SUNFISH CORE. 1 LD 2ND CORE. RECOVERED 60' F/ 100% RECOVERY. 4 TESTED BOPE. RAMS, STACK & MAN VLVS TO 300/8000 PSI. FLOOR VLVS IBOP ETC TO 300/5000 PSI. ANNULAR TO 300/3500 PSI. 1.5 PU INNER ALUMINUM CORE BBL & MU NEW CORE BIT. TIH W/3RD CORE ASSY TO 9 5/8 SHOE. REPAIR LEAKING SEALS ON IRON ROUGHNECK. FINISH TIH - NO FILL. DROP BALL, BREAK CIRC & PUMP BALL DOWN. CUT 3RD SUNFISH CORE FR/ 14393 TO 14453'. CIRC BOTTOMS UP. SAMPLES FR/BTM STILL SANDY W/ GOOD FLOUR & C-1 THRU C-5 DRILL GAS. 2 PUMP SLUG & POOH W/CORE BBL. STILL NUMEROUS TIGHT PLACES BUT HOLE MUCH SLICKER THAN PREVIOUS TRIPS ONLY HAD TO ROTATE UP THRU 1 SPOT @ 11665 FT. 3.5 1 TIH TO 9 5/8" SHOE. 1.5 CUT DRLG LINE AND ADJUST BRAKES. 3 REPAIR STABBING GUIDE IRON R/NECK REPLACE BUSHINGS IN TOP DRIVE MAKE UP/BREAK OUT SYSTEM. FINISH TIH W/2ND 60' CORE ASSY. OBSERVED DRAG IN SEVERAL SPOTS BUT CONTINUED TIH W/OUT WORKING PIPE THROUGH THEM. 1 DROP BALL & PUMP DOWN SAME. 4 CUT 2ND 60' CORE IN SUNFISH FORMATION FROM 14333 TO 14393'. 1.5 CIRCULATE BOTTOMS UP. Page 5 of 33 · Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH'COOK INLET UNIT B-1 (D0124) Date From Hrs Operation O9/3O/97 O9/29/97 O9/28/97 O9/27/97 15:30 8.5 00:00 2 02:00 0.5 02:30 3 06:30 2 08:30 11 19:30 1 20:30 1 21:30 2.5 00:00 2.5 02:30 1.5 04:00 7 11:00 1 12:00 4.5 16:30 1 17:30 5.5 23:00 1 00:00 0.5 00:30 2 02:30 0.5 03:00 5 08:00 1.5 09:30 0.5 10:00 1.5 11:30 1.5 13:00 2 1 5:00 0.5 1 5:30 1.5 POOH W/CORE #2. TIGHT IN NUMEROUS PLACES. HAD TO WORK THOUGH TIGHT SPOTS AT 11665' - 11635' & SEVERAL PLACES BETWEEN 10817 & 10630'. CIRCULATE HI-VIS SWEEP DROP BALL. PREPARE TO CORE CORE 14273' - 14333' 60' CBU AFTER CORING. MIX SLUG & PUMP SAME. POOH INTO CSG WITH CORE. TIGHT SPOTS AS FOLLOWS 13484, 13253, 13039, 11697, 11664, 10863, 10728, 10698, 10636. SCREWED INTO EACH STD W/TOP DRIVE. WORK THRU TIGHT SPOTS WITHOUT ROTATING & PUMPING IN ATTEMPT TO KEEP CORE INTACT. LD CORE #1. RECOVERED 6OFT F/100% RECOVERY. PU 2ND CORE ASSY. TIH W/SECOND CORE ASSY. FINISH BACKREAMING TO 9 5/8 SHOE. CIRCULATE BOTTOMS UP. PUMP SLUG. POOH. LD JARS, MOTOR & BIT. PU CORE ASSEMBLY. TIH W/CORE ASSY TO SHOE. PU NEW JARS CHANGE OUT HYD KNIFE VALVE ON TRIP TANK FLOW LINE. SPOT TANK ON APOLLO SYSTEM FR/RIG FLOOR DRAINS. CONT TIH TO 12133'. TIGHT. WORK THRU TIGHT SPOT FR/11133 TO 11160'. TIH, TIGHT AGAIN. HAD TO WASH & REAM FR/12137 - 1 2229'. CONT TIH TO 13922'. TIGHT AGAIN. WASH & REAM FR/13922 - 14089'. WASH FR/14089 TO BTM @ 14273'. NO FILL ON BTM. PUMP HI-VIS SWEEP AROUND PRIOR TO CUTTING CORE. CONTINUE TO SLIDE TO 14046' DRLG 14046' - 14073' SERVICE RIG DRLG 14073' - 14228' CBU FOR CORE POINT DRLG 14228' - 14255' CBU FOR CORE POINT DRLG 14255' - 14268' CBU FOR CORE POINT. PLATFORM SHUT DOWN ON RED PAUL KING. STARTED STANDBY ENGINES & CONT. CIRCULATING & WORK PIPE. DRLG 14268' - 14273' CBU @CORE POINT. PUMP WEIGHTED HI-VIS SWEEP, HOLE CLEAN. Page 6 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hfs Operation 09/27/97 09/26/97 O9/25/97 09/24/97 O9/23/97 17:00 7 00:00 0.5 00:30 2.5 03:00 0.5 03:30 0.5 04:00 11.5 15:30 0.5 16:00 0.5 16:30 0.5 17:00 0.5 17:30 3 20:30 2.5 23:00 1 00:00 6.5 06:30 2 08:30 4 12:30 2 14:30 8.5 23:00 0.5 23:30 0.5 00:00 22.5 22:30 1.5 00:00 1 01:00 6 07:00 3 10:00 3.5 13:30 1 14:30 0.5 15:00 4.5 19:30 4.5 BACKREAM OOH F/CORES. BIT DEPTH @ REPT TIME 10956'. REAM TO SMOOTH UP TIGHT HOLE @ 12367' & 10956'. DRLG 13473' 13480' SLIDE 13480' - 13500' DRLG 13500' - 13508' SERVICE RIG - TOP DRIVE DRLG 13508' - 13890' ATTEMPT TO SLIDE 13890'- 13895'. DRLG 13895' - 13900' ATTEMPT TO SLIDE 13900 - 13905' DRLG 13905 - 13930' SLIDE 13930' - 13952' DRLG 13952' - 14037' SLIDE 14037 - 14045' DRLG FR/12952 TO 13158 FT. SLID FR/13158 TO 13158 FT. DRLG FR/13158 TO 13241 FT. SLID FR/13241 TO 13258 FT. DRLG FR/13258 TO 13460 FT. SLID FR/13460 TO 13465 FT. DRLG FR/13465 TO 13477 FT. DRILLED (RTRY) FR/12378 TO 1 2952'. DRILLED "C" SAND FR/12923 FT MD, (10858 FT TVD) TO 12952 FT MD, (10882 FT TVD). CIRCULATE FOR SAMPLES. CONFIRMED SAND IN SAMPLES, NO SIGNIFICANT INCREASE IN GAS. PREPARING TO TEST BOPE, DRAIN STACK, PUMP TO APOLLO F/INJECTION. TEST BOPE, 250/5000 PSI, ANNULAR 3500, FLOOR VALVES 250/5000 PSI. PICKUP CDR, MWD, MOTOR & TEST. RIH TO 10332' CUT DRLG LINE. RIH, TAG SOLID 11030' REAM F/11030-12252'. BRIDGES AT INTERVALS, 18' SOLID FILL.TIGHT @ 10870,10970,11030,11331,11474,11 505,11584,11657, ROTATING DRILLING F/12252-12378' ACTUAL ROTATING TIME 3.25 HR. Page 7 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/22/97 09/21/97 09/20/97 09/19/97 09/18/97 00:00 12:00 13:00 17:00 18:00 21:30 22:30 00:00 00:00 09:00 09:30 11:30 14:00 15:00 15:30 19:00 00:00 01:00 00:00 01:30 07:00 10:00 11:00 15:00 16:00 20:30 21:00 12 DRLG&SLIDING 12115' - 12252' ANGLE DROPPING 1 -1.5 DEG/IO0' WHILE ROTATING. @12252' MOTOR STALLED, PU OFF BOTTOM PUMP PRESSURE INCREASED W/LESS PUMP STKS. TAG BOTTOM, NO DIFFERENTIAL PRESSURE. 1 CBU - PREPARE POOH FOR BIT & MOTOR. 4 BACK REAM F/12252-10428' 1 CBU BELOW SHOE & PUMP DRY JOB. 3.5 POH 1 DOWNLOAD CDR DATA, LAY DOWN MOTOR, CDR & MWD. 1.5 TURN KELLY HOSE AWAY FROM DERRICK LEG, PUT SHEATH ON VIBRATOR 4" MUD LINE BETWEEN RIG SUB BASE AND UTILITY UNIT. 24 9 0.5 2 2.5 1 0.5 3.5 1 23 1.5 5.5 1 1 4.5 0.5 3 DRLD, SLIDING & ROTATING Fl11,748'-1 2,113'. ACTUAL ROTATING TIME 16.2 HR, ACTUAL SLIDING TIME 6.0 HRS SLIDE & ROTATE Fl11528'-11660, 8.0 HR ROTATING, .5 HR SLIDING. CIRCULATE. PUMP OUT OF HOLE 15 STDS TO CSG SHOE. REPAIR TOP DRIVE OIL PUMP PLUG & RECEPTACLE. CHANGE OUT SAVER SUB & PREFILTER ON TURBINE INTAKES RIH TO 11103', TAG SOLID, ALSO TAGGED @ 10675' & 10940' WASH & REAM F/11103-1.1660', 18' SOLID FILL ON BTM, PUMP HI VIS PILL, VERY LARGE AMOUNT OF COAL RETURNS. SLIDE & ROTATE DRILL F/11660-11748' ,.67 HR SLIDING, 4.5 HR ROTATING. WASH W/CDR TOOL F/10707'-10865' SLIDE AND ROTARY DRILL F/10865'-11528', ACTUAL SLIDING TIME 6.75 HR, ACTUAL ROTATING TIME 12.25 HR, BHA ASSY DROPPING -- 1 */100'. CIRCULATED BOTTOMS UP. POH F/BIT & BHA, STOPPED AND MONITORED WELL F/FLOW SEVERAL TIMES.SWABBING UNTIL SHOE. LAY DOWN BIT, CLEAN FLOOR, L/D MUD MOTOR, 2 MONEL LEAD CLRS, NMSTAB. PICKUP CDR, MUD MOTOR, CHANGE BLADE ON MOTOR & CHANGE SETTING TO 1.5, ORIENT, TEST MWD & MOTOR. REPAIR TORQUE WRENCH CYLINDER HEAD. RIH TO 10,332' SLIP & CUT DRILLING LINE. INSTALL NEW KELLY HOSE & TEST TO 250 & 5000 PSI CALIBRATE ANADRILL CDR & BHI WASH F/1041 5'-10707' W/CDR LOGGING TOOL. Page 8 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/17/97 09/16/97 09/15/97 09/14/97 00:00 24 00:00 09:00 12:00 13:30 15:00 16:00 00:00 01:30 02:30 04:00 07:00 08:00 10:00 10:30 14:00 15:00 21:00 23:00 00:00 09:00 16:30 17:30 CONTINUED SLIDING & ROTATING DRILLING F/10,495-10,865', 2.5 SLIDING HRS, 18.3 HRS ROTATING 9 CONTINUE WITH TRANSFERRING OIL BASE MUD FROM PLATFORM GIRDER TANK TO PLATFORM MUD PITS. WEIGHT UP & TREAT SAME FOR DRILLING. THIS VOLUME NEEDED TO DISPLACE HOLE. SEALED UP VARIOUS LEAKS IN RUBBER SEALS EFFECTED BY OIL BASE MUD. ALL CONTAINED. ALL PRODUCT TRANSFERRING VERY SLOW. HELD SAFETY MEETING RELATED TO SWAPPING OUT TO OIL BASE MUD. 3 PUMP HIGH VISC OIL BASE SWEEP & CONTINUE DISPLACING WATER BASE MUD WITH OIL BASE MUD WHILE DRLG FLOAT TRACK. DIVERTED SPACERS TO APPOLLO HOLDING TANKS. 1.5 CONTINUED DRILLING FLOAT TRACK & NEW HOLE TO 10,386'. 1.5 CIRC BU & CONFIRM LITHOLOGY. 1 PERFORMED FIT TEST WITH 12.2 PPG MUD. 1700 PSI AT 8850' TVD = 15.9 PPG EMW. USED 5 BBLS. BLED 4.5 BACK. 8 DRILLING AHEAD F/10,386' TO 10495', SLIDING HRS 2.3, ROTATING HRS 6.3 1.5 1 1.5 3 1 2 0.5 3.5 1 6 7.5 1 0.5 CONTINUE IN HOLE TO CMT AT 9757'. MOVE MUD AROUND FOR DRLG CMT. ClRC CEMENT OUT OF HOLE. DRILL CEMENT F/9757' TO LC 10,280'. CIRC BU. CLEAN PITS AFTER DRILLING CEMENT. PUMP 35 BBL WATER & 35 BBL HI VIS PILL CLEAN PITS & PREPARE F/OBM REMOVE OVERBOARD LINES & PLUG OFF. INSTALL APOLLO AUGER F/ACTIVE PITS, INSTALL DRIP PAN ON ACTIVE MAIN AUGER OUTSIDE, PLUG ALL WATER LINES AND F/D ALL DRILL WATER & SALTWATER LINES TO ACTIVE PITS, R/D WATER TO TEST PUMP, INSTALL SPRING ON BRAKE BAND DRILLERS SIDE, INSTALL CLAMPING CYLINDER ON RAISE BACKUP. TRANSFER OBM F/PRODUCTION PLATFORM PITS TO ACTIVE SYSTEM. TRANSFER OBM FROM PRODUCTION TANK TO PLATFORM PITS. CONTINUED CLEANING PITS & TRIP TANK, PUMP WATER THRU KILL LINE, CMT LINE, PUMP BLEED OFF, & CHOKE MANIFOLD. TEST CHOKE MANIFOLD, FLOOR VALVES, TOP DRIVE VALVES, KELLY HOSE AND STANDPIPE VALVE, TEST BOP PULL TEST PLUG, INSTALL WEAR BUSHING, R/D TEST JT, BLOW DOWN STAND PIPE & MANIFOLD, TOP DRIVE, CHOKE AND KILL LINES. PLUG GAP IN RIG FLOOR DRIP PAN. Page 9 of 33 & Gas C~ns. C~mm~sion Anchorage Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/14/97 09/13/97 09/12/97 09/11/97 18:00 3.5 21:30 2.5 00:00 24 00:00 1.5 01:30 1.5 03:00 1.5 04:30 6.5 11:00 2 13:00 1 14:00 1 1 5:00 3 18:00 1.5 19:30 4.5 00:00 0.5 00:30 2 02:30 1 03:30 2 05:30 4 09:30 3 PICK UP BHA, CDR WOULD NOT MAKE UP, L/D CDR, TEST MWD W/H20 RIH W/HWDP, P/U JARS, RIH W/DP CHANGED SWABS & LINERS IN MUD PUMPS, CHANGED VALVES & SEATS IN PUMPS, CLEANED RIG PITS INSTALLED DIESEL LINE IN PLATFORM PITS, CHANGED SHAKER SCREENS, PERFORMED INJECTION TEST WITH APOLLO THRU INJECTION TBG: 1/2 BPM @ 1150 PSI, 3/4 BPM @1250 PSI, 1-1/2 BPM @ 1400 PSI. CIRC THRU STANDPIPE, MANIFOLD AND SOLIDS CONTROL EQUIPMENT, CLEANED OUT DESlLTER & POSSUM BELLY, DISCONNECT WATER IN PLATFORM PITS. CLEAN OUT PBR W/MILL & SWEEP. POOH W/MILL. RU WEATHERFORD CSG TOOLS. PU & MU SEAL ASSEMBLY & RIH WITH 9 5/8" TIE BACK STRING. PU LANDING JTS. MU CIRC HOSE & RIH TO TOP OF PACKER W/PUMP IDLING. OBSERVED PRESS INCREASE. BLED OFF PUMP. PU 2' & CIRC HIGH VlSC SWEEP AROUND. NO SEALS TO SURFACE. SLACK OFF TO 120K SET DOWN WEIGHT & TEST SEALS TO 500 PSI. OK. SPACED OUT REPLACING 6' PUP WITH 8' PUP TO LAND 80,000 LBS ON SEALS. WITH HANGER LANDED, BACKED OUT & LAYED OUT LANDING JTS & RUNNING TOOL. RD WEATHERFORD. RUN PACK OFF. PRESS TEST CSG LINER TO 5000K F/30 MINUTES. CLEAN PITS, CHANGE PUMP LINERS, PREPARE OIL MUD MIX & PUMP SLUG. POOH & LID RTTS PACKER. PULL HANGER PACKOFF. RU CSG CREW. PU LANDING JTS. MU INTO HANGER & PULL HANGER TO FLOOR. INSPECT HANGER & MAKE SAME BACK UP. STD BACK LANDING JTS & HANGER. PU TWO JTS OF CASING. RIH SPACING OUT TO JUST ABOVE PBR. ENGAGE PUMP, & ENTER PBR TILL PRESSURE INCREASE OBSERVED. SHUT DOWN PUMP. CONTINUED ENGAGEMENT INTO PBR WITH PROPER SPACE OUT, TILL LANDING ON STOP RING. SET DOWN W/ 40,000 LBS. ATTEMPTED TO TEST TO 3000 PSI BUT STRING STARTED HYDRAULICING AT 2200 PSI. ALLOWED FOR STABILIZATION & PRESSURE CONTINUED TO FALL RAPIDLY. BLED OFF PRESSURE. PREPARE TO L/D CSG. Page 10 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/11/97 09/10/97 O9/09/97 12:30 20:30 22:00 8 POOH LAYING DOWN 9 5/8" TIE BACK STRING TO CHANGE SEALS ON SEAL ASSEMBLY. 1.5 RIG DOWN CASING EQUIPMENT. 2 P/U MILL, WASH SUB & STABILIZER & RIH, PUMP HI-VIS SWEEP AT LINER LAP. 00:00 1 01:00 1 02:00 2 04:00 8 12:00 3 15:00 2.5 17:30 2.5 20:00 2 22:00 2 00:00 0.5 00:30 0.5 01:00 2 MU HANGER & LANDING JNT. LAND HANGER. L/D LANDING JOINTS. R/D CASING TOOLS. INSTALLED & TESTED PACKOFF SEALS TO 10,000 PSI. OK. ATTEMPT TO TEST CSG W/2500 PSI. OK. CONTINUED UP TO 3300 PSI AND BEGAN TO LEAK OFF. REPAIRED STEM PACKING ON MUD PUMP. ATTEMPT TEST AS BELOW: TEST PSI: BK SIDE: INJ TBG: VOLUME 500 PSI 100 PSI 800 PSI 1.5 BBLS 1000 PSI 250 PSI 700 PSI 2.5 BBLS 1500 PSI 425 PSI 850 PSI 4.0 BBLS 2000 PSI 590 PSI 1000 PSI 6.0 BBLS STOPPED PUMP & BLED OFF TO 1100 PSI IN 10 MIN., 500 BK SIDE, 1050 INJ LINE. PRESSURED UP ON 9 5/8" ANNULUS W/ TOP CSG VALVE OPEN. JUST BEGAN TO PUMP W/LOW VOLUME TEST PUMP & GOT FLOW OUT TOP CSG VALVE INSTANTLY. PULL & RERUN NEW PACKOFF. NO DAMAGE FOUND ON THE 1ST PACKOFF. TEST WITH TEST PUMP. AT 1650 PSI TEST PRESSURE & 550 PSI ANNULUS PRESSURE, BLED OFF BACK SIDE. TEST PRESSURE IMMEDIATLY FELL TO 1100 PSI. STOPPED PUMPING & TEST PRESSURE FELL TO 900 PSI IN TWO MIN. STEADY RETURN ON BK SIDE. CLOSED IN BACK SIDE & TEST PRESSURE CONTINUED TO FALL RAPIDLY TO 460 PSI & STABILIZED. MONITORED CASING & UNLOADED OIL BASE MUD FROM WORK BOAT WHILE WAITING ON HALLIBURTON REP TO RUN RTTS. PRESSURES STABILIZED AT 460 PSI INSIDE 9 5/8", ZERO ON CSG, 590 INJECTION LINE. P/U RTTS TOOL, TESTED 9-5/8 HANGER SEALS TO 2000#, WELLHEAD TO 5000# RIH W/RTTS TO 3630' TEST CSG BELOW PBR TO 5000#-OK, TEST CSG F/3540'(ABOVE PBR) TEST CSG, IMMEDIATE LEAK THRU SEALS IN PBR. POH W/RTTS L/D PBR MILLS. PULL WEAR BUSHING. .RU SCHLUMBERGER & HELD PRE JOB SAFETY MEETING. Pagellof33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/09/97 09/08/97 03:00 4 07:00 1 08:00 1 09:00 1 10:00 4 14:00 0.5 14:30 2.5 17:00 0.5 17:30 6.5 00:00 00:30 02:00 03:00 04:30 09:30 13:00 15:00 16:00 18:00 19:00 19:30 20:30 21:00 22:00 23:00 0.5 1.5 1.5 5 3.5 1 2 1 0.5 1 0.5 RIH W/4.5" CSG GUNS & PERF AT 4 SPF STERLING SANDS FOR DISPOSAL. ON RUN #1 F/3530 TO 3540', RUN #2 F/3520-3530', ALL SHOTS FIRED. MISFIRE ON RUN # 3. POOH & REDRESS FIRING CAP. RIH WITH GUN RUN RR#3 & PERFORATE F/3500' TO 3520'. POOH. ALL SHOTS FIRED. OBSERVED RADIO SILENCE. RD SCHLUMBERGER & MONITOR WELL ON TRIP TANK. WELL STATIC. RIH & L/D 6 5/8" HWDP & MONELS. CLOSED BLINDS & ESTABLISHED INJ RATE THROUGH STERLING PERFS AS FOLLOWS: 900 PSI AT 1.0 BPM, 970 PSI AT 2.0 BPM, 985 PSI AT 3.0 BPM, 965 PSI AT 4.0 BPM, 975 PSI AT 5.0 BPM, 990 PSI AT 6.0 BPM, 1000 PSI AT 7.0 BPM, 1000 PSI AT 8.0 BPM. TOTAL OF 45 BBLS INJECTED. RIG UP WEATHERFORD CSG EQUIPMENT PRE-CASING SAFETY MEETING. RUN 77 JTS 9-5/8, 53.5#, P-110 BTC CSG 3585 FT, INCLUDING PUPS AND VETCO MANDREL HANGER, SPACE OUT, LAND CSG, PULL LANDING JTS. FINISH TIH. WASH LAST STD TO LINER TOP. SET 65000# ON TIE BACK EXTENSION. OBSERVED WT IND JUMP INDICATING PKR SET. CIRC BOTTOMS UP, RECOVERED SOME CMT CONTAMINATED MUD. PUMPED DRY JOB. POOH W/2 STDS. SLIP & CUT 105' OF DRLG LINE. POOH W/DOG SUB. TEST BOP'S FOR WEEKLY & SET WB. RIG REPAIR: FRONT BRAKE BAND BOLTS VIBRATED OFF OPPOSITE THE DRILLER. REMOUNTED SAME & THREAD LOCKED BOLTS. RIH W/12 1/4" BIT & CLEANED OUT TO TOP OF LINER PKR AT 3588'. OK. CIRC BU. POOH W/BIT. MU PBR MILLS & RIH. CLEAN OUT LINER TIE-BACK EXTENSION. CIRC BU. CLOSED ANNULAR AND PRESSURE TEST CSG, LINER LAP & LINER TO 3000 PSI- 1 5 MIN-OK. 1 PUMP SLUG & POOH W/16 STDS DP. 1 RIG REPAIR. HUB SPUN ON SHAFT TO DRWKS "B" TRACTION MOTOR. DISCONNECT "B" TRACTION MOTOR. WILL RUN ON "A" MOTOR. I FINISH POOH W/PBR MILL Page 12 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/07/97 00:00 03:30 07:30 08:00 09:30 11:00 15:00 16:30 19:30 22:00 22:30 2.5 0.5 1.5 3.5 FINISHED IN HOLE W/A TOTAL OF 148 JTS OF 9 5/8" - 53.5# - P110 - BTC CSG FOR 6790' INCLUDING FLOATS & HGR. WASHED LAST STAND DN. ATTEMPT TO PU W/NO SUCCESS. MAX 50OK. 4 CIRC & COND MUD FOR CEMENTING. MAX GAS 2200 UNITS. FULL RETURNS. 0.5 HELD PRE JOB SAFETY MEETING. 1.5 DROPPED & PUMPED DOWN BALL TILL SEATED. PRESSURED UP TO 1800 PSI & SLACKED OFF 20,000 LBS. BLEW BALL SEAT W/4000 PSI & REESTABLISHED CIRCULATION. ROTATED & RELEASED RUNNING TOOL & CHECKED FOR FREE TRAVEL. OK. SET BACK DOWN & CIRC. 1.5 CONTINUE CIRC WHILE WAITING ON TIDE TO CHANGE SO BOAT CAN COME IN WITH NEEDED CEMENT FOR JOB. RIG CMT TANKS FULL, BUT CMT ON BOAT NEEDED TO FINISH JOB. 4 TIED UP MV MONARCH & HOOKED UP CMT HOSE. TESTED LINES TO 5000 PSI & PUMPED 10 BBLS FW. MIX & PUMP 822 BBLS ( 2400 SX ) OF LEAD CMT AT 12.5 PPG, FOLLOWED WITH 144 BBLS (704 SX) OF TAIL CMT AT 15.8 PPG. NOTE: AT 300 BBLS OF LEAD PUMPED, RETURNS STARTED PHASING IN & OUT. AT 500 BBLS OF LEAD PUMPED, LOST ALL RETURNS. SLOWED PUMP FROM 5.5 BPM TO 3.0 BPM TO REGAIN CIRC. NO SUCCESS. CONTINUED PUMPING AT 5.0 BPM DUE TO THICKENING TIME CONSTRAINTS. 150 PSI PUMP PRESS. NO RETURNS. 1.5 DROPPED DART & PUMPED 10 BBLS OF FW BEHIND. DISPLACED DART W/RIG PUMP NOTICING SAME LAND IN LINER WIPER PLUG. CONTINUED DISPLACING W/RIG PUMP. DID NOT BUMP PLUG. 3 BLED OFF & CHECKED FLOATS. PULL OUT RUNNING TOOL. CIRC BU. CIRC OUT 50 BBLS CMT CONTAMINATED MUD. PUMP DRY JOB & POOH. LD BAKER 2 RH RUNNING TOOL. TIH W/DOG SUB TO SET LINER TOP PKR. 09/O6/97 00:00 01:30 NOTE: 21:30 HRS 9/6/97 NOTIFIED BLAIR WONDZELL W/AOGCC OF OUR INTENTION TO PERFORATE AND ESTABLIS INJECTION THROUGH THE 13 3/8" CSG. 1.5 CIRCULATE & REAM TIGHT SPOT AT 6533'. MIX & PUMP A 35BBL HIGH VISC SWEEP & CIRC HOLE CLEAN. 2.5 BACK REAM TO 13 3/8" SHOE AT 3760' Page 13of33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/06/97 09/05/97 09/04/97 04:00 1 05:00 2 07:00 2 09:00 3 12:00 12:30 11.5 00:00 3.5 03:30 0.5 04:00 4 08:00 12:00 13:00 16:00 17:00 00:00 OBSERVE WELL FOR FLOW. OK. CBU W/83 UNITS OF GAS MAX. CHECK FOR FLOW & SLUG. POOH & STAND BACK BHA. PU, DRIFT, STRAP, & STAND BACK 30 JTS OF HWDP & PULL WEAR BUSHING. RU WEATHERFORD CSG TOOLS. HELD PRE JOB SAFETY MEETING. NOTE: BLAIR WONDZELL W/AOGCC GRANTED EXTENSION TO BOP TEST REQUIREMENT UNTIL LINER SET & CMTD. 11:15 HRS 9/5/97. RAN LINER. RAN 146 JTS 9 5/8" 53.5// P-110 BR&C CSG. RD CSG TOOLS & CONT'D RUNNING LINER ON 5" HWDP. DEPTH AT MIDNIGHT 6900 FT. CONTINUE RFT PROGRAM. TOOK 20 MORE PRESSURE POINTS IN THE COOK INLET AND BELUGA SANDS. EXPERIENCED CONSIDERABLE OVER- PULL ON THE LAST PRESS POINT. DECIDED TO CUT RFT PROGRAM SHORT. POOH W/RFT TOOLS. RD SCHLUMBERGER. TIH W/BIT # 12. FILL PIPE @ 13 3/8". CONTINUE IN HOLE TO 9429'. 4 CIRCULATED OUT GAS FROM 9429' WHILE WORKING ON EL-MAGGO BRAKE. ROTATED WHILE CIRC. MAX GAS 730 UNITS WITH MUD CUT FROM 11.2 PPG TO 9.3 PPG. CIRC GAS OUT & BALANCED. EL-MAGGO BRAKE LOCKED IN. HUNTING PARTS. I FINISHED IN HOLE TO 10,278' W/NO PROBLEMS. MU TOP DRIVE & WASHED & ROTATED 100' TO BTM FOR SAFETY W/NO PROBLEMS. NO FILL. 3 CIRC HIGH VISC SWEEP AROUND W/ LOTS OF FILTER CAKE OVER SCREENS MAX GAS 1100 UNITS W/MUD CUT TO 9.5 PPG. GAS 500 UNITS. 1 CONTINUE CIRCULATING TO REDUCE GAS WHILE LOWERING YIELD FOR CSG RUNNING. 7 BACKREAM TO 6533'. PULL TIGHT COMMING OFF SLIPS. HOLE HAD BEEN SLICK. PU SINGLE & WORKED PIPE FREE. WORK OUT TIGHT SPOT ATTEMPT TO STAND BACK STAND TIGHT AGAIN, MU STAND ESTABLISH ROTATION & CIRCULATION WORKED OUT TIGHT SPOT AGAIN. PREPARE HI-VIS SWEEP. 2 FINISHED BACK REAMING TO SHOE. Page 14 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/04/97 O9/03/97 O9/02/97 02:00 1.5 03:30 1 04:30 3 07:30 2 09:30 7 16:30 1.5 18:00 2 20:00 0.5 20:30 3.5 00:00 07:00 10:00 12:00 13:00 18:00 00:00 01:00 01:30 1 0.5 4 OBSERVE WELL FOR FLOW. OK. CBU WITH 460 UNITS GAS, BRIEFLY. POOH. STD BACK HWDP. DOWNLOAD CDR. LAY OUT MWD & MOTOR. BIT SHOT W/ TWO LOOSE CONES. 3/8" UNDERGAUGE HELD PRE JOB SAFETY MEETING AND RU SCHLUMBERGER, NOTE: NOTIFIED MR. BLAIR WANDZELL W/AOGCC OF OUR INTENTION TO RUN 9 5/8" CSG AT 09:30 HRS 9/3/97. RIH W/DITE-CNL-LDL-LSS-MICROLOG- GR-AMS TO 9680', UNABLE TO GET BELOW 9680' BUT NO HANGING WHEN PICKING UP. OPEN CALIPER & LOG UP TO CSG SHOE, POOH W/LOGGING TOOLS. LD OPEN HOLE LOGGING TOOLS, PU CBT TOOLS. RAN CBT FR/3762' TO 1300 FT. LD CBT TOOLS & PU RFT TOOLS, RUN #3 RFT'S. RIH W/RFTTOOL, TOOK 12 PRESSURE READINGS IN THE COOK INLET SANDS BETWEEN 4225 FT & 4850 FT. 7 DRILLED (RTRY) FR/10327 TO 10378 FT BGG RUNNING 450 - 500 UNITS WITH 10,7 PPG MUD, 3 CIRCULATE AND RAISE MW FR/10,7 TO 11.O PPG. BGG DECREASED TO 300 TO 400 UNITS & STABILIZED, 2 BACKREAM FR/10378 TO 9696 FT, 1 TIH TO TD (SLICK). 5 CIRC & COND MUD, TRIP GAS 3170 UNITS. PUMP HIVIS WT'D SWEEP AROUND. RAISED MW TO 11.2 PPG. BGG DECR'D TO APPROX 200 UNITS & STABILIZED, 6 BACKREAM OOH F/LOGS, DRLG 10115' - 10143' CHANGE SWAB IN #1 MUD PUMP DRLG 10143' - 10227' Page 15 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 09/02/97 09/01/97 O8/31/97 O8/30/97 05:30 11.5 17:00 1.5 18:30 0.5 19:00 5 00:00 1 01:00 1 02:00 1 03:00 2.5 05:30 0.5 06:00 18 00:00 4.5 04:30 0.5 05:00 2 07:00 4 11:00 7.5 18:30 1 19:30 2 21:30 1.5 23:00 00:00 05:00 06:00 09:00 5 1 3 4.5 CIRCULATE OUT GAS FROM DRLG BREAK @10185' - 10215'. BG GAS INCREASED FR/80 UNITS TO 3000. MUD BELCHING OVER BELL NIPPLE, SD PUMPS, CLOSE HYDRIL, NO SI PRESSURES. CIRC 2000 STKS THRU CHOKE WHILE WORKING PIPE IN ANNULAR. SD PUMP, NO FLOW. OPEN HYDRIL CIRCULATE DOWN FLOWLINE. CONTINUE CIRC WITH BG GAS DROPPING TO 100 UNITS. SD PUMP FOR 20 MINUTES CHECKING FOR FLOW, NONE. CBU, GAS INCREASED TO 900 UNITS. INCREASE MUD WT TO 10.2//. WHILE CIRCULATING BG GAS INCREASED TO 2900 UNITS. 10.2//IN & OUT BG GAS DROPPED TO 2200 UNITS & STABILIZED. INCREASED MUD WT TO 10.5// W/BG GAS DROPPING TO 500-600 UNITS. DECIDED TO DRILL AHEAD MONITORING BG GAS. DRLG 10227' - 10254' CIRCULATE & WORK PIPE PRIOR TO MAKING CONNECTION. NO PROBLEM. MADE CONNECTION @ 10254'. DRILL (RTRY) TO 10399'. RAISE MW TO 10.7 PPG - 10.6 PPG OUT. BGG STABILIZED @ 300 - 400 UNITS. CONNECTION GAS FR/ 10254' - 860 UNITS. MU BHA. TEST MWD,OK. TIH TO CSG SHOE. SLIP & CUT 101' DRLG LINE TIH FILL DP @7172'. CONTINUE TIH TO 9630' WASH 9630' - 9727' + LOGGING W/MWD DRLG (RTRY) FR/9727 - 10115 FT. DRLG 9648' - 9707' CIRCULATE. CLEAN SUCTION SCREEN ON #1 MUD PUMP. ATTEMPTING TO SLIDE 9707' - 9715' DRLG 9715' - 9727' SLOW PENETRATION RATE , UNABLE TO GET ANY DIFFERENTIAL ON MUD MOTOR. PUMPED SWEEP & TRIED VARIOUS WEIGHTS & ROTARY SPEEDS. BACKREAM OOH TO 13 3/8 SHOE. CIRC AT SHOE & PUMP DRY JOB. FINISHED POOH. DOWNLOAD CDR. LD ANDERGUAGE STAB & EXP MOTOR. PU USED LOW SPEED MUD MOTOR. MU NEW BIT #11, ORIENT MWD/MTR & START TIH. CONTINUE POOH W/TOP DRIVE 8670' - 3780' TO JUST BELOW CSG SHOE. CBU @3780' - CK FLOW NONE. PUMP SLUG POOH POOH LD BIT. DOWNLOAD MWD. CHECK BIT, NO DAMAGE. NORMAL WEAR. PULL WEAR BUSHING. SET TEST PLUG. WEEKLY BOP TEST, ALL OK. PULL PLUG & SET WEAR BUSHING. ~NOTE: BLAIR WONDZELL STATE OF ALASKA OIL & GAS WAIVED WITNESS OF TEST. Page 16 of 33 Operation Summary Thursday, October 30, 1997 Well: NORTH COOK INLET UN Date From Hrs 08/30/97 13:30 0.5 14:00 3 O8/29/97 08/28/97 O8/27/97 08/26/97 17:00 4.5 21:30 1.5 23:00 1 00:00 14:00 16:00 20:00 21:00 00:00 00:30 02:00 15:00 16:00 16:30 17:00 19:30 20:30 00:00 03:00 05:00 05:30 07:30 08:30 10:30 11:30 00:00 12:30 13:30 14:30 15:30 IT B-1 (D0124) Operation Date: 1997-06-05 to 1997-10-22 SAFETY MEETING AFTER CREW CHANGE CHANGED OUT MWD TOOL. P/UP ANDERGUAGE ADJUSTABLE STABILIZER ON TOP OF MOTOR & MU NEW PDC BIT. PROGRAM MWD & FLOW TESTED SAME. TIH TO 9526 FT (HOLE SLICK). WASH & REAM TO BOTTOM. CIRC B/UP. 756 UNITS TRIP GAS. BREAK BIT IN W/LOW WT. DRILL (RTRY) FR/9641 TO 9648 FT. 14 DRILLED (RTRY) FR/9357 - 9576'. 2 DRILLED (SLID) FR/9576 - 9581'. 4 DRILLED (RTRY) FR/9581 - 9641'. 1 CIRC BOTTOMS UP. 3 BACKREAM OOH. BIT DEPTH @ MIDNIGHT 8576'. 0.5 DRLG 9006' - 9039' 1.5 SLIDE 9039' - 9054' 13 DRLG 9054' - 9245' 1 RIG REPAIR. CHANGE SWAB MP #2. 0.5 DRLG 9245' - 9257' 0.5 RIG REPAIR. CHANGE SWAB MP#1. 2.5 DRLG 9257' - 9296'. 1 RIG REPAIR. CHANGE SWAB MP #2. 3.5 DRLG 9296' - 9357'. 2 0.5 2 1 2 1 12.5 12.5 1 1 1 6.5 RACK BACK DC'S. LD MOTOR, NM PONY DC'S & ANDERGUAGE ADJ STABILIZER. PU 9 1/2" EXP MOTOR & PDC BIT. DOWN LOAD CDR TOOL, TEST MWD & TIH TO 13 3/8" SHOE. ADJUST BRAKES AND SERVICE RIG. FINISHED TIH. CIRCULATE AT REDUCED RATE - SHAKERS OVERLOADED. DRLG (RTRY) FR/8701 TO 8727 FT. CIRC & WORK PIPE WHILE CHANGE SWAB IN MP//2. DRLG (RTRY) FR/8727 FT TO 9006 FT. ROTARY & SLIDE DRILL F/8375-8678 MUD PUMP DOWN, CIRC & WORK PIPE, REPLACE SWABS. ROTARY DRILL F/8678-8701 ', HIGHER PUMP PRESSURE AND TORQUE. CIRC BTMS UP. BACK REAM TO SHOE. Page 17of33 Operation Summary Thursday, October 30, 1997 Well: NORTH COOK INLET UNIT B-1 (D0124) Date: 1997-06-05 to 1997-10-22 Date From Hrs Operation 08/26/97 08/25/97 08/24/97 08/23/97 O8/22/97 08/21/97 22:00 00:00 1 01:00 1.5 02:30 1 03:30 20.5 00:00 13 13:00 0.5 13:30 5 18:30 3.5 22:00 2 00:00 0.5 00:30 1.5 02:00 3 05:00 6 11:00 2.5 13:30 0.5 14:00 10 00:00 15 1 5:00 0.5 15:30 0.5 16:00 1.5 17:30 0.5 18:00 2.5 20:30 0.75 21:15 1.25 22:30 0.75 23:1 5 0.75 00:00 1.5 01:30 1.5 03:00 1.5 04:30 0.5 05:00 0.5 2 PUMP DRY JOB AND POH F/BIT & BHA. SLIP & CUT DRILLING LINE. RIH W/NEW BIT. LOG W/CDR F/7500-7640' SLIDE & ROTARY DRILL F/7640-8375',5.5 HR SLIDING 11.75 HR ROTATING. SLIDE & ROTARY DRILL F/7350-7640', ERRATIC TORQUE & LOSS OF PENETRATION. CIRC BTMS UP. POH, L/D STAB & BIT, TIGHT @ 7292-6730',4772-4491 '. DRESS BIT,P/U ANDERGAUGE ADJUSTABLE STAB & XO, ORIENT & RETRIEVE CDR DATA, TEST MWD. RIH TO 3746' POOH TO 5687' - TIGHT. BACKREAM OUT 5687 - 4422'. FINISHED POOH. REMOVE BLADE FR/MUD MOTOR, LD MOTOR, BIT & XO. PU NEW BIT & MTR. INST STAB ON MOTOR. SET MTR @ 1.15 DEG & ORIENT SAME. TIH W/HWT & PU 5 MORE JTS HWT. RIH TO 6826' REAM F/6826-6896' SLIDE & DRILL F/7350-7640' DRILL & SLIDE F/5892-6751 ', LOST TURBINE POWER CIRC 8TMS UP SHORT TRIP PULL F/6751-6383' CAME TIGHT BACK REAM @6783' RIH, LOG F/6741-6751' DRILL & SLIDE F/6751' ClRC @ SLOW RATE & MOVE PIPE WHILE SOLAR GENERATOR DOWN F/45 MINUTES DRILL & SLIDE TO 6896' CIRC BTMS UP, PREP TO POH POH F/BHA CLEAR FLOOR. MU BIT. PU STB, MWD - ORIENT SAME. TIH 4000' TEST MWD TIH TO 4296' TEST MWD. OK. TIH TO 5712' WASH & REAM 5712' - 5767' Page 18 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 08/21/97 08/20/97 08/19/97 08/18/97 05:30 2.5 08:00 1.5 09:30 0.5 10:00 2 12:00 2.5 14:30 4 18:30 1 19:30 2.5 22:00 0.75 22:45 1.25 00:00 3.5 03:30 0.5 04:00 2.5 06:30 0.5 07:00 1 08:00 '0.5 08:30 1 09:30 0.5 10:00 1 11:00 0.5 11:30 3 14:30 4 18:30 5 23:30 0.5 00:00 3 03:00 7.5 10:30 8.5 19:00 3.5 22:30 1 23:30 0.5 00:00 06:00 07:00 ATTEMPT DRLG. BIT BALLED UP . PUMP 35 #/BBL NUT PLUG SWEEP, PUMPED 30 BBL WTR & THINNER, ATEMPTED TO GET BIT TO DRILL FAILED. DRILLED 5767' - 5787' CIRCULATE & MIX DRY JOB TO POOH FOR BIT CHANGE. POOH 4 STDS. TIGHT COMING OFF SLIPS. TIGHT @5543' SCREW IN TOP DRIVE & BEGIN BACKREAM INTO CSG. BACKREAM F/5543-4235' POH F/4235-3683', PUMP DRY JOB, STOP & TURN OFF CDR BATTERIES. PULL WEAR BUSHING, TEST BOPE, INSTALL WEAR BUSHING. M/U BIT, RETRIEVE CDR DATA & REPROGRAM TOOLS, CHECK ORIENTATION. RIH TO 5730' LOG & REAM F/5730-5787' ROTARY DRLD F/5787-5892' DRLD F/4899-5081 SLIDE F/5081-5101' DRLD F/5101-5267' SLIDE F/5267-5307' DRLD F/5307-5360' SLIDE F/5360-5400' DRLD F/5400-5454' SLIDE F/5454-5494' DRLD F/5494-5548' SLIDE F/5548-5578' DRLD F/5578-5767' POH, BACKREAM TO 4528', PULL TO 3683' PUMP SLUG, POH L/D 10' LEAD CLR & STAB, HEAVY CLAY BALLING ON HWDP, STAB & BIT, CHANGE OUT MWD/CDR BATTERIES M/U BIT & BHA CLEAR TOP DRIVE OF PARTS & TOOLS, CLEAR FLOOR, WORK ON PIPE RACK, R/U TO PICK UP DP, INSTALL SHIMS #2 DISCHARGE MANIFOLD. P/U 72 STDS DP & STAND BACK IN DERRICK. SERVICE RIG, MONITOR WELL AWAITING TOP DRIVE PARTS. INSTALL TOP DRIVE BRAKE PADS, HUB AND AIR LINES, TEST SAME. RIH W/DRLG ASSY F/CSG SHOE TO 4847' ROTARY DRLD F/4847-4899' 6 SLIDE F/4463-4644', AST 5 HR 1 CIRC-BTMS UP, MIX DRY JOB 1 BACKREAM TO SHOE, TIGHT OUT FIRST 4 STDS, 60-90K OVERPULL Page 19 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 08/18/97 08/17/97 08/16/97 08/1 5/97 08:00 4 12:00 2 14:00 1 15:00 0.5 15:30 2.5 18:00 1.5 19:30 0.5 20:00 4 00:00 2 02:00 4 06:00 0.5 06:30 1 07:30 1 08:30 0.5 09:00 1.5 10:30 1.5 12:00 12 00:00 5.5 05:30 1 06:30 2.5 09:00 1 10:00 0.5 10:30 1.5 12:00 2 14:00 1 15:00 1 16:00 2.5 18:30 4.5 23:00 I 00:00 13.5 13:30 1.5 15:00 2 17:00 3 20:00 2.5 22:30 1 PUMP DRY JOB, POH, L/D BIT, CHANGE ORIENTATION ON MUD MOTOR & ORIENT, RIH (PORTION OF A BOTTOM BIT BLADE MISSING) RIH W/MILL TOOTH BIT ON MOTOR BHA ASSY TO 3683' SLIP & CUT 100' DRLG LINE RIH, REAM F/4620-4644' DRLD F/4644-4847', BACK BRAKE ON TOP DRIVE LOCKED UP. CIRC, MIX & PUMP DRY JOB POH TO 3683' IN CSG. REMOVE TOP DRIVE MOTOR BRAKE, REMOVE AIR HOSES LEVEL DERRICK P/U DP, RIH TO 3760' WASH & REAM F/3760-3780' MOTOR DRLG F/3780-3820' CHANGE SHAKER SCREENS, CIRC SLOW & WORK PIPE ,DRLD F/3820-3823' WORK/CLEAN SHAKER SCREENS MOTOR DRLG F/3823-3881' CLEAN SHAKER SCREENS MOTOR DRLG F/3881-4463' P/U BHA, CHANGE SETTING ON MOTOR, ORIENT, RIH ON HWDP P/U DP, TAG HARD @980', WORK DOWN TO 985' POH, STD BACK MWD & MOTOR, CLEAR FLOOR. MAKE UP MILL TOOTH BIT & BIT SUB, RIH TO 932' WASH & REAM CMT F/932-1025' RIH, TAG CMT @3649' DRILL HARD CMT F/3649'-THRU FLT CLR & FLT SHOE & 10' NEW HOLE TO 3780' CIRC & COND MUD PERFORM LOT W/HALLIBURTON, 14.46 PPG EQUIV MUD WT POH F/DRLG ASSY MAKE UP PDC BIT, MOTOR & MWD & TEST SAME, MAKE & BREAK ALL HWDP CONNECTIONS. CONT. RIH W/BHA, PICKING UP DP SINGLES. CONT. TEST BOPE. INITIAL TEST OF 10 K MANIFOLD, STACK. SET WEAR BUSHING, R/D TEST EQUIP CENTER RIG OVER HOLE. CHANGE OUT & TEST UPPER I8OP ON TOP DRIVE. INSTALL ROOF CAP OVER CHOKE MANIFOLD & INSTALL .-~h~,~'a~ STIP-O-MATIC. R/U & TEST CASING TO 4000 PSI. Page 20 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 08/15/97 08/14/97 08/13/97 08/1 2/97 08/11/97 08/10/97 08/09/97 23:30 0.5 P/U BHA & RIH 00:00 24 00:00 24 00:00 24 00:00 8 08:00 5.5 1'3:30 10.5 00:00 5 05:00 1.5 06:30 15 21:30 2.5 00:00 04:00 06:00 08:00 BUILDING 10,000# CHOKE MANIFOLD WITH RELATED WELDING, ETC. CONTINUE NU BOP'S & BUILDING l OK CHOKE MANIFOLD. CONTINUE BUILDING 10,000# CHOKE MANIFOLD & NU BOP'S. DRAINED & CLEANED MUD PITS. CHANGED PUMP LINERS FROM 6 1/2" TO 6". CONTINUE RU OF 10,000# CHOKE MANIFOLD & 3RD BARITE TANK. RD SLICKLINE & RU SCHLUMBERGER. ATTEMPT 1 3/8" DUMMY RUNS ON BOTH 2 3/8" INJECTION STRINGS W/N SUCCESS. 2550' & 2600' MAX PROG. CONTINUE BUILDING 10,000# CHOKE MANIFOLD & NU 10,000# BOP STACK. TROUBLE GETTING TEST ON VOID SECTION OF MULTI-BOWL WELLHEAD, MANAGED TO GET SEAL COMPRESSED & GET A TEST. MADE UP FLANGED OUTLETS ON INJECTION STRINGS, MADE UP TUBING RISER FOR WIRELINE WORK. RU SCHLUMBERGER & ATTEMPT TO RIH W/DUMMY-GAMMA RAY W/NO SUCCESS. UNABLE TO GET PAST 1076' ON ONE STRING & 1930' ON THE OTHER STRING. TRIED DIFFERENT HOOK UPS W/NO SUCCESS. RU SLICK LINE & ATTEMPT TO GET DOWN WITH 1 1/2" TOOLS W/NO SUCCESS. TRIED DIFFERENT HOOK UPS INCLUDING IMPRESSION BLOCK W/NO OBVIOUS INDICATIONS OF TBG DAMAGE. TBG APPEARS TO BE CORK SCREWED IN THAT JAR ACTION IS NOT EVIDENT AS LINE PULL INCREASES. SLICK LINE PROGRESS = 1768' & 1538'. UNABLE TO GET ANY DEEPER. CHANGING OUT RIG 5000 # CHOKE MANIFOLD WITH 10,000 # MANIFOLD. ALSO, HOOKING UP 3RD BARITE TANK, PRESENTLY ATTEMPTING TO LOCATE 1" TUBING FOR CLEAN OUT OF 2 3/8". 4 FINISHED CEMENTING 13 3/8" CASING WITH 115 BBLS OF 1 2.0 PPG CEMENT RETURNED AT SURFACE. BUMPED PLUG W/CALCULATED AMOUNT OF MUD & TESTED CASING TO 2000 PSI FOR 30 MIN. OK. CIP AT 0315 HRS. CEMENTING DETAILS AS PER CEMENT .. REPORT. 2 BACK OFF AT RUNNING TOOL & LD SAME W/LANDING JOINT. RD RUNNING TOOLS & CLEAR FLOOR. 2 PU STD OF DP W/TOP DRIVE & WASH CEMENT F/TOP OF HANGER. 7 ND BELL NIPPLE & DIVERTER SYSTEM Page 21 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 08/09/97 08/08/97 08/07/97 08/06/97 08/05/97 15:00 7.5 22:30 1.5 00:00 17.5 17:30 3 20:30 1 21:30 2.5 00:00 00:00 02:00 08:00 RIG WELDER MODIFIED INJECTION STRING OUTLETS ON WELLHEAD TO ACCOMMODATE WIRELINE ENTRY. INSTALLED SEALS & MADE CUTS TO TBG TOPS. INSTALL & NU ABB VETCO-GRAY MULTI-BOWL WELLHEAD. INJECTED SEALANT & TESTED SEALS & VOID. CONTINUE IN HOLE W/13 3/8" CASING WITH ATTATCHED 2 3/8" INJECTION STRINGS TO 3760'. CIRC BU. RU HALLIBURTON & HELD SAFETY MEETING. PUMPED 50 BBL FW SPACER & TEST LINES TO 3000 PSI. STARTED CEMENT JOB BY PUMPING LEAD. 2 FINISHED LAYING DOWN BHA. 6 RU WEATHERFORD & HELD PRE JOB SAFETY MEETING. 16 RUNNING 13 3/8" CSG W/DUAL 2 3/8" INJECTION STRINGS. 34 JTS OF 13 3/8" 72//, L80, SLX CASING W/ATTATCHED 2 3/8", 4.7//, N80, BTS TBG RUN BY RPT TIME. 00:00 2.5 02:30 2 04:30 12 16:30 1.5 18:00 2.5 20:30 1 21:30 2.5 00:00 5 05:00 4 09:00 1 10:00 2 12:00 2 14:00 2 16:00 1.5 CONTINUE DRILLING & SURVEYING F/ 3018' TO 3285'. POOH TO CSG SHOE & REPAIR LEAK IN UNION ON GOOSE NECK. RUN BACK TO BTM. SLICK HOLE. CONTINUE DRLG F/3285' TO 3770' TD. CIRC HOLE CLEAN W/SWEEP. BACK REAMED TO CSG SHOE AT 2579 FT W/NO PROBLEMS. CIRC BU F/SHOE. POOH & LD BHA. CONTINUE NU DIVERTER & RISER. FUNCTION TEST DIVERTER. MU BHA W/18.5" BIT TEST KELLY VALVES, FLOOR VALVES, SAFETY VALVES 250/5000// TEST BULK BARITE SYSTEM. MIX DRY JOB TO TEST SYSTEM. ALL WORKING OK. TIH TAG CMT @2518' DRLG SOFT CMT 2518' - 2535' FLOAT COLLAR. DRLG HARD CMT 2535' - 2567' CIRCULATE & CONDITION MUD. MUD RUN OVER BELL NIPPLE & SPILL INTO BOP ROOM. CLEAN SPILLAGE & SLOW DOWN PUMP RATE. Page 22 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 08/05/97 08/04/97 O8/O3/97 17:30 6.5 00:00 1.5 01:30 0.5 02:00 1 03:00 1 04:00 2 06:00 1.5 07:30 6 13:30 1 14:30 1.5 16:00 6 22:00 2 00:00 5 05:00 3 08:00 1 09:00 1 10:00 1 11:00 11.5 22:30 1 23:30 0.5 DRILL OUT SHOE AT 2579'. CONTINUE DRILLING & SURVEYING F/2579' TO 3013'. FINISHED CIRC BU AT 8,0 BPM W/150 PSI. NO LOSSES. HUNG OFF CSG ON HANGER W/310,000 LBS, DRAINED & FLUSHED BETWEEN CSG & RISER FOR VIEWING PROPER BACK OFF OF LANDING JT THROUGH WELLHEAD VALVE. BACK OFF & LAY OUT LANDING JTS. RD ALL CASING TOOLS FROM FLOOR. MU .CEMENT SUB/STINGER & RIH ON DP W/BTM JOINT STABILIZED, PU PUP JT & MU CIRC HOSE. BREAK CIRC AT 5 BPM W/60 PSI, STING INTO FC AT 2534'. TEST HB LINES & PUMP 50 BBL FW SPACER AT 8 BPM W/468 PSI, TOOK RETURNS OUT TWO 4" LINES FROM WELLHEAD, SHUT DOWN & HELD PRE JOB SAFETY MEETING. TESTED LINES & PUMPED 50 BBLS OF WATER SPACER. MIXED & PUMPED 1690 SX OF LEAD CMT AT 12,0 PPG, FOLLOWED WITH 700 SX OF TAIL AT 15,8 PPG, DISPLACED DP W/39 BBLS OF MUD. DETAILS AS PER CMT RPT. FULL RETURNS WITH GOOD CEMENT TO THE SURFACE, CIRC DP CLEAN. SLUG PIPE, POOH. RD DIVERTER LINES & SUPPORTS TO DIVERTER & PAN UNDER FLOOR. PU RISER & DIVERTER, CLEANED UP HANGER TOP & INSTALLED PACK OFF W/RING GROOVE PROTECTOR. SET RISER & DIVERTER BACK DOWN. FINISH OUT OF HOLE WITH DRLG ASSEMBLY, LOTS OF GUMBO ON BHA, RU WEATHERFORD CSG EQUIPMENT & HAVE PRE JOB SAFETY MEETING, PU VETCO HANGER JOINT, BREAK CONNECTION & CHECK OUT SAME. LD HANGER JT. MAKEUP SHOE JT & 2ND JT OF 20" CSG, WEATHERFORD CSG TONGS BROKE DOWN. REPLACE TONGS & POWER UNIT, FINISH RUNNING 20", 133#, K55, BT&C CASING TO 2579'. RAN 62 JTS TOTAL PLUS HANGER JT & PUP. INSTALLED CENTRALIZERS AS PER PROCEDURE. LANDED CSG ON WELL HEAD HANGER. REMOVED FILL UP TOOL. INSTALLED PUMP IN SWEDGE & MU HOSE. PU HANGER 2' & START CIRCULATING Page 23 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 08/02/97 08/01/97 00:00 8.5 08:30 1.5 10:00 1 11:00 1.5 12:30 1 13:30 2.5 16:00 1.5 17:30 2 19:30 4.5 00:00 01:30 1.5 03:00 0.5 03:30 04:30 CONTINUE DRLG & SURVEYING 1930' - 2583' TORQUE & DRAG INCREASING, WORK PIPE SEVERAL TIMES, OK. PUMP 50 BBL HI VIS SWEEP & CBU DRLG & SURVEY 2583' - 2646' TD 20" CSG POINT PUMP 50 BBL HIVIS SWEEP/CBU SD PUMPS. MONITOR WELL. WORK PIPE CHECKING HOLE FOR FILL, NONE. CBU. SPOT 100 BBL HIVIS PILL ON BOTTOM. POOH 12 STD SHORT TRIP. DRAG INTERMITTENT TO 60000# TIH WASH DOWN LAST 3 STDS WHILE ROTATING . OK. NO FILL. BACK REAM OUT OF HOLE . OK TO 1400'. HAD TO WASH & REAM TIGHT HOLE FROM 1400' TO 1200'. OK. HAD TO CHANGE SHAKER SCREENS DUE T MUD LOSSES FROM THICK MUD. BUILDING MORE MUD VOLUME. 1.5 CLEANED OUT 5' OF FILL & DRILLED F/530' TO 545'. RU & RUN GYRO. 0.4 DEGREE ANGLE. DRILLED F/545' TO 670' . RUN GYRO WITH 0.7 DEGREE ANGLE. TRY MWD WITH GOOD ANGLE READING BUT NO GOOD AZMUTH READING YET. 1 DRILLED F/670' TO 790'. 1 ATTEMPT SURVEY W/MWD BUT STILL TOO MUCH INTERFERENCE. DRILL TO 820' & RUN GYRO. 1.9 DEGREE ANGLE. 07/31/97 05:30 1.5 07:00 1.5 08:30 11.5 20:00 1.5 21:30 2.5 06:00 2 08:00 0.05 08:30 3.5 12:00 4 16:00 4 20:00 4 CONTINUE DRILLING F/790' TO 960'. CIRC OUT & POOH FOR REMAINING HWDP & JARS. PU SAME. DRILL & SURVEY F/960' TO 1775'. SURVEYING WITH MWD FROM 1029'. REPAIRING POP OFF VALVE ON # 2 MUD PUMP. CONTINUE DRILLING & SURVEYING F/ 1775' TO 1930'. BIT WANTING TO WALK RIGHT, HAVING TO HOLD HARD LEFT TO MAINTAIN DIRECTION. LOTS OF GUMBO. SWEEPING HOLE AS NEEDED. DRLG 467' - 530' SURVEY W/MWD TESTING TOOL, GETTING MAGNETIC INTERFERENCE POOH TO PU DRLG MOTOR. PU DRLG MOTOR, 2 DEG BENT SUB, 18.5" STABILIZER. MAKING UP TOOLS THREADS GALLED ON SUB & STABILIZER. ATTEMPT BREAK OUT BENT SUB FROM MOTOR, FAILED. LD MOTOR,SUB,STABILIZER. TUBOSCOPE THREAD INSPECTOR ARRIVED RIG. CHECKED ALL CONNECTIONS ON EQUIPMENT TO BE RUN IN HOLE. NO DEFECTS OR PROBLEMS FOUND. PU NEW MOTOR, 2.5 DEG BENT SUB, STABILIZER & MAKEUP SAME WITHOUT ANY PROBLEMS. RIH TO BTM WITH5' OF FILL AT 525'. Page 24 of 33 Operation Summary Thursday, October 30, 1997 Well: NORTH COOK INLET UN Date From Hrs O7/3O/97 06:00 6 O7/29/97 12:00 6.5 18:30 2 20:30 7 03:30 0.5 04:00 2 06:00 24 Date: 1997-06-05 to 1997-10-22 IT B-1 (D0124) Operation FINISH OFFLOAD 20" CSG FROM WORKBOAT. CONTINUE WELDING PROJECTS. WORKING ON PLATFORM MUD PITS. RIG UP HOSE TO JET FLOW LINE. PU 153 JTS 5" DP & STD IN DERRICK TURN KELLY HOSE ON TOP DRIVE & ADJUST SAME. ORIENTATE CAMERAS FOR TOP DRIVE. PU 24" BIT , MWD, DCS, & HWDP TO CLEANOUT 30" . TIH TAG @373' CLEANOUT 373' - 405' END OF 30" CSG. OPEN HOLE. SPUD WELL 0400 HRS. 07/30/97. DRLG 405 - 467' @REPORT TIME. CONTINUE RIGGING UP SCHLUMBERGER MWD UNIT. SPOT BAKER MUD LOGGING UNIT & RIGGING UP SAME. FINISH INSTALLING STORM CLAMPS ON RIG. PERFORM DERRICK INSPECTION. SERVICE TOP DRIVE. INSTALL QUICK RELEASE ON TOP DRIVE LINK TILT. RIG UP FLOW LINE TO TRIP TANK. RIG UP STAIRS TO CRANE PIPE RACK. FAB DRAINS IN MOTOR ROOM & AROUND TURBINE. MOVE MUD MATERIAL TO MUD ROOMS. OFFLOAD 1000 SXS CEMENT & 55 JTS 20" CSG, CONTINUE WORKING ON PRODUCTION MUD PITS. HAVING TO MODIFY MUD HOPPER DISCHARGE LINE INSIDE PITS. CLEAR RIG FLOOR. O7/28/97 06:00 24 REPAIR LEAKS IN KOOMEY LINE. FUNCTION TEST DIVERTER SYSTEM. FUNCTION TEST FLOW LINE VALVES & TRIP TANK VALVES. SET HALLIBURTON CEMENT AIR COMPRESSOR IN PUMP ROOM. CONTINUE WELDING PROJECTS FOR MUD TRANSFER & OVERBOARD DUMP LINES. CHECK GAS, LEL, H2S MONITORS. PUT 20' BOOM SECTION IN BAKER CRANE. INSTALL LINE FROM BULK BAR TANKS TO RIG MUD PITS. FILL PRODUCTION PITS WITH WATER, PITS LEAKING. MAKING REPAIRS. PUMP 1000 SXS CEMENT FROM WORKBOAT. RIGGING UP SCHLUMBERGER MWD UNIT. SET MOUSEHOLE. *''CALLED BLAIR WONDZELL ALASKA OIL & GAS. 07/27/97 1 200 HRS. NO ONE REQUIRED TO WITNESS DIVETER FUNCTION TEST. '''ETA SPUD WELL 0600 07/30/97. O7/27/97 06:00 24 CONTINUE RIG UP 30" RISER, DIVERTER SPOOL, 16" KNIFE VALVE, 16" DIVERTER LINE, BELL NIPPLE, INSTALL TURN BUCKLES & ALIGN STACK. WORKING ON WELDING PROJECTS IN PLATFORM PITS. INSTALL MUD TRANSFER LINE FROM RIG MUD PITS TO PLATFORM MUD PITS. RU BARITE SUPPLY LINE TO BARITE TANKS ON PRODUCTION DECK. WORKBOAT OFFLOAD 1350 SXS BARITE. MIX & PRE HYDRATE 400 BBLS BENTONITE IN RIG MUD PITS. WORKING ON ACCUMULATOR LINES TO STACK. Page 25 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 07/26/97 06:00 24 COMPLETE WELDING ON ALT-2 WELLHEAD. CONTINUE HOOKUP CEMENT & BULK BARITE LOADING LINES & MANIFOLDS. WORKING ON MUD PITS. INSTALL SERVICE LINES BETWEEN RIG & UTILITY MODULE. INSTALL AIR EXHAUST DUCT UNDER PIPE RACK FOR PLATFORM PITS. FINISH HANGING HOSES FOR NORTH PLATFORM LOADING STATION. CHANGE BRUSHES ON DRAWWORKS TRACTION MOTORS. CLEANING OUT PRODUCTION MUD PITS & WORKING ON OVERBOARD DUMP LINES. CIRCULATE BRAKE WATER COOLANT SYSTEM FOR LEAKS. NIPPLE UP 2 30" RISERS & PREPARE TO LOWER IN WELLROOM. 07/25/97 06:00 24 PULL WIRE FOR MAIN AUGER, TEST SAME, TRIAL RUN AGITATORS & SHALE SHAKERS. HOOK UP AUTOMATIC GREASE SYSTEM ON AUGER & TEST SAME. INSPECT DUMP LINES ON PITS & UNPLUG OVERBOARD DRAINS IN PITS. CIRCULATE WITH CENTRIFUGAL PUMPS THRU EQUIPMENT & LINES, REPAIR LEAKS. SET ALT-2 WELDHEAD IN WELLROOM. CUTOFF COVER PLATE & DRESS CONDUCTOR PIPE, REBEVEL ALT-2 & PREPARE TO WELD ON SAME. START RIG UP BARITE TANKS. OFFLOAD LOGGING UNIT & MWD BUILDINGS. HOOKUP SENSORS ON MUD MANIFOLD & TEST SAME. HOOKUP DRAIN SYSTEMS ON BMC CRANE PIPE RACK & IN MOTOR ROOM.I 07/24/97 06:00 24 INSTALL HANDRAILS ON BMC CRANE PIPE RACK. CLEAN OUT ROD OILER TANK #1 MUD PUMP. HOOK UP BLOWER MOTOR HOSES, INSTALL SAFETY BOLTS ON SOUTH SIDE UTILITY MODULE STAIRWELLS, WORK ON IRON ROUGHNECK. CLEAN UP IN MUD PITS & INSTALL GRATING. DRESSING SHALE SHAKERS. STRING GEOLOGRAPH. INSTALL PIT WALL & MAKE PENETRATIONS FOR LINES. HOOKUP 4" HIGH PRESSURE LINE FROM RIG TO UTILITY MODULE. CHECK OUT #1 & #2 CHARGE PUMPS, MUD CLEANER, DESANDER,MUD GUNS,ETC. UNLOAD WORKBOAT, DIRECTIONAL EQUIPMENT, 160 JTS 5" DP,DCS, HANDLING TOOLS , Page 26 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 07/23/97 06:00 24 INSTALL PANELS ON CRANE STRONGBACK. CLAMP DOWN & INSTALL HANDRAILS. WORK ON MUD PUMP, TOP DRIVE COUNTER BALANCE SYSTEM, BULK BAR SYSTEM. ASSIST APOLLO RIG UP EQUIPMENT. HOOK UP BLOWER HOSES ON SKID UNDER TURBINE. INSTALL HANDRAILS ON BACKSIDE OF TURBINE, RU DERRICK CLIMBER. MAKEUP & INSTALL SERVICE HOSES IN SUB. CONTINUE HOOKUP SERVICE & UTILITY LINES. O7/22/97 07/21/97 07/20/97 07/19/97 06:00 24 06:00 24 06:00 24 06:00 24 INSTALL FLUID END ON PUMP//2. REMOVE SAME. TAP OUT BOLT HOLE INSTALL SAME OK. TEST KOOMEY AND REMOTE STATIONS, OK. HOOK UP KOOMEY HOSES. FIX OIL LEAK ON TURBINE. INSTALL BRACES ON CAT EXHAUSTS, INSTALL GUARDS ON DRWKS. TEST WATER PUMP, OK. UNLOAD CONEX BLDGS. HANG KELLY HOSE CLAMPS IN DERRRICK. CHANGE OUT SAVER SUB. OFF LOAD BOAT. BEGIN SET PIPE PANELS ON CRANE PEDESTAL. BEGIN MANIFOLDING CEMENT TANKS TOGETHER AND TEST RUN HALLIBURTON UNIT, ONE AIR VALVE AND ONE HYDRAULIC VALVE INOPERABLE, WILL REPLACE. FAB UP AUGER DISCHARGE TO OVER BOARD LINE. CONTINUE WITH VARIOUS WELDING PROJECTS. ELECTRICAL POWER INSTALLED IN CAMP. SEWER DRAIN IN PLACE. HOOKING UP POT WATER AND SRINKLER WATER. SKID CRANE AND CRANE BASE. INSTALL BELT GUARDS ON MUD PUMPS. ASSIST IN RU OF APOLLO CUTTINGS UNIT. WORK BOAT. CLEAN OUT DEGASSER. SET LOWER BEAM IN CRANE PEDESTAL. CLEAN DECKS ON PIPE RACK, SET CONEX'S ON PIPE RACKS. FILL KOOMEY UNIT. SET ONE PIPE PANEL ON CRANE STRONG BACKS. HANG LIGHTS UNDER CRANE. CONTINUE HOOK UP UTILITIES TO CAMP. INSTALL WINDWALL ON HYDRAULIC MODULE. SET UP LIGHTS ON UTILITY MODULE PIPE RACK. WORK ON HYDRAULIC SYS OF IRON ROUGHNECK. INSTALL BOILER EXHAUST. INSTALL FLUID END ON PUMP//1. SET UP EXTERIOR LIGHTS ON CAMP. FINISH HOOK UP UTILITY MODULE WATER LINES AND FILL WATER TANK. CHECK AND FILL KOOMEY BOTTLES W/NITROGEN. PULL MIDDLE FLUID END OFF PUMP #2. PREPARE TO REPLACE SAME. UNLOAD BOAT. CONTINUE RU UTILITIES TO CAMP AND FINISH INTERIOR TO SAME. SET MATTING BOARDS FOR CAMP. INSTALL EXHAUST EXTENTIONS FOR CATS. INSTALL FLOWLINE SUPPORTS. INSTALL VIBRATING HOSE ON MUD LINE. SET CAMP UNITS, BEGIN HOOK UP UTILITIES TO SAME. INSTALL PVT PROBES IN PITS. HOOK UP UTILITY HOSES FROM PLATFORM TO UTILITY MODULE. FINISH INSPECT TOP DRIVE. Page 27 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 07/18/97 07/17/97 07/16/97 07/15/97 07/14/97 06:00 24 06:00 24 06:00 24 06:00 24 HOOK UP LIGHTS ON PIPE RACK. WORK ON PUMPS. INSTALL FLOWLINE. MAKE MODIFICATION FOR UTILITY MODULE. WELDERS WORKING TO RIG UP APOLLO CUTTINGS GRINDER. PUT POOL GRAY IRON ON PLATFORM CAMP STRUCTURE. BOLT DOWN SAME. SET WALK ALONG ONE EDGE OF CAMP. WORK BOAT. HOOK UP HYDRAULIC TO IRON ROUGHNECK. WORK ON PLATFORM PITS AND HALLIBURTON UNIT. HOOK UP DRAIN SYS ON OUTSIDE OF UTILITY MODULE. HANG WINDWALL ON HYDAULIC HOUSE. INSTALL LIGHTS ON OUTSIDE OF RIG. INSTALL SCAFFOLDING SUPPORT IN BOP ROOM. HOOK UP MUD LINE IN CELLAR. PULL WIRE FROM CHARGE PUMPS TO CONTROL PANEL. INSTALL PIPE HANDLER ON TOP DRIVE. HOOK UP HYDRAULIC LINES IN DERRICK. WORK ON MUD PUMPS INSTALL LINERS AND SWABS. SET APOLLO CUTTINGS GRINDER IN PLACE. INSTALL KILL LINE, CMT LINE AND CHOKE LINE IN SUBBASE. HANG STABBING BOARD. INSTALL HEATERS AND LIGHTS ON RIG FLOOR. INSTALL IRON ROUGHTNECK PREPARE TO HOOK UP HYDRAULICS TO SAME. HELP SET CAMP STRUCTURE IN PLACE. RU RIG STRUCTURE FOR CAMP PREPARE SET SAME. SKID CRANE AND PEDESTAL. INSTALL FLOWLINE TO GAS BUSTER. INSTALL COUNTERBALANCE CYLINERS AND BLOWER DUCTS ON TOP DRIVE. OFF LOAD CAMP SUPORTS FROM WORK BOAT. RU LINK TILT ON TOP DRIVE. INSTALL IBOP IN TOP DRIVE. SET CAMP SUPPORTS. 07/13/97 07/1 2/97 06:00 24 06:00 24 06:00 24 INSTALL MUD LINE, PUMP AND CEMENT MANIFOLD. HOOK UP BLEED OFF MANIFOLD. INSTALL SMT HOSE AND STANDPIPE HOSE. PICK UP HOOK. MOVE STAIRS TO RIG FLOOR. HOOK UP GAS BUSTER VENT LINE UP DERRICK LEG. PU SWIVEL AND SPLINE SHAFT. PICK UP TOP DRIVE AND MAKE UP SAME. WORK BOAT. PULL WIRE TO UTILITY MODULE. INSATLL UPPER SUB BASE CLAMPS. PLUMB DIESEL LINE FROM PRODUCTION TO UTILITY MODULE. INSTALL ACTUATOR ON DIVERTER LINE KNIFE VALVE. HOOK UP PLUMBING TO MOTOR ROOM. RU TRIP TANK VALVES. PLUMB AIR LINES TO 399;S. PULLED DC WIRES TO DRWKS. TEST DRWKS MOTORS. STRUNG DRLG LINE. WORK ON TURBINE EXHAUST. SKID BMC//9 TO MIDDLE OF SUPPORT BEAMS. SKID CRANE STRUCTURE AND TIGHTEN CLAMPS SKID CRANE TO OPERATING POSITION AND TIGHTEN BOTLS. SKID RIG FLOOR OVER WELL AND SECURE SAME. PULL ELECTRICAL CABLES. WORK ON TURBINE EXHAUST. CONTINUE WELDING AND ELECTRICAL PROJECTS. Page 28 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 07/11/97 07/1 O/97 O7/09/97 06:00 24 06:00 24 06:00 24 RU DOLLY ON BLOCKS, RU RBS IN DRK. SET TURBINE AIR INTAKES IN PLACE. HOOK TURBINE AIR EXHAUST TO HEAT EXCHANGER. RU STAIRS AND LNDG .ON NORTH SIDE OF MOTOR COMPLEX. RU LNDG ON SOUTH SIDE OF MOTOR COMPLEX. SET 3 PIPE RACKS IN PLACE, BOLT DWN SAME. WORK BOAT. HANG STAIRS PUT CROWN LIGHT ON. WORK ON TURBINE GENERATOR. WORK ON MUD END OF PUMP #2. REMOVE EXHAUST STACKS FROM MECHANIC SHOP AND SET SHOP IN PLACE. RU STA IRS FRAME SURVEY DECK TO DRK. SET GRASSHOPER WIRE TRAY INPLACE, PULL ELECTRICAL WIRES IN MOTOR COMPLEX. RAISE CABLE TRAY UP BACK OF DERRICK. INSTALL ELECTRICAL AND HYDRALIC SERVICE LOOPS. RU STAND PIPE, KELLY HOSE AND TBG BOARD. WORK IN MOTOR ROOM. SET STRONG BACKS AND SET EXHAUST IN PLACE ON #1 BOILER. INSTALL WIND WALLS AROUND BOILER AND MOTORS. RIG UP MUD DOCK. HOOK UP GAS LINE TO SOUTH SIDE OF MOTOR COMPLEX. SET WINDWALLS AROUND MOTOR COMPLEX. SET AND WORK ON TURBINE GENERATOR. BEGIN HOOK UP OF EXHAUSTS ON CAT 399'S, HOOK UP GEN ON SAME.PULL WIRES AND WORK IN PUMP ROOM ON SUCTION LINE HOOK UP. SET WALK WAY AT MOTOR ROOM. 07/08/97 06:00 24 FINISH OFF LOAD BOAT. SET CAT 399 IN PLACE. SET BOILERS, TURBINE, AND RADIATOR BUILDING IN PLACE AND BEGIN HOOK UP. HOOK UP FLOW TO SHALE SHAKERS, HOOKUP UTILITY LINES IN MOTOR COMPLEX AND CLEAN WORK AREA, BEGIN UP LIGHTS. BEGIN WORK IN PIT AND PUMP ROOM. SKID CRANE AND BEGIN HOOK UP OF PORCH ON RADIATOR BUILDING. 07/07/97 07/06/97 07/05/97 06:00 24 06:00 24 06:00 24 RU HEAT EXCHANGER AND UDCK WORK TO SAME. HOOK UP DISCHARGE LINE ON CENTRIFICAL PUMPS. SET SCR HOUSE. SET A/C UNIT. HOOK LINES TO MUD PITS. INSTALL DRIP PAN ON CRANE. CONTINUE WELDING PROJECTS. OFF LOAD BOAT THIS AM. TIGHTEN BOLTS ON HEAT EXCHANGER AND RU DUCK WORK TO SAME. SET SCR HOUSE AND AIR COND. UNIT. HOOK UP CENTRIFICAL PUMPS AND LINES. WORK BOAT HOOK UP LIN ES IN PIT ROOM. WORK BOAT.SET MCC BLDG. Continue welding projects. Hookup suction lines in pump room of rig, hook up utility lines under power module. Set floor for mud pits, tighten bolts. Set both mud pumps & mud pits. Backload workboat & send to dock. Set traction motors for mud pumps & bolt down same. Workboat at dock @0300 hrs for next load. Page 29 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 07/04/97 07/03/97 07/02/97 07/01/97 06/30/97 06:00 06:00 24 06:00 24 06:00 24 06:00 24 24 Continue welding projects. Order piping & fittings to hookup Halliburton equipment. Finish skidding Baker crane in position. Install boom poles in derrick & hang windwalls around derrick board. Install floor windwalls Continue clear deck to offload boat. Set traveling blocks & hook on rig floor. Set power module skid beams - 2 for support complex. Set in center pump deck, deck with work bench, & mud pump deck. Backload boat & send to dock. Continue welding projects. Install Halliburton pump skid,bulk tank, & tear drop tank in platform pump room. Unstring Lantec winch used to raise derrick. Inspect derrick · Ru derrick ladder. Rig down dolley system used to rig up derrick sections. Removed 20' boom section from Baker//1 crane to handle heavy loads of power module. Skidding #2 Baker crane in postion to offload workboat. Clearing deck to offload power module pieces. 24 hrs Tyonek. Continue welding projects. Finsish installing boom section on #1 Baker crane for 100' boom. Raise derrick 15' install derrick board & one windwall. Loadout boom section on workboat. Rig down Unit crane cab & set on workboat. Cut off Unit crane pedestal, laydown on production deck with two cranes. Offload to workboat. Unit crane complete on workboat for shipment to Osk dock. Workboat offloaded 0300 hrs & backloaded w/traveling blocks-hook & 1st load of utility module. Installed bottom section of derrick & raised same. Continue welding projects. Work on raising derrick. Install middle section & raise same. Install lower middle section & bolt up same. Rig down boom on Unit crane. Skid Baker crane #2 on pipe rack to offload boat. Offload Halliburton cement unit, 550 cu/ft bulk tank, 80 cu/ft tear drop tank. All this equipment set on decks in preparation to set in pump room for installation. Offloading Unit crane to boat as dismantling. Present operation taking "A frame off Unit crane & also putting extra boom section in Baker crane #1 to handle installing board on derrick. Finish RU Baker Crane No. 2. Check all fluid levels & re-inspect crane. Offload /load workboat. Set derrrick crown section & crown, raise same. Set and raise upper intermediate derrick section. Set middle section & prep for raising. Continue welding projects. Working on loading stations at each end of platform for barite, cement, water, & diesel. Prepare to rig down Unit crane at report time. Boat will offload at OSK dock at 1100 hrs this AM. Page 30 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 06/29/97 06/28/97 O6/27/97 06/26/97 06/25/97 06/24/97 06/23/97 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 Continue working on welding projects. Tie substructure to platform power. Complete torqueing 3" bolts on crane structure. Install handrails and stairs. Set king post, crane cab, and gantry for No. 2 Baker crane. Bolt boom sections together. Install boom camera, connect cables, hoses between sections & inspect boom. Set and pin boom. Stringing up at report time. Boat loaded with derrick sections enroute to platform. Work completed and last piece of rig equipment shipped from Baker platform. All work completed on Baker. Unaware of any problems. Continue working on welding projects. Baker crane installed. Set and bolt top crane supports, strongbacks, walkways, and crane pedestal. Install and torque all bolts. Continue to rig down and offload power / utility module from Unocal Baker platform. Sent in two more boatloads, Continue working welding projects. Offload workobat. Set crane uprights and brace same. Offload 2nd workboat with remainder of crane pieces. Set and pin spreaders for crane. Halliburton cement unit ready for shipping. Continue working stairway / handrail modifications. Install Dril-locks on skid rams. Re-arrange equipment on all decks to facilitate rig up of Baker Crane No. 2 and utility / power module. Connection lines in substructure and rig floor. Offload trusses for Baker Crane. Continue to rig down and offload pwer / utility module from Baker Platform Continue working on stairway / handrail modifications. Offload Baker Crane pieces. String new line on Manitowoc crane. Connect steam and water to rig floor and survey deck. Connect driller's console / drawworks with air, electrical, and hydraulic lines. Continue to rig down and offload power / utility module from Baker Platform. Derrick' dolley is up and waiting on crown section. Windwalls installed. Continue to pull wiring harness. Modify stairs and RU rig floor. One crew on Unocal Baker Platform continuing to rig down power module. Tighten derrick bolts, pulled electrical cables. Hooked up chain on drawworks. Installed wind walls and roof caps. Offload workoboat and set up welding shop. Modify stairs to rig floor. Crown section of derrick being examined by DRECO for repairs. Baker crane and auxiliary generator hours, and fuel consumption being tracked. Page 31 of 33 Operation Summary Thursday, October 30, 1997 Date: 199'7-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 06/22/97 06/21/97 O6/2O/97 06/19/97 06/18/97 06/17/97 06/16/97 06/15/97 06/14/97 06/13/97 06/12/97 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 24 06:00 Attached traction motors to drawworks, hooked up electric brakes. Set choke manifold / gas buster mezzanine in place over drawworks. Set starting legs of derrick in place and bolted down same. Set ODS dog house. Unit crane pedestal ready for removal. Finish installing drawworks, installing wind wall panels. Rigging down the utility module on Unocal platform. Rig up floor. Standpipe and Koomey Unit installed. Offload drawworks and other rig floor equipment to platform and rig up same. Three pin rail extensions finished. Working on new communications tower placement beam. Base oil pump stand done, cement room all cleaned out. Unload rig floor sections from work boat. RU support beams, then rig floor. Two pin rail extensions installed. Moved transformers from area where quarters deck cantilever beams will be installed. All "black iron" substructure base beams up. All doors hung, BOP trolley installed. Unload substructure from M/V Champion. Continue rig up of substructure. Rig now two levels high. 1st = Substructure. 2nd = Trip Tank and Water Tank. Next comes the rig floor. Finish skidding lower section of BMC. Clamped down and secured same. APC continue to RU skid beam extensions. Unable to use Manitowoc crane due to cable winding. Order new Diaform 18-HSLR non rotating cable. Fabricate clamps to skid upper portion of BM Crane. Have crane inspected by Crane and Lift Inspections, Inc.. Continue rigging up Baker Marine Crane. APC crews rigging up scaffolding for pinrail extensions. Test run crane. Boat arrived at 20:00 hrs with first load of substructure. Clear deck for skidding crane. Continue rigging down and demob from Unocal Platform. Continue rigging up Baker Marine Crane. Eight more Pool personnel arrived at 15:00 hrs. Continue rigging down and demob from Unocal Platform. Rigging up Baker Marine Crane. Unload boat. Continue rigging down and demob from Unocal Platform. 6 man Pool crew arrived with Gary Smith. M/V Monarch arrived with 1st load of crane beams. Unloaded Same. 24 Continue rigging down and demob from Unocal Platform. Page 32 of 33 Operation Summary Thursday, October 30, 1997 Date: 1997-06-05 to 1997-10-22 Well: NORTH COOK INLET UNIT B-1 (D0124) Date From Hrs Operation 06/11/97 06/10/97 06/09/97 O6/08/97 O6/07/97 06/06/97 06:00 24 06:00 24 06:00 24 06:00 Continue rigging down and demob from Unocal Platform. Lowering and rigging down the derrick. Increased workforce to assist in rigging down. Billy Hayes and radio personnel installing radio and communications equipment on both workboats. Continue rigging down and demob from Unocal Platform. Second boatload to dock 0800 hrs 6/9. 10 boxes of radio equipment arrived. Material for pin rail extensions to arrive today. Platform stiffening project completed. Continue rigging down and demob from Unocal Platform. First boatload to dock 0600 hrs 6/8. Utilizing an additional crane operator on Demob for more efficient load out of boats. One constantly running from one crane to the other. 24 Continue rigging down and demob from Unocal platform. 06:00 24 12:00 18 Pool continuing to Demob rig. SCR house sent to Anchorage for modifications for cuttings grinding adaptation. First boat arrived @ 1000 hrs with rig down equipment. Boat contract started 0600 hrs 6/06/97 Rig 428 released by Unocal to PPCO. Accepted rig @1200 hrs, 6/5/97. Boat Agreement still did not show up, being tracked down. First load out scheduled 0600 hrs 6/6/97. SeCorp Medic sent to Tyonek Platform to begin orientation and duties. Unocal completed inspection of turbine. Unit to be partially dismantled due to weight. Unocal to have Solar Turbine rep install mother board in control panel. Page 33 of 33 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Alter Casing 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South, Bellaire 77401 Location of well at surface: . 1250' FNL & 980' FWL SEC 6-T 11N-R09W At top of productive interval: 2178' FSL & 2086' FEL SEC 7-T11N-R09W At effective depth: (11,100 MD; 9400' TVD) 1320' FNL & 2900' FEL SEC 7-T11N-R09W At total depth: 1310' FSL & 1860' FEL SEC 7-T11N-R09W 11. Present well condition summary: Total Depth: measured 15,500 true vertical 12,878 Stimulate ~ Plugging _Xw Perforate ~ Pull Tubing Other feet feet Plugs (measured) 5. Datum elevation (DF or RKB) RKB 132 6. Unit or Property Name North Cook Inlet Unit 7. Well Number NCIU B-1 8. Permit Number / Approval Number 97-115 9. APl Number 50-883-20093 10. Pool Cook Inlet / Belu~la Feet PBTD: 10,029' (MD) or 8605' (TVD) Effective Depth: measured 15,500 feet true vertical 12,878 feet Junk (measured) Casing: Length Size Structural 407' 30" Conductor 2579' 16" Surface 3760' 13 3/8" Intermediate 6788' 9 5/8" Production 3535' 9 5/8" Liner Cemented Measured Depth Yes 407' Yes 2579' Yes 3760' Yes 10,376' No 3588' True Vertical Depth 407' 2571' 3521' 8846' 3376' Perforation Depth: measured 3500'-3540' true vertical 3307'-3339' Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) Perforated for cuttings' disposal zone ORIGINAL 2 3/8" 4.7 Ib/ft N-80 CS Hydril set a 3,663' (Dual Strings Cemented Outside 13 3/8" Surface Casing) Baker Liner Top Packer on top of 9 5/8" Intermediate Liner @ 3588' 12. Stimulation or cement squeeze summary: 10/16/97 Pumped 261 SXS Cement balanced plug from 15,500 to 14,850 10/16/97 Pumped 282 SXS Cement balanced plug from 14,560' to 14,150'. Tagged cement plug at 13,564' w/20,000#. 10/17/97 Pumped 535 SXS Cement balanced plug from 10,800'to 10,270'. Tagged cement plug at 10,029'(MD)orlI~(~_'J~V~),/II(]I0J~)~%, Intervals treated (measured): 15,500'- 14,850' (MD) I~C%,ClV EU 13. 14,560'-13,564'(MD) 10,800'-10,029'(MD) Treatmentdescriptionincluding volumes used and finalpressure: Volumes Listed Above. Prior to well operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure NOV ,2 1 199/' Al, nb i311.9. R~:e ~.,m~ ~,~mmig~;~.n_ Anchorage Tubing Pressure Subsequent to operation: 14. Attachments: Daily Report of Well Operations: Yes Copies of Logs and Surveys Run:Survey attached Lo~s will be sent from Schlumbe~ler office 15. I hereby~-rti~that the foregoing is true and correct to the best of my knowledge: Signed\ '~~ ~), ~~ Title ~'1~ __~~, ~+.~-e_..'~u0~._ ~ Date ~ ~_-,~,, j~l'~. Form 10-404 Rev. 12/01/85 ~ ' Submit in .Duplicate ' I EXit~' ~'ING CASING & CEMENT f"tAGRAM -30' ~ 4o7' BPV~ ,'ype,OD) ABB Vetco-Gray ~, RKB-THF: Tl~.l~:.tMnke. Type) ABB Vetco-Gray -' RKB-BHF: Annulus Fluid: 14.5 lb/gal mud ]:~(B-MSL: 132.00 TOC: Tagged TOC (~ 10,270' in 9 S/~" Casing Water Depth 130.00 :'OD'....:I ': .',TOP- i".. ]-.::Bottom::'!i ]:i.? .'i~.~'I'".:. ,[.. :.i..~.ac~....::.[ ~: .cmm~..~ii ]i.i:!.i,.:BUtSt:i.:i ~.i .~"i ~CoH'..: i:1~ :Fcmn ' Structural Casing: Drive Pipe 14.5 lb/galI 20' Q 2579' 3o" ] 57[ 4o?I ] [ I ] ] 20' I 571 2,5791 133.01b/fi I K-55 I BT&C [ 2860] 14101 1700 ,i Surface Casing: 133/s'I 57[ 3,7~01 72.01b/itI L-80 I SL/X I 4730[ 25201 761 Intermediate Liner:. =.!~.~ 95/8- I 35881 10.3761 53.5i~1 P-11o I 8T&c I 87101 75O01 F :~ Intermediate Tie-Back Strin~ 3 ~[i" 95/8- I 531 3,5881 53.51b/~I P-lZO I 8T~c I 87101 7500I 3] 2 Strings Production Liner:. Not Sct ~'~==~'Q==' ?" I I I 3=lb/. I P-11o I sr&c' I ~o=?ol ~o15oI 688 ! CutUnl;s Disposal Tubing (2 string) 13 3/8 O 3760 2 3/8' I 551 3,6631 4.7 Ib/fi I N-80 [CS .~'a,, I 89101 10240l i IL.~.~ Cook Inlet Sar :Is CEMENTING PROGRAM I l~ 20" Conductor Cemented with 1690 ax H'burton Premium Cement with 3% gel + 0.50 % CFR-3 8/04/97 plus 1.0 % CaCI2 followed with 700 ax I-rburton Premium + 2.0 % CaCI2 [ [!~ + 0.2 % CFR-3. Cement circulated to surfacc. t! 13 3/g "Surfacc Cemented with 1234 ax I-rburton Pr=mium Cement with 3% gel + 0.25 % CFR-3 ,~"~ 8/09/97 plus 1.0 % CaCI2 followed with 672 sx Il'burton Premium + 2.0 % CaCl2 Upper Beluga + 0.1% CFR-3. Cement circulated to surfacc. '~ ~' 9 5/8" Intermediate Liner ' Lead Cemented with 2400 sx Halliburton Premium Cement with 3%gel + 0.5% CFR-3 p + 0.2 % HR-5. TOC ~ 3,588'. Tail Cement with 704 ~x H'burton Premium Ccment with 0.20 % CFR-3 ii.i Lower Beluga 9/06/97 '0.13 gal/ax Halad 344L + 0.13 % HR-5. TOC (~ 9,400'. 14.5 lb/gal__:~. I Mud F.i~t'i~! Tyonek :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 9 5/8"{~ 1037i~ Plug No. ! 650' cementplug from 15,500'to 14,850'. Not required to Tag. . 261 sx Class "G" plus 0.2% CFR+0.08% HR-5 (~ 15.S lb/gaL MGS Plug No. 2 410' cement plug from 14560'to 14,150'. Tagging Required. 2~2 sx Class "G" plus 0.2% CFR+0,0S% HR-$ ~ 15.~ lb/gaL Tagged Plug ~ 13,564'. Plug No. 3 530' cement plug from 10g00' to 10,270'. Tagging Plug Required. ) 14.5_lb/gal ~ 535 sx Class "G" plus 0.2% CFR+0.0S% HR-5 ~ 17.0 lb/gaL [ ~ud ) T ag~,dP~u~e~0.0~;. I' 'c' =., (Siaotra=~ e~S). The wellhead will be capped with a Vetco-Gray tOM blanking flange with tOM valve. ~ Sunfish Sand Total Depth PBTD: 10,270 [Sup~. $'m'ton; Bab'n'enlTbg Wt: Well: North Cook Inlet Unit "B" No. I IDate: October 16, 1997 15,500' Location: T~'onek Platform! Cook Inlet7 Alaska Field: North Cook Inlet PRD SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 77251-2 ! 75 "OCT 3 1 1997 Phillips Petroleum b330 West Loop S., Texas Commerce Bank Building Houston, TX 77251 Attention:__Mark Kingsley Gentlemen: , Enclosed are. . print~s of the Phillips Petroleum Company_ PLEASE REPLY TO SCHLUMBERGER WELL SERVICES HC01, Box 337 Kenai, AK 99611 Attn: Shelley Ramsey _on'. North Cook Inlet NCIA B-1 Tyonek County Kenai State AK Field Additional prints are being sent to: prints Your transmittal consists of 3 boxes: BOX 1: DSI, DSI TVD., CNL/LDT 6 BL~ 2 films each Box 2:. AIT 6 BL, 2 films RFT 6 BL, 0 films nrints Box 3': CNL/LDT TVD~ AIT TVD 6 BL, 2 films each prints prints :2 .BL nrints 'Ala~k~i"'"0±l,' &'"Ga~ ¢onserva~i'g~?~'~'Lg~i'~s'~'i~n''' 3001 Porcup±ne Drive Anchorage, AK 99501 Attn: Blair E. Wondzell prints prints PLEASE SIGN AND RETURN ONE COPY OF THIS TRANSMITTAL. prints The film is. returned to Phillips We oppreciate the privilege of serving you. 32'/ I' Rece______ived b~ Date: N^~'~v ~ ~qq?--- Alaska 0il & Gas Cons, compression, Very truly yours,' Anchorage SCHLUMBERGER WELL SERVICES Rachel Walsh .......... o,S~,,c~ ~0~'" " 0CT-14-1997 11:51 PHILLIPS PETROLEUM PHILLIPS PETROLEUM COMPANY P. O. Box 1987 Hou,~ton, Texas 7?251-1987 ?136693?55 P.01/05 6330 West Loop So~th Belloirs. 'rexne 77401 October 14, 1997 North Cook Inlet Unit "B" No. 1 PPC0. Ty0nek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Gentlemen: Enclosed for your consideration and approval are three copies of Form 10-403 (Application for Sundry Approval) and three copies of the proposed Abandonment Schematic. Phillips requests your approval to Temporarily Abandon the referenced well. The target intervals in the well were not reservoir quality. Plans are being made to sidetrack the well, after a geologic review of the maps and existing log information. While the referenced well is TA, Phillips would also like to stimulate the disposal horizon being used for cuttings injection. A separate Sundry request is enclosed for this work. Should you have any questions or require any additional information, please contact Paul R. Dean at (713) 669-3502. Regards, N, P. Omsberg North America Drilling Manager · nc: ~t cc: J.W. Konst (wen¢} W. L. Carrico {w/o enc) J, R. Soybel " (~~R. Dean { w/enc ) 0CT-14-1997 11:S2 · . . PHI LL I PS PETROLEUM ?136693?55 Ab~.'°' OIL AND GAS ¢ON.~ERYATION COMMISSION APR ;ATION FOR SUNDRY APPROVAl( 1. Type orRequest: Time Ext~sion ..... Change_Al=proved Program Pluggin~t,. 2. Name of Operator: ~ Phillipq..P.~.roleum Co. ,, 3, Address: 6330W, LaogScMh, BelieVeT Texas 77401 4::- L~i6h o! well at surfaoe: Tyonek Pla{f~'m Leg 1 Slot 4 1250' FNL & 980' FWL SEC 6-T 11N-RI~W At top of productive ~terval: 2178' FSL & 2086' FEI. SEC 7-T11N-Rogw At effective depth: ( 11.100' MD; 9400' TVD) 1320' F NL & 2g00' FEL SEC. 7-T 11N-R09W At total depth: 1:310' FSL& 1860' FEL SEC 7-T 11N-R09W Abandon m Suspend-------Operatioei ;~hutclevm __ Re-~' Suspended Wel! .-- Stimulate .X. Pull Tubin_a 11. Preseh~'well condition summary Total Depth measured t5.500 feet true reft. Peal 12.878 feet Plugs (measured) .. . P. 04/05 ... Alter Casing Other 132 reel 6. Unit or Prope~/Name No;th Cool< Inlet Unit 7. WeU Numeer NCIU B-,1 ERR 8. Permit Number 97.115 9. APl Number 50-~83.20093 10. Poo~ Effective Depth measured 15Aa0 feet tree vertical 12,878 feet Casing Length Size Structural 0omluctor 2S79' Surface 3760' Intormed'rate 6788' Tie-Back String 3535' Production Liner Perforatiorl Depth: measured true vertical Junk (measured) Cemented 30" Yes 20' Yes 13-3/8' Yes 9 5/8' Yes g5/8- No ANNULAR I TUBING DISPOSAL CRITERIA 3500' · 3540' 3307' - 333g Measured Depth True Ve~ical Depth 407' 407' 2~7;r 2b'Tr 3760' 3521' 10,376' 8846' Tubing (s~e. grade, and measured depth) Packard and 888V (type and measured depth) 23/8" '4.7 lb/It N-80 G$ Hydril set at 366~' (Dual Strings Cemented Outside 13 3/8" Surfaoe Casing) Baker Liner Top Packer on top of 9 5/8" Intermediate L~er ~ 358~', Approval is requested t~ aoidize the disposal perfora~ns to clean up and insure disposal zone will remain open pending side~aoR operMion~. Stimulation is planned to be 25 bbl. 15 % HCI aobi. displaced with hi.viseoU~ brine to keep parrs open. oRiGiNAL 12. Attaohme~t$ "!'" De~iptio~ summary of pm~al __ ~'&talled Operations Program .- BOP sketoh .._' iii , ii ii . i , , iii _., i T3="E~mated Date far C~ing Operation: ......... :.,, October 17r 1997,, ~4: If proposal was verbaliy approved .Name ef Approver Date Approved.., 21.1 P~ere~that the fora'~ing is true and ~or~ct to the best of my knowledge' - " &omn~ss~ln Use (~nly oonditio6s'~, Approval: ........ Notify d~mmlsslon a~ ,epreeenta,ve may'witneSs ' ! I A~ro~al I~o. .--. Plug Integrity ~ .BOP Test Location Clearance ....... .., u,,,;,l,,,~-,~ai ~tgneO By A..roved,~ 0avid ~N. Johnston ~yordero~ /O Commissioner the ;~mmission Date Form 10-403 Rev. 12:~-85 ................ mit in IriPli~ate 0CT-14-1997 11:52 ~ 3/8 ' ~ Tda-Tl~ Cook Inlet Sa, Upp~ Beluga LqMor Beluga Tyonek MGS 14273.14453 NOl~ I=omlal~l =bm 14972 - 15056 i iii i PHILLIPS PETROLEUM ?136693?55 ,Wi') ...v.=o~,~ __ { ~aa~~..---- · -: ' ' X A~:-- "b;7,-oo 0~. :1: ~";,;; ;::;~[: a~ium ~I..' wT.....:!=.".' or~...:.. { :.-.;¢~,,,: $[~etur~l Cxdn~: Drl~ PiI~ ' ....... ~o~d,,ctm- CAdaI~" ' . __~PC& Allowable t~allnl~ ~o- ] s?l z.s?~ t'~'.Ol~nI ~'~- I BT-~C I' 2"~0l Z41'01 ~0 .... Surr~e C~1~$: ' ' x33/:'-"[- ..... S?t 3,7;o] ~,,o~t J_ L-10 [ SL/X ...... [~termedhle ~ ................ ~.' I . .3. mi' "'~U?~t ~.~r~! P.t).o. [nterrr~dbl~Ti~.'i~.:l( $~n~ ' . ......... 9~/l'f ~J 3,SnI S3.Slb,'fll P-ti0 I m'&c J :?Zoi '750ol tlS~ ' PmducfiOA L~ller: ............ ?" t ~eo?~I '~:looI 32r~ j p..o t' ersc .... .. . CuUln~ Dts~nl TUbinl' t3.~u~n~) ' CEMENTING PROGRAM 20' Coadurdar + 0.2 ~, CTR-3. Cemem e~ulald to *m'f',~.,c. Cm ,~?d wi~% i~90 = I~u~on P~.~. '...m Cn~m_..Mm 1.0 % CaC12 foll~w-~d with 700 8/09/97 #ut 1.0 % CaCl3 followed wi~ 672 ~t l-relatoR Premium + 2,0 % C~C12 *~1%CFR-3. Ceawnt~irculated tosur~ee. Plug PluS Plus $50' ceme~ plug ~om 15,500' to 14,850.. Not requital to 410' ccmm plug Rom 14560' to 14,150*. Tqpjng of Plug Ralu~ ~30' ceatmt plug ~m 10800* to 10,270'. Tnssjng of'Plug (Sidetrack Plus), RI! C:em~t to be Clm ~'0" ~ ZS.& lb/pl. will be capped with a VeK'o-Omy 10M blankingflaage with 10M v~ve, W*dl: North Cook_~le, r,.~t "B" Fla. I l~ai~: o=~= D, x~7 Lo=O.!_ ....W....kP,-.'~.~c~z~.~,..~,b _~ , ~e~ ,Ceokr. l.: .... '~ P.05/05 TOTAL P.05 OCTOBER ! 1997 PHILLIPS NCIU BI / ~ · CORE NO. 3 [4393' TO 14453', CUT 60', RECOVERED 60 ' BASZC DESCRIPTION OF CORE SAHPLES: SS: 14401' SS: 14404' COAL= 14407' COAL: 14410' COAL: 14413' COAL: 1441G' 14423' 14426' 14429' 14432' 14435' 14430' 14441' 14444' 14447' 14450' 14463' LT er, LT GY BRN TO $&P, FLDSPR, TR LT GN, MRN LITHS, CON BLK LITH$ (MAFICST). $L CALC CLV MTX, V rRI. ? Gl, OCC N GR, MOD ~ SRTD, APRNT FR VIS POR; SL PET OBR. SCAT LT BRN OIL STN~ N YEL-ORNG $PL FLUOR, INST LT BRN CUTt INST LT MLKV VEL-VHT CUT FLUOR= V LT BRN RES RNG. A/A BLK, HD, BRIT, BLKY TO PLTV BLK, HO, BRIT. BLKY TO PLTV BLK, HO, BRIT, BLKY BLK, HD. 8RIT. BLKV - PLTV eROS TO CARB CLYST. CARB CLYST: V OK BRN - BLK, HO, COH CARB PRAGS THROUGHOUT= W/ THIN INTRLAM$ COAL. CARB CL¥ST/ COAL: V OK BRN - BLK, HO, BRIT, PLTY " -~/-IM~N C~C"LA#~= NuN C~LC. CARB CLVST= A/A CLYST: DK GY - BLK. W/ SCAT CARB FRAG$, HO, BLKV, NON CALC. CLYST: A/A CLVST: A/A SS: SS: SS: SS; LT GY TO $ & P, VF GR, FLDSPR, SCAT LT GN MRN, COM BLK LITHS (MAFIC$?), FRI..SL CALC CLV MTX; NO APPRNT SHOW OTHER THAN FROM VF GR. A/Al NOSCF. VF GR, A/A; NOSCF. VF GR, A/A; NOSCF. VF GR, A/A~ NOSCF. VARICLRD DK GY - BLK, GRN - P6~$, W/ F MTX, SEPTEMBER 30, CORE NO. 2 14333 TO 14393', CUT $0', RECOVERE~ BASIC ~E$CRJPT:~N OF C¢~ SAHPLES: Sample Depth 14336' J4339' 14342' [4345' [4348' i43S4' 1&3S7' I43GO' 14363 143S9 ~4375 ~d378 ~438~ 14384 14390' ~393' SLTST: N GY, HO, VERY SL CALC CLYST: M - OK GY BEN, HO, BLKY, V SL CALC. CLYST= O~ G¥ 8RN, HO, NON CALC. CL¥ST: DK GY BRNt HD, NON CALC. LT GY BRN, Vr - ; GR, ;LDSPR, HNR LT GN, BLK LITHS, FRI, SL CALC eLY MTX, P - FR ViS POROSITY, SL PET ODOR, EVEN LT YEL - GN SPL FLUOR, SLU - INST LT BRN CUT, ~NST MLK¥ VEL CUT FLUOR; LT BRN RES RNG. LT GY, LT GY BRN, VF - F GR a/a $$: LT G¥, VF - F GR, CLYST: DK BRN V/ OCC iLK CARB LAMS LT GY, VF - F GR No Semple SS: $S: SS: SS: $$: LT GV, LT aY BRN, F SR - OCt M GR. F - MGR, lie. · idllk · · F ~ MGR, F - H GR, a/l. F - M GR, OCC CHT PBL$, SS/$LTST: VF ' GR, GRDS TO SLTST, V CALC, HO. · SSt F GR, i/a. SS: F GR~ &/a. SS= ~HT - ~ & p, CLR - VHT FLDSPR, HNR LT GN L]THS, BLK CARB OR MAFZCS(?) GRNS, TR MRN CHT GRN$, F GR, OCt MGR, SL CALC, ~HT CLY MTXt P - FR VIS PORE SL PET ODR; SCAT LT BRN APPRNT OIL STN, SCAT (8OX) VHT - BRT VEL SPL FLUOR~ SLV LT STRAV CUT; ~K VHT/LT VEL CUT (SOL) FLUORI V LT IRN RES ENG. NOTE: SHO~ VAR[ED THROUGHOUT CORE, EH PLACES TT ~AS O~IVOUS THAT THE COKE CH~P$ ~£RE CONTAHINATED V/ OIL tASK MUD. UNCONTAM]NATEO CHIPS GAVE ~'LT VEL GN $PL FLUOR. AN ZNSTANT MLKY VEL - VHT CU~ FLOUR. AND A V ~£AK STRAV V]$ABLE CUT, THERE VAS A SLIGHT PETR¢.EUM O00R THAT SEEMED "$VEETER" THAN THAT OF THE O]L BASED MUD ON THE CLEAN SAMPLES. NOTE' £ZGHT 5Q LB. IAG~ OF SOL?£X V£~E ADDED DURING COK£ RUN OJ~ BASED HUD SYST[H- BACKGROUNO FLUOR[SCtNC£ - LT GRECN, INSTANT DUL~ Y£LLO~ - VHTT~ CUT 14~?1 1~298 COALJ BLK. HO, IR|T SLTST CDAL CLAYSTONE/ S~TS~ ~JTH CARS PTS S~! VP - F Gl, CLA. FAOS.OCC TAN. F£LOSPA~, HOD ~RTO~ SLI CALC, NO ODOR, NO STAIN, SL! YEL ORNG SPL FLUOR, VK STRAV CUT, HLKY VHT - #LKY YEL VH? CUT FLUOr, B~T VHT RING FLUOR RESIOUK J4297' 14304' 14330' 1&313~ 1431~' ~4322' 14328' X433i' Zd333.~* SILTSTONE g! OCC COAL 'SILTSTONE/ VF GR SANDSTONE · SIL?SON£/ VF GR SANDSTONE SS: VF GR'NO VIS FLUOR SSs VF GK-NO VIS FLUOR COAL: iLK, HARD. BRZT CLAYS?ONE C~AYSTONE SSt OCt ~ED ER - HO VIS CUT CLA¥~TONE! SILTSTONE FRED C~AYSTONE/ $I~TSTON£ PRED CLAYSTOH[/ SILTS?ONE PR£O CLAYSTON[/SILT~TON£ FRED MEMORANDUM TO: David Joh~~ Chairman THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 21, 1997 Blair Wondzell, ~ P. I. Supervisor FROM' Lou Grimaldi~'~,,. SUBJECT: Petroleum Inspector~' FILE NO: AX8JIUEE.DOC BOPE Test UNOCAL/Pool rig #.428 North Cook Inlet Unit B-1 Phillips Petroleum Co. PTD #97-115 Sunday, September 21, 1997: I witnessed the weekly BOPE test on UNOCAL/Pool rig #.428 which was drilling Phillips Petroleum well #N.C.I.U. B-1 on the Tyonek platform. This rig is owned by UNOCAL Oil and Gas and is leased to Phillips Petroleum for this well and possibly some workovers, the rig is manned by Pool Arctic who is the manufacturer of this rig. I arrived the evening before the test and made a walk-through of the platform. The lower Kelly valve which failed to hold on its initial closure was cycled and retested "OK". The test spanned 'four hours. Rick Brumley (Pool toolpusher) exhibited a good test procedure and I found all necessary BOP equipment to be in place and operating properly. SUMMARY: I witnessed the weekly test of the BOPE on UNOCAL/Pool rig ~28 drilling Phillips Petroleum well #N.C.I.U. B-1 on the Tyonek platform. There was one failure observed. Test time four hours. Attachments: AX8JIUEE.XLS CC: Walt Carrico (Phillips Petroleum drilling Supt.) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Pool Rig No. 429 PTD # 97-115 Phillips Petroleum Rep.: NClU B-1 Rig Rep.: Set @ Location: Sec. Weekly X Other DATE: 9/21/97 Rig Ph.# 776-6013 Danny Simington Rick Brumley 6 T. 11N R. OgW Meridian Seward TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Well Sign P Upper Kelly / IBOP Drl. Rig P Lower Kelly / IBOP Hazard Sec. P . Ball Type . Inside BOP Quan. Test Press. P/F 1 250/2500 ~ I 250/5,000 1 250/5,000 I 250/5,000 1 250/5,000 2 250/5,000 I 250/5,000 N/A 250/5, 000 MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Quan. Pressure P/F 1 250/5,000 P 250/5,000 F 250/5,000 P 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes · Hydraulic Chokes 14 Test Pressure P/F 250/5,000 P 32 250/5, 000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 1 Twelve Bottles 3,050 I P 1, 800 P minutes 21 sec. minutes 41 sec. P Remote: P 2050 average Psig. TEST RESULTS Number of Failures: I ,Test Time: 4.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within N/A 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 REMARKS: Lower Kelly valve failed, cycled and retestpd OK. Good test procedure and results. Before entering high pressure zone retest BOPE to full required pre'ssure on permit, v' Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) AX8JIUEE.XLS .,/ PETROLEUM COMPANY ¢' /~' ' ~/ BELLAIRE, TEXAS PHILLIPS HOUSTON, TEXAS 77251-1967 BOX 1967 PHILLIPS BUILDING NORTH AMERICA August 21 1997 . PRODUCTION DIVISION . ' ~ Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Annular Disposal of Drilling Wastes This letter is to confirm your conversation with Mickey Carter of this office on August 20, 1997. It is our understanding that the permit for annular disposal of drilling wastes would include the following wastestreams: _/ ~,~ Drilling mud, drilling cuttings, reserve pit fluids, cement-contaminated drilling mud, completi~.on fluids, and formation fluids associated with the act of drilling a well. Drill rig wash fluids. Drill rig domestic waste water · D~k dr~nage Please respond back to me as soon as possible if the above listed wastestreams are not included in the AOGCC definition of drilling wastes. If you should have any questions or need further information, please call Mickey Carter at 713- 669-6075. Regards, NPO: cc: R.A. Bradford (r) M. W. Carter W. L. Carrico P. R. Dean J. W. Konst J. R. Soybel N. P. Omsberg North America Drilling Manager ?.8 1997 Alaska 0ii & Gas Cons. Comm~s~' ,~cho~age AUG-21-199? 18:24 PHI LL I PS PETROLEUM PHILLIPS PETROLEUM COMPANY P. O. Box 1967 H~ten, Tern 772~1-1967 ?136693?55 P.01/03 6330 We~t Loop sash Bellalre, Texas 77401 August 21, 1997 North Cook Inlet Unit B No. 1 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Gentlemen- Enclosed for your consideration and approval is a Form 10-403 (Application for Sundry Approval). The request is to alter the approved casing program as previously approved. The reason for the request is that the perforating of the tubing strings proposed to serve as cuttings injection tubulars was not successful. It is proposed to set the 9 5/8' casing string now as a liner, with a proposed TD just short of the Middle Ground Shoal Formation. The top of the liner would be at 3600', and the liner would be cemented the entire interval. With this scenario, we would then perforate the 13 3/8" surface casing at 3500' - 3540' (same interval as previously approved) and take an injection test. If successful, a tie-back string of 9 5/8' casing would be ran into the top of the liner, landed in the seal bore extension. This would give us the annulus between the 9 5/8" casing and the 13 3/8" casing to utilize for cuttings disposal. PPCo. Wants to utilize the oil based mud system to drill the troublesome Middle Ground Shoal coal beds, etc. Enclosed with the application is the proposed casing and cementing diagram. The detailed Operations program is being prepared and will be forwarded to your office as soon as it is finished, should you require it. Your earliest attention to this request wOuld be appreciated. NPO/prd Regards, J.W. Konst Central Files N.P. Omsberg North America Drilling Manager AUG-21-199? 18: 29 . PHI LL I PS PETROLEUM (" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS i 1. Type of Request' Abatxton -.-- Suspend---- Opera~m~ $huMown.~. Re-enter Suspended Well ' '"._~' Alter Casing Time ExMnsio~ Chan~e Ap _prpved_ _Prooram Plu~_~k~_e S~e 2. N~KY,~ M Operamc Ph~li~ Pdroieum Co. ~W. L~ S~ B~ T~ ~! ~,~ 4. L~ ~ ~1 ~ ~ T~ PI~ ~ 4 I~FNL&~~ SEC ~T 11N~W 21~' FSL & ~ FEL SEC 7-T11N-R~ I~FNL&~FEL SEC 7-T 11N-R~ At ~l d~: 131~ FSL& 1~ FEE SEC 7-T 11N-R~ t~ ~1 f~ ~~ f~ ?136693?55 __ , S. U~ ~ P~ N~ N~ C~ Inl~ U~ 7. W~ N~ NCIU B-I S. P~ Num~ ~-115 ~. ~PI Numar il mill Plugs (maasu~l) Junk (measured) P. 02/03 _ Cmmsing Sa, ucturat C~lductor SuKace In.fine. ate Pmdu~bn Length Si~e 40?' 3O' 257~ 20' 37B0' 1S-~J8' Cemented Measured Depth True Vertical Depth Yes 407 407' Ye~ 2579' 2S7~' Yes 3760' 3521' P~l'orati~n D~lh: rm~sumd ~t~le ve~eat Tubing (si;e, grads, and measured deplh) Pa~kers and S88V (type and measured depth) Appm,mi is reglUeeted to alter the approved casing program. The request ia made due to the inability to sueces~liy perforate the 2 3/8" tubin9 strings designed for the ;uflingmm inje~on service, The alteration emulate ef setting the 9 5?8' easing string shallower (above the IvIGS fomtatlon), and eeltlm~ i~ as a liner, wilh sul:~N4Uer~ lie-back being made alter perforating and e, ompleti~ the anmllus as mm disposal hmizon for the oil base ~uttings. 12. A~a~h~ts · Description summary of proposal _X_ Detailed Ope~tions Program .-. BOP sl~.t~'~ ' 13. ES|~i~d G~i--f~Commeneing O~ion: - -- mllll i ........ i . . .Oiee~eed ~al~m~ _at? with B~ Wo~, bm ~ ~1 ~ peking ~ei~ of t~ ~ ~ of ~ S~ R~u~,. Gom~!en l * .............. the ~m~n Da~ ---r~ ~3-R~. ~2.,~ David W. Johnston ............ Approved O~PY ~UG-21-1997 18:~0 2 str~s -- 133/8-O3760, C<ml< Inlat Sar Upper Belu~r4 Lowar Belug~ Tyoneic 15.800' 151800' .~,, PHI LL IPS PETROLEUM .., ~OPOSED CASING & CE&(" ~ Yelao-Gray IT ?1~669~V55 P. 0~/03 DIAGRAM ~ ]IUU~-BHF** Anmulus ]b'lu~l: I RKB-MSL -. 132.00 TOC: ]Water'Dcptlt 130.00 ..... CEMENTIN(~ PR~iRAM 20" Conduct<~ Cunmred wilh 16Sq) sx l-Fbufloa Prc~um Ccmmt wi~h 3% l~l + 0.:~0 % CF1~-3 plus 1.0 % CaCI2 followed with 900 u~ H'our~a 1%L-mium + 2.0 % CuCI2 +0.2%CFIt-3. Canemckcu]md mnn, fu,:e. 13 3/~ "S~ ~ with1234 txl-FburtaaPt%-mium C~.me~ with 3% ~J + 0.25 %C1~..3 8/09/97 Figs 1.0 % CaCI2 Followed with 672 s= H'bu,mon l'rumhun + :LO % C,,CI2 +0.1'.4, CFR,.3. CMM msurfia~ ' 9 S/~" ]0~'~ l.,ia~ C4:mcut with 1500,,~ }.hllib,rmn l~=mlunCemcatwith 3%sci...-,-0. _2% CF'lt..3 plus, '0.10 ~pd/~ R, dmi344L+0.15M, HR-S. TOC ~i 3,600'. Cment ~ 400 =¢ l-l'ourtoa Pf=mium Cancat wi~h 3% Sd 4- 0.20 % CFR-3 Toil plu 0.1. % ['1~$ 'lOC ~} 10,100% Ccmcitt wid~ 500~ ~Prcmlum+ 0.2%CFR.3 + 0. I:S lblsd344L+0.25 % I*!~-3, TOC~ 10,800' ( 300' abo~ Liner Top,) RECEIVED :~!r; 2 't 1991 Alaska Oil & Gas Cons. Anchorage ~ell: No~h Cook lnl~ Unit "B" No. l Ii)al='. Aufust 21.199'7 TOTRL P.03 MEMORANDUM TO: David John, ' Chairmar~ ~' State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 14,1997 THRU: Blair Wondzell, .~'~ P. I. Supervisor ~/~-'t' FROM: Lou Grimaldi,~~ SUBJECT: Petroleum InSpector FILE NO: AX9JHNEE.DOC BOPE Test UNOCAL/Pool rig #~t28 North Cook Inlet Unit B-1 Phillips Petroleum Co. PTD #97-115 Thursday, August 14, 1997: I witnessed the initial BOPE test on UNOCAL/Pool rig #~28 which was preparing to drill Phillips Petroleum well #N.C.I.U. B-1 on the Tyonek platform. This rig is owned by UNOCAL Oil and Gas and is leased to Phillips Petroleum for this well and possibly some workovers, the rig is manned by Pool Arctic who is the manufacturer of this rig. I arrived the day before the test and observed a portion of the rig-up. The test once started, went slow but fairly well. There were five failures observed, These being the upper Kelly valve which was replaced and tested after I left, the lower Kelly valve which was cycled and retested "OK", the bonnet flange on the #1 Blooey valve, the stem packing on the outside valve for the #2 hydraulic choke, and the #2 valve on the choke manifold sensor line. All failures with the exception of the upper Kelly valve were remedied during the test. The Gas detection system was tested and found to be operating properly. The mud monitoring system was in good shape. The test spanned a long period of time (12 hours) which in a large part was due to the high test pressure (8000 psi) and a slow test pump. Darrel Greene (Pool toolpusher) exhibited a good test procedure and there was always a Phillips representative on hand during the test. SUMMARY: I witnessed the initial test of the BOPE on UNOCAL/Pool rig ~428 drilling Phillips Petroleum well #N.C.I.U. B-1 on the Tyonek platform. There were five failures observed. Test time 12 hours. Attachments: AXgJHNEE.XLS CC: Walt Carrico (Phillips Petroleum drilling Supt.) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: ~ Drlg Contractor: Pool Arctic Operator: Phillips Petroleum Well Name: North Cook Inlet Unit B-1 Casing Size: Set @ Test: Initial X Weekly Rig No. 428 PTD # g7-115 Rep.: Rig Rep.: Location: Sec. Other DATE: 8/14/97 Rig Ph.# 776-6014 Lindsey Lyons Darrel Greene 6 T. 11N R. 9W Meridian Seward TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posteci P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. 1 Test Press. P/F 300/3500 P 1 300/8000 P 1 300/8000 P 1 300/8000 P 1 300/8000 P 2 300/8000 P 1 300/8000 P N/A 300/8000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure PIF I 300/8000 F 1 300/8000 F 1 300/8000 P I 300/8000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 15 300/8000 F 38 300/8000 F P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 1 Blind Switch Covers: Master: Nitgn. Btl's: 12 Bottles 2300 average 3,050 I P 1,go0 P minutes 23 sec. minutes 41 sec. P Remote: P Psig. ~ TEST RESULTS Number of Failures: 5 ,Test Time: 2~. Hours. Number of valves tested 21 Repair or Replacement of Failed --quipment will be made withi'n N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7642 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 REMARKS: Lower Kelly leake~ cycle valve and retest "OK". Upper Kelly leakec~ cycle and grease valve no good, valve will be changed out before drilling out. Bonnet on #1 blooey valve leaked change APl and retest "OK". #2 valve before #2 hyd choke leaked at stem, replace packing and retest "OK". #2 valve on sensor (superchoke) line leaked, cycled and retested "OK". Good test procedure. Long test time partially due to slow test pump. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO ' 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) AX9JHNEE.XLS TONY KNOWLE$, GOVERNOR AI,ASI~X OIL AND GAS CONSERVATION July 28. 1997 N. P. Omsberg, Drilling Mgr Phillips Petroleum Company 6330 West Loop South Bellaire. TX 77401 3001 PORCUPINE DRIVE ~ ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Revised to include annular ~lisposai Re.' NCIU B- 1 Phillips Petroleum Company Permit No: 97-115 Sur. Loc. Tyonek Pltfm 1, Slot 4, 12$0'FNL & 980'FWL, Sec. 6, T1 IN, Rgw, SM Btmhole Loc. 1310'FSL & 1860'FEL, Sec. 7, TllN, Rgw, SM Dear Mr. Omsberg: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations.are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records, FIT data, and any CQLs are to be submitted to the Commission prior to the start of disposal operations.' Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the ission at 279-1433. David W. Yq,hnston xk - ~ Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY July 24, 1997 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING David Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK Mr. Johnston, Subject: Drilling Permit for North Cook Inlet Unit B No.1 A phone conversation between Shonna Boyer of our Drilling Group and Blair Wondzell of your office indicated that the drilling permit for the subject well would be approved contingent on four proposed changes: 1) 2) 3) 4) Run a BOP instead of a diverter on the 20" casing to drill the 18-112" section. Run BOP tests every 7 days. Run a leak-off-test on the 20" casing shoe. Run a 10,000 psi BOP stack while drilling the 8-1/2" hole. Phillips will change the Drilling Procedure to include changes #2 and #4. The 10,000 psi BOP stack will have a 5,000 psi annular preventer. Phillips requests permission to use a diverter on the 20" casing while drilling the 18-1/2" hole, and, therefore, to omit the leak-off-test at the 20" shoe. Phillips intends to set the 13-3/8" casing shoe above the Cook Inlet sands. This is stated verbally in the Drilling Procedure in a section called "Anticipated Surface Pressure Calculations". Based on our geologist's best interpretation of the surrounding wells, Phillips actually intends to set the 13-3/8" casing at' about 3530' TVD RKB (but not below 3600' TVD), which is in a shale that lies between two coals. The seat will be about 100' TVD above the top .of the Cook Inlet "A" sand (3630' TVD). Therefore, the 18-112" hole will only be drilled through zones that are known to be gas- free. This is based on previous drilling wells at the Tyonek piatform, and a shallow hazard survey conducted by ARCO for the Sunfish drilling program. The top of the injection sands is about 3330' TVD. The Drilling Procedure will be edited to reflect the above depth for the 13-3/8" casing seat. Please contact Walt Carrico at 713-669-2173, Shonna Boyer at 713-669-7980, or Dave Beardmore at 713-669-2198 if you have any questions. ,~ 'h A~ca~Drilling Manager NPO/bcf CC: P. R. Dean J. W. Konst J. R. Soybel TONY KNOWLE$, GOVERNOR ALASILA OIL AND CiAS CONSERVATION CO~SSION July 25. 1997 o 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907") 276-7542 N P Omsberg Drilling Manager Phillips Petroleum Company 6330 West Loop South Bellaire, TX 77401 Re: NCIU B-I Phillips Petroleum Company Permit No: 97-115 Sur. Loc. Tyonck Pltfm 1, Slot 4 12$0'FNL & 980'FWL Sec. 6, TI IN. RgW. SM Btmhole Loc. 1310'FSL &: I860'FEL. Sec. 7. TI IN. R9W. SM ' ' Dear Mr. Omsberg: Enclosed is the approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized s.vnopsis of the week's activities and is exclusiveh, for the Commission's internal use. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface easing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. ' ~,oocn ~. ~.nnstcnson Commissioner BY ORDER OF THE COMMISSION dlf/Enciosures cc; Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ,SKA OIL AND GAS CONSERVATION COMMISSIONI{ PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill_X_ Redrill__llb. Type of well Exploratory_X_ Stratigraphic Test__ Development Oil__ Re-Entry Deepen ~Service Development Gas Single Zone Multiple Zone 2. Name of Operator: 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Petroleum Co. 132 feet North Cook Inlet Unit Field 3. Address: 8. Property Designation Exploratory 6330 W. Loop South. Bellairet TX 77401 ADL-17589 4. Location of well at surface: Tyonek Platform Leg 1 Slot 4 7. Unit or Property Name 11. Type Bond (sE£ 20AAC2S.mS) 1250' FNL & 980' FWL SEC 6-T 11N-R09W North Cook Inlet Statewide At top of productive interval: 8. Well Number Number 2178' FSL & 2086' FEL SEC 7-T11N-R09W NClU B-1 41-0-524 At total depth: 9. Approximate spud date ~.mount 1310' FSL & 1860° FEL SEC 7-T 11N-R09W 07/15/97 $200t000 12.Distance to nearest 13. Distance to nearest well 14. No. of acres in property 15. Proposed depth (MD and TVD) property line Surface: 4' 9920 726 feet NCIU A-12 15840 MD 13262 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (SEE 20 AAC 25.035 (e)(2)) Kickoffdepth 600 feet Maximum hole ang 35.24 degrees Maximum surface 3711 psig At total depth ~VD) 9719 psig Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 30" Drive 368' 0 0 407' 407' N/A 24" 20" 133 K-55 BT&C 2500' 0 0 2500' 2365' Lead,1530 sxst Tail 690 sxs 18-1/2" 13-3/8" 72 L-80 SL/X 4500~' 0 0 4500' 4000' Lead '~245 sxst Tail 1075 sxs 12-1/4" 9-5/8" 53.5 P-110 BT&C 14200' 0 0 14200' 11900' Stage 1:215 sx Stage 2:lead 100sxstai1380 sx 8-1/2" 7" 32 L-80 BT&C 1940' 13900 11700 15840' 13262' 380 sxs 8-1/2" 3-1/2" (alt) 12.95 P-110 PH-6 1940' 13900 11700 15840' 13262' 750 sxs (if used) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ;;;:;,c,or R'E.,':¢EIV D Intermediate Production1 2 1997 Liner Perforation depth: measured AJaska 0,.1 & Gas C0ns. Commiss'°'ORIGINAL true vertical ~ch0rage 20. Attachments Filing fee _X_ Property plat_X_ BOP sketch _X_ Diverter Sketch _X_ Drilling program _X_ Drilling fluid program X Time vs depth plot .X. Refraction analysis Seabed report 20 AAC 25.050 requirements (Directional Program) 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~JI)Sig~~' Title ;"" ~ Commission Use Only Permit Number JAPI Number IApproval.~ Ieee cover letter ~;:t,~,,. ,,//~',_,.z" J 50- ;~.~'~"' ~-- <::~ (:~ ?,,~ ~/'~"* ~? Iforother requirements Conditions of Approval: Samples required ,~ Yes ~ No Mud log required .~Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ..~ Yes ~ No Required working pressure for DOPE ~ 2M ~ 3M ~_ 5M ~ 10M ~ 15M Other: ORIGINAL SIGNED BY by order of ? ..~t~,,'~ ~' ."/ Approved by Robert N. Christenson Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate JUL-16-199? FROM PHILLIPS PETROLEUM CO. TO 890?2?6?542 P.0017005 DATE: TO: · m 3~ PHILLIPS PETROLEUM COMPANY HOUSTON. TEXAS 77251-1967 BOX 1967 ' TELECOPY COVER SEEET NORYH AMERICA PROOUCTION DIVISION BELLAIRE. TEXAS 633.0 WEST LOOP SOUTH PHILLIPS BUILDING ATTN: TELECOPY #: . ATTN: TELECOPY #: ATTN: TELECOPY #: FROM: Brett A, Butterfield OPPORTUNITIES TEAM Telephone: (713) 669-3729 Telecopy: (713) 669-3769 Houston, Texas 77251-1967 NO. OF PAGES (INCLUDING COVER SHEET): RECEIVED JUL ]G 199Z Alaska Oil & Gas Cons. Commir~oD PLEASE CALL SUSIE DEASON AT (713) 669-2929 IF THERE ARE ANY PROBLEMS. SPECIAL INSTRUCTIONS: pllep.s._e I~oo_k.t.h!s ove. r.~ .an.d..i.f aacpDt_able to vou_....s!gn and return by fax, We will.need to attacha land olat for this oros.oect, , JUL-16-1Dg? 07:33 FROM PHI LL I PS PETROLEUM CO. ~,. ARCO Alaska, ln~. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Dora I. Soda Senior Landman Telephone (907) 265-6297 Fax (907) 26a-4~e TO 89072787542 P. 002/005 July 2, 1997 Mr. Brett A. Butterfield Phillips Petroleum Company PO Box 1967 Houston, Texas 77251-1967 Re: Phillips-North Cook Inlet B #1 Well Tyonck Dccp Prospect Well Spacing Exceptions Cook Inlet, Alaska AR-101857 Dear Brett · Enclosed please find your letter dated June 16, 1997 executed by ARCO to evidence thc approval of your bottom hole location for the referenced well. We wish you success in you endeavor. Very truly yours, Dora I. Soria Senior Landman DIS (coy) RECEI¥ D j, · OL 997' Alaska Oil & Gas Cons. COl'/}fl}Js. sJoi'l Anchorage ARCO AlaMm, Inc. is a SUl~ldlllvy of Atl~ntlcRIchflold(~omptln¥ JUL-16-1997 07:33 FROM PHILLIPS PETROLEUM CO. 89072767542 P.003/005 PHILLIPS PETROLEUM COMPANY HOUSTON, TEXAS 77251-1967' BOX ~, 967 NO,TH AME,~CA June 16, 1997 PRODUCTtON DIVISION BELLAIRE, TEXAS 6330 WEST LOOP SOU'TH PHILUPS BUILDING REGISTERED MAIL . RETURN RECEIPT REQUESTED ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Attention: Mr. David L. Suffer RECEIVED JUN Z 0 1997 ALASKA LAND Re: Notification of Affected Owners The Phillips NCIU-B Well No. 1 Spacing Exception Cook Inlet, Alaska Dear Mr. Suffer: Phillips Petroleum Company has proposed the drilling of the Phillips NCIU-B Well No. 1 as an intentionally deviated hole pursuant to the Alaska Administrative Code Title 20. As the proposed well path has an intersection at the top of the primary target which is less than 500' from a governmental quarter section line, a Spacing Exception will be required pursuant to 20AAC 25.055. The Phillips NCIU-B Well No. 1 will be drilled from a surface location of 1,250' FNL and 980' FWL of Sec. 6-T11N-R9W, being Leg 1. Slot 4 of the Phillips Tyonek A Platform. The proposed bottomhole location is 1,310' FSL and 1,860' FWL of Sec. 7-T11N-R9W Upper Cool< Inlet, Kenai Borough, Alaska. A plat showing the surface and bottomhole locations is attached hereto. Phillips Petroleum Company requests that you acknowledge your receipt of this notification and that you state your non-objection to this application by signing and returning to the undersigned one (1) original of this letter. If you have any questions on this matter, please conta(;t the undersigned at (713) 669-3729. Very truly yours, PHILLIPS PETROLEUM COMPANY Brett A. Butterfield Senior Land Specialist BAB:sd Atta~.-hment JUL-16-1997 07:33 FROM PHILLIPS PETROLEUM CO. ARCO Alaska, Inc. Notification of Affected Owners The Phillips NCIU-B Well No. 1 Spacing Exception Cook Inlet, Alaska June 16, 1997 Page 2 of 2 TO 890?2?6?542 P.004/005 THE UNDERSIGNED DOES HEREBY ACKNOWLEDGE RECEIPT OF THIS NOTIFICATION CONCERNING THE PHILLIPS NClU-B WELL NO. I AND THE UNDERSIGNED DOES HEREBY STATE THAT THEY HAVE NO OBJECTIONS TO THE GRANTING OF A PERMIT TO DRILL AND SPACING EXCEPTION FOR THIS WELL. DATED THIS 2nd DAY OF July 1997. ARCO A~~ BY: - TITLE: Attorney in Fact p:~'~inword~bab~t97.14 RECEIVED JUL Alaska 0il & Gas Cons. Commissior~ Anchorage JUL-16-199? i ARCO, PHILLIPS 3-31-98 ADL- 374083 07:~3 FROM ARCO, PI~ .... LIPS 3 - 3'1 - 98 ADL-374081 PHI LL I PS PETROLEUM CO. TO ARCO ' 8-31-96 ADL-369101 ARCO PHILLIPS HBP ,L-37831 -I- ARCO PHI_J=LIPS HBP ADL- 37831 · ARCO, PHILLIPS ..,:,/ 17589 T 1 2 N ILLIPS ]1-98 "I ' - _.._! \ '~ · 1- r x 1 PHILLI'PS I A~CO ~ ~ ~ , "a" I ..~u.s L ~,,~' ~' ~1 ~ - ~ ~ . · ... LL. . ADL 18740 + · .,,.. ........... ., ~ ,-- .~ ..... R10W ']L,' 2 -- '7.." mm mm m mmm~l PHILLIPS ......... ILI m PETROLEUM 1 i RECEIVEID "' '"""' '"' ' ~1 & Gas~ns. Comrd~sJon . , R 9 W Anchorage COMPANY /7_,50 F'~; 980 ~'~t.._ /.~/o ~-"5'L. /Et~O ' ~e~- '7- COOK INLET BASIN OIL & GAS LEASE OWNERSHIP MAP :zoo0 4~ , SCALE f FF. ETI . TOTAL P.005 g¢~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 THE APPLICATION OF PHILLIPS PETROLEUM CO. for an order granting an.cxccption to spacing requirements of Title 20 AAC 25.055 to provide for the drilling of the North Cook Inlet Unit NCIU-B Well No. 1 oil well. Conservation Order No. 395 Phillips Petroleum Company NCIU-B No. 1 Well July 14, 1997 IT APPEARING THAT: Phillips Petroleum Company (Phillips) submitted an application dated June 16, 1997 requesting an exception to 20 AAC 25.055(a)(3) to allow drilling the North Cook Inlet Unit NCIU-B No. I oil well closer than 500 feet to a drilling unit boundary in an 'undefined pool. 2. Notice of hearing was published in the Anchorage Daily News on October 17, 1992 pursuant to 20 ACC 25.540 and the Anchorage Daily News on June 25, 1997. 3. No protests to the application were received. FINDINGS: As proposed, the Phillips North Cook Inlet Unit NCIU-B No. I oil well will be drilled from a surface location 1250 fcet from thc north linc and 980 feet from the west line of Section 6, T1 IN, R9W, Seward Meridian (SM), to a proposed producing interval 2178 feet from the south line (FSL) and 2086 feet from thc east line (FEL) of Section 7, T1 IN, R9W, SM and a proposed bottom hole location 1310 feet FSL and 1860 feet FEL of Section 7, T11N, R9W, SM. 2. Offset owner ARCO Alaska, Inc. has been duly notified. 3. An exception to 20 AAC 25.055(a)(3) is necessary to allow drilling of the well to the proposed location. CONCLUSION: Granting a spacing exception to allow drilling of the Phillips North Cook Inlet Unit NCIU-B No. 1 oil well, as proposed, will not result in waste nor jeopardize correlative rights. Conservation Order lq ,,:, July 14, 1997 Page 2 NOW, THEREFORE, IT IS ORDERED: Phillips Petroleum Company's application for an exception to 20 AAC 25.055 for the purpose of drilling the Phillips North Cook Inlet Unit NCIU-B No. I oil well is approved as proposed. DONE at Anchorage, Alaska and dated July 14, 1997. David W. Johnston, [, Alaska Oil ~ Commission '"...~p.'x. ~.,,/r..o Il /~x%q~.7 Robert N. Ch~-stenson, Commissioner ..... [j~ON ~--'~~ Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days at, er receipt of written notice of thc entry of an order, a pcrson affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within I 0 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th da), aRer the application for rehearin~ was filed). PHILLIPS PETROLEUM COMPANY P. O. Box 1967 Houston, Texas 77251-1967 6330 West Loop South Bellaire, Texas 77401 June 9, 1997 North Cook Inlet Unit "B" No. 1 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Gentlemen: .~;as~;a ~;Jl & Gas :;c~s. ~;0m[.~[$~t~''' Anch0r.-::ge Enclosed for your consideration and approval are three copies of Form 10-401 (Application for Permit to Drill). The referenced well will be drilled from the Phillips' Tyonek Platform to test the extent of the Sunfish and North Forelands reservoirs discovered by the ARCO-Phillips Sunfish No. 1 and the PPCo. Sunfish No. 3. Phillips plans to use the Unocal owned Rig No. 428, which will be operated by the capable crews of Pool Artic Alaska. Enclosed with the application are the following support documents: 1) Check for $ 100.00 to the State of Alaska, Department of Revenue. 2) A plat showing the referenced property, leaseholds, surface and proposed target and bottom hole locations. 3) The proposed casing and cementing program. 4) Formal request for a variance to the setting depth of the conductor casing (reference AOGCC 20.AAC 25.030 (c)(2)). 5) Schematic diagrams of the proposed Diverter and BOP equipment. 6) Proposed drilling fluid program with supplementary documentation as follows: a) b) c) d) e) Anticipated Mud Weight / Casing Point Plot Pressure Analysis Anticipated Surface Pressure Calculations Solids Control Program Schematic Diagrams of Rig 428 and Tyonek Platform Mud Systems. 7) 8) 9) 10) 11) 12) 13) 14) Predicted gee-pressured strata are described in detail in the drilling fluid program and supporting documentation. A copy of the proposed drilling program. The well will be intentionally deviated to reach from the Tyonek Platform to the bottom hole location southeast of the platform as illustrated on the proposed directional plan. Projected Time versus Depth Plot. Hydrogen Sulfide gas has not been encountered in any of the referenced offset wells drilled from or near the Tyonek Platform, nor is it anticipated in the North Cook Inlet Unit B No. 1. It is PPCo's. intent to monitor for the presence of hydrogen sulfide while drilling the entire well. Should H2S be detected, the AOGCC will be notified and contingency equipment installed immediately. Summary of Cuttings Injection Requirements Worksheet. Geological Cross Sectional Plot of the Sterling Formation, which is proposed for cuttings injection. The referenced well is scheduled to be spud approximately July 15, 1997, or as close thereafter as possible. AOGCC is requested to keep this application and the attachments confidential. Should you have any questions or require any additional information, please contact Paul R. Dean at (71 3) 669-3502. enc: cc.~ J. W. Konst (w/o enc) (~jpW... L. Carrico " R. Soybel " R. Dean ( w/enc ) Regards, North America Drilling Manager 1 2 1997 '~!a~ka Oil & Gas Cons. bummiss" Anchorage PHILLIPS PETROLEUM COMPANY Retain for Group ol' Staff Files State of Alaska Dept, of Revenue 3001 Porcupine Drive Anchorage Ak 99501 0O0776 Purpose: Penait to brjll NorU~ Cook Iulet Unit "B" No. 1. Charge Co~e AFE P- x047 FORM 9004-14 12-94 FIELD CHECK LOCATION DATE CHECK NO. AMOUNT co .z .o.,,t,o. ~-:~o-.?000776 $ ! 00.00 One ttundred ................................................................... 00/I State Of .Alaska, Oept, of Revenue 3001 Porcupiae Drive Anchorage Ak 99501 PHILLIPS PETROLEUM COMPANY State of Alaska Dept of Revenue 3001 Porcupine Drive Anchorage Ak 99501 DESCRIPTION o.~o~.o, 0 0 0 7 7 6 Purpose: Permit to Drill North Cook Iulet Unit "B" No. 1. Charge Code AFE P - x047 TAX ID NO. REPORTABLE 1099 COMMODITY CODE LEDGER LOC. EMPLOYEE NO.' CL YES I NO THE ATTACHED CHECK IS IN FULL PAYMENT OF ITEMS ~1/~.11=lJ ABOVE. ENDORSEMENT MUST BE IDENTICAL WITH THE PAYEE DESIGNATED. FORM 9004-14 12-94 DETACH BEFORE DEPOSITING AND RETAIN FOR YOUR FILES. Tyonek Deep Proposed Wellbore Schematic Injection zone 3350' TVD (3710' MD) Cook Inlet Sands 3700' TVD (4140' MD) Beluga Sands 4482' TVD (5122' MD) L Tyonek 'C' sand 11025' TVD (13138' MD) Sunfish sands 12082' TVD (14380' MD) North Forelands sands 12682' TVD (15116' MD) 20" csg @ 2400' TVD (2600' MD) 2 3/8" tbg @ 3375' TVD (3740' MD) TOC @ 3500' TVD (3771' MD) 13 3~8" csg @ 4000' TVD (4600' MD) Stage tool @ 5000' TVD (5800' MD) TOL 7" @ 11600' TVD (13900' MD) 9 5/8" csg @ 11900' TVD (14200' MD) 7" liner @ 13280' TVD (15800' MD) CASING DEPTH SETTING VARIANCE REQUEST Phillips Petroleum Company requests a variance to the required~ setting depth of the conductor casing as specified in 20 AAC 25.030~ ~ (c) (2). The planned casing is 20" 133 lb/ft K-55. The intended setting depth is 2350' TVD (2600' MD) which is 2250' below mud line. Phillips is requesting this variance based on the drilling information from the previous 14 wells drilled from this platform and the information gained from the Arco Sunfish No. 1 and the Arco-Phillips North Foreland St No. 1. The change in conductor setting depth will permit an optimized hole/casing program for reaching the objectives of the well. Arco Alaska conducted extensive shallow hazards surveys over the area in conjunction with the Arco Sunfish No. 1 and the Arco- Phillips North Forelands State No. 1. These surveys did not identify any hazards to a drilling program from the Tyonek platform. There have been no indications of anomalies above 3000' BML in the wells drilled from the platform, the Arco Sunfish No. 1 or the Arco-Phillips North Foreland St No. 1. The mud weights used in this interval on the recent wells have typically been below 9.0 ppg. The mud weight has been dictated by drilled solids rather than additions of barite. There was no indication of flow in any of the wells through this interval. Mud flow into and out of the well will be monitored by two independent systems, the PVT system installed on the rig and the mudloggers. The diverter system to be utilized in drilling to the 20" casing point is described elsewhere in this application. A 30" diverter with a 16" line will be used. The diverter line will extend in a straight run from the spool. The same 30" Diverte~ stack will be used for drilling below the 20" casing to the 13 3/8 casing point. ~.~ The maximum pressure anticipated under diversion mode would be 200- 250 psi. Further supporting this request is the following tabulation listing several wells in the Cook Inlet Area where the second casing string was set deeper than 1000' below mud line or ground level. The depths shown are TVD-RKB. Well String 1 String 2 String 3 Arco Fire Island # 1 30" @ 328' 20" @ 1685' 13 318" @ 7603' Stuart W. McArther RU #1 30" @ 127' 20" @ 2040' unknown Phillips NCIU A-12 30" @ 381' 20" @ 1990' 13 318" ~ 6950' Arco-Phillips North Foreland St # 1 30" @ 316' 20" @ 2489' 13 5~8" @ 8498' Arco Funny River # 1 30" @ 60' 20" @ 2971' 13 3~8" @ 8312 Arco Beluga RU # 1 20" @ 95' 13 3~8" @ 2985' Phillips-Arco Sunfish # 2 ¢3 ?-- ~0 {= ~, 30" @ 407' 20" @ 2482' 13 3~8" ~ 7695' Phillips-Arco Sunfish #3 ~3 -~4 30" @ 407 20" @ 2535' 13 3~8" @ 8125' ANTICIPATED SURFACE PRESSURE CALCULATIONS The following presents the information used in the calculation of maximum potential surface pressure for the various hole sections. Casing Setting Depth Rationale 30" 175' BML, 407' RKB Conductor pile, driven when platform was installed in 1968 20" 2200' BML, 2450' TVD, 2600' MD, This string of casing will top set the Cook Inlet sands. It will provide a good anchor for the BOPE and provides an adequate fracture gradient for drilling to the 13 3/8" casing point. 13 3/8" 4000' TVD, 4600' MD Surface casing set above the Cook Inlet Sands, With with the two 2 3/8" strings as cuttings disposal 2 3/8" into the shallow sands at 3300'-3400' TVD. Disposal Tubings 9 5/8" 11900' TVD, 14200' MD Intermediate/Production casing through the C sand. Will provide an adequate fracture gradient to drill to total depth. 7" 13262' TVD, 15840' MD Production liner to isolate Sunfish and North Forelands sands for potential testing Casing Setting Fracture Pore Pressure Maximum Downhole Maximum Size Depth Gradient Gradient That Pressure That May Potential Surface (ppg) May Be Be Encountered Pressure Drilling Encountered (psi) (psi) (PPg) 30" 175' BML, 10 8.7 1130 205 405' RKB 20" 2450' TVD, 12.5 9.0 3790 200 PSI 2600' MD (Flow Diverted) 13 3/8" 4000' TVD, 14.5 12.5 5434 3625 4600' MD 9 5/8" 11900' 17.0 14.5 9719 3711 TVD, 14200' MD - PRESSURE ANALYSIS Pore pressure predictions have been made based on the offset well information from other wells drilled in the area and the seismic data. The most important offset wells used in this analysis are the production wells on the platform for the shallow horizons, and the Shell North Cook Inlet State No. 1, Arco Sunfish No. 1, Arco- Phillips North Forelands State No. 1, and the Phillips-Arco Sunfish No's. 2 and 3 wells recently drilled. The interval above 7,800' TVD, ± 9,300 MD will be the Cook Inlet and Beluga sands that are produced at the platform. The pressures in these sands have declined to a 5 - 6 ppg equivalent mud weight. Based on the results from the Arco Sunfish No. 1, the Arco-Phillips North Forelands State No. 1, the Phillips-ArCo Sunfish No's. 2 and 3 and the workovers on the North Cook Inlet Unit Wells A-1 thru the A-13, lost circulation is not expected to be a problem despite the low reservoir pressures. Due to the lenticular nature of the Beluga formation, there is the possibility of encountering a Beluga sand at virgin conditions. Virgin pressure in the Beluga interval was 8.5 - 9.5 ppg. The geologic interpretation for the interval below 7800' TVD is that the formations and pressures should be similar to those encountered in the Arco Sunfish No. 1 and the PPCo. NCIU No. A-12 (formerly Cherryville A-15). The interval between 7800' TVD and the proposed 9 5/8" casing point at 11900' TVD, 14,200' MD is essentially normally pressured. This is the Middle Ground Shoal section with the "10,700' Sand" and the Tyonek nC" Sand. Mud weights of 10.5 to 11.5 ppg are anticipated and will be dictated by the coal seams throughout this interval. There is a pressure transition that occurs slightly above the Sunfish Sands at ± 12,000' TVD, ± 14,300' MD,. Pore pressure will increase from 9.8 ppg to about 13.2 ppg during this transition. This abnormal pressure trend is expected to continue to TD. Actual mud weights could be as high as 14.5 ppg. PROCEDURE FOR DETERMINING MAXIMUM DOWNHOLE PRESSURE AND MAXIMUM POTENTIAL SURFACE PRESSURE Maximum Downhole Pressure is determined from the pore pressure predictions of the interval to be drilled below the subject casing. The pore pressure predictions were made from offset well data and the seismic data. The maximum potential surface pressure is determined to be the lesser of the fracture pressure of the formation at the subject casing shoe less a fluid gradient to surface or the bottomhole pressure of the intervals to be drilled less the gradient of the fluid produced from the formation. I . . Drilling Below 30" Conductor Pile: Maximum Bottomhole Pressure (BHP): BHP = PP x 0.052 x De BHP = 8.7 x 0.052 x 2500 = .1130 psi Maximum potential surface pressure is based on the frac pressure at the shoe less a gas column to surface. At this shallow depth the gas gradient is about 0.015 psi/ft, and the frac gradient is estimated to be 10 ppg. MPSP = ((FG x 0.052) - GG)D=s MPSP = ((10 x 0.052) - 0.015)405 = 205 psi Drilling Below 20" Conductor Casing: BHP = PP x 0.052 x Dd BHP = 9.0 x 0.052 x 4000 = .1872 psi This interval includes the shale and non-productive sand sequences above the Cook Inlet Sands. Pore pressures are less than 9.0 lb/gal. The fracture gradient below the 20" shoe is approximately 12.5 lb/gal equivalent. Maximum Potential Surface Pressure is determined based on the pressure that would result if 50% of the mud was displaced by formation fluid, which in this interval could be gas, oil, or water. The maximum pressure is based on the assumption that the formation fluid is gas with a resulting formation fluid gradient of 0.015 psi/ft. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. The maximum shut-in pressure is: MPSP = BHP - (MW x 0.052) (0.5 x D~) - (FFG) (0.5 x D~) MPSP = 1872 - (9.0 x 0.052) (0.5 x 4000) - (0.015) (0.5 x 4000) = 966 psi. However, with the 30" diverter, the well will never be shut in. The maximum pressure will be 200-250 psi through the diverter. . · Drilling Below 13 3/8" Surface Casing: BHP = PP x 0.052 x D~ BHP = 12.0 x 0.052 x 11900 = .7426 psi Maximum Potential Surface Pressure is determined based on the pressure that would result if 50% of the mud was displaced by formation fluid, which in this interval could be gas, oil, or water. The maximum pressure is based on the assumption that the formation fluid is gas with a resulting formation fluid gradient of 0.015 psi/ft. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. MPSP = BHP - (MW x 0.052)(0.5 x D~) - (FFG) (0.5 x Da) MPSP = 7426 - (12 x 0.052)(0.5 x 11900) - (0.015)(0.5 x 11900) = 3625 psi Drilling Below 9 5/8" Intermediate: BHP = PP x 0. 052 x Da BHP = 14 x 0.052 x 13400 Maximum Potential Surface Pressure is determined based on the pressure that would result if 50% of the mud was displaced by formation fluid, which in this interval is expected to be oil and gas. Mud weight would be approximately 0.5 ppg over the pore pressure. Based on test results the formation fluid pressure gradient is about 0.2 psi/ft. MPSP = BHP - (MW x 0.052)(0.5 x D~) - (FFG) (0.5 x D~) MPSP = 9755 - (14.5 x .052)(0.5 x 13400) - (0.2) (0.5 x 13400) = 3711 psi SOLIDS CONTROL PROGRAM Ria Eauipment: Linear shakers - 3 Derrick Model 58 FIo-Line Cleaners Desander Pioneer Model T-86 with 8-6" cones Mud Cleaner Derrick with 16-4" cones Degasser Drilco See-Flow 0BM Cuttincls Handlinn: -- Apollo Services will vacuum the drill cuttings to their catch tank. From there, the cuttings will be ground and disposed into the non-productive sands at a TVD of approximately 3300' TVD. Disposal will be down one of the two 2 3/8" tubing strings attached to the 13 3/8" surface casing. Additional EauiDment Needed: 1) 2) A dedicated steam cleaner is needed at the shakers to allow for screen cleaning at any time. Coarse {e.g., expanded metal) cages will be installed over the pump intakes in the pits to prevent trash from fouling the valves. 3) A dedicated pump capable of pumping liquids out of the cuttings catch tank back over the shakers will be furnished by Apollo Services. 4) Use Pyramid Plus screens as the first 2 screens on the Derricks. The Plus feature is merely taller corrugations, which allows for more separation in the deep pool section of the shakers. NOTE: Ensure all equipment is fully operational before drilling ahead with oil base fluids. Install an operational pressure gauge on the hydroclone headers. Pressure should be 4 x MW in psi. Upgrade feed pump impeller if necessary. Be sure cones are clean and in spray discharge. Conductor and Surface Hole: Use all rig solids control equipment. Run 210 mesh pyramids on the Derricks. Run desander and desilter on surface hole. Intermediate H01A: The goals during the OBM sections are to produce dry cuttings {to reduce cuttings slurry volumes), and yet keep Iow gravity solids (Igs) less than 8 vol% with existing rig equipment. In past wells, < 8% Igs has been achieved using 210's on the Derricks. Again, the goal is to produce dry cuttings, even during upsets and startups with cold mud. During switch out to OBM, put coarse flat screens on Derricks (e.g. 80 mesh). After several circulations, start the Derricks with 140 mesh screens. Use Pyramid Plus screens on the first 2 screens, and a regular Pyramid on the last screen. Screen down to 210's in the same arrangement consistent with dry cuttings as soon as possible. A major goal is to produce dry cuttings. To prevent whole mud going over the shakers, it may be necessary to bypass the Derricks for the first half circulation after a trip into the hole. When the mud warms up, immediately switch back over the Derricks. Pump liquids that collect in the catch tanks back over the shakers. Lost circulation is possible at any time. It may be necessary to bypass the Derricks for a short time to allow bridging size LCM (e.g., sized calcium carbonate and Steel Seal) to build up in the mud to plug the problem zone. Return flow to the Derricks as soon as possible to prevent buildup of Igs. It is better to have to keep adding LCM than to let the Igs build up over 8 vol%. Production Hol~: Continue with previous program. Lower pump rates may allow 250's on the Derricks. Phillips PeLroleum Company Sfructure-TyonekPIofformWelI-TyonekDeepProspecf Field 'Alaska Location 'Alaska 12~30 2000 2400 28O0 4000 1OOOO 104O0 10800 tl200 11600, . t200~ - . 1240O - . 12100 - . 13.200 - Casing Point KOP Begin 2.00 deg./100' Build 4.00 8.00 12.00 16.00 20.00 24.00 28.00 32.00 gin 55.2,t deg. Tangent Section ' 20' Casing Point Casing Point SchlumbergerI Anadrill WELL PROFILE DATA .... Po;nt .... MO l~e [~¢ ~ No~h Coat ;~ afl 0 O.OQleS.'lS 0 0 0 O.QO ICOP 8~0 O.OQI SS.SS SO0 O Q 0.00 £M of Build 2382 35.24 I SS.S5 2253 -S08 131 2.~ f~t 1430S35.24 145.55 12~ -7~ 1864 O~ ~d ~ ~M 158S535241 e5.55 132~ -80~ 2075 0.~ Created By _ .~~:--- - -..~'" Cu,tCmlir AF, Pr~I ......................... 4, "~'( ~ East -600-JO0 0 JO0 600 g~ 12~ 30" Casing Point ~ KOP Be~in 2.00 de~./100' Build -600 ~~0 3egin 55.24 deg. TancJent Section ' Casing Point 15 3/8' Casing Point 9 5/8' Casing Point Sunfish Sands ~ North Fetch PBHL/TD -900 . --15OO . --1800 - --2100 . --2400 . --2700 . --.3000 . - -3300 --3600 - - lrreated by ; NASD/DPC CatherTne Ortizl ate plotted, 6-Mar-97 lot Reference is Proposal Rev 0. oorclinates are in feet reference slot !1 -I ue Vertical Oepths ore reference RKB. --- Anadrill Schlumberger --- I J, MAP DRAWN TO GRID NORTH J 9 5/8' Casing Point Sunfish Sands North Forelon¢ PBHL/TD~ [llllll[llll~l,[l[lllll[llll IJilllllltlllll~llll~ Scale 1 ' 400.00 Vertical Section on 1 65.55 azimuth with reference 0.00 N, 0.00 E 'TjE!CONTROLLEE PHILLIPS PETROLEUM COMPANY NORTH AMERICA E & P DRILLING OPERATIONS WELL: North Cook Inlet Unit "B" No. I APl NO. Permit No. FIELD: North Cook Inlet Field LOCATION: Surface: BHL : WORKING INTEREST: AFE: BUDGET ITEM: GROSS AUTHORIZATION: OBJECTIVE: 1,250' FNL & 980' FWL Leg No. 1; Slot No. 4 1,310' FSL & 1,860' FWL Phillips Petroleum Co: P-X047 2A $ 15,867,000 COUNTY, STATE: NCIU Alaska AREA: Kenai, Alaska Sec. 6-T 11 N-RO9W Sec. 7-T 11N-RO9W 100.000000 % Drill and Test a 15,840' MD (13,262' TVD) Exploration Appraisal Well. DRILLING ENGINEER (~O,t,,~ ~, DRILLING ENGR. DIRECTOR DRILLING SUPERINTENDENT DRILLING MANAGER DATE ~T~ ~.-/~9~ DATE DATE DATE DISTRIBUTION: d. W. KONST N. P. OMSBERG (R) CENTRAL FILES W. L. CARRICO DEVELOPMENT SUPERVISOR (2) J. R. JACKSON (R) L.D. AIRINGTON J. G. HAMMEKE E. R. RAMP S. J. REYNOLDS (2) POOL ARTIC ALASKA J. W. SPENCER P. R. DEAN (ORIGINAL) ORIGINAL ( X ) REVISION ( ) TIGHT HOLE: YES ( X ) NO ( ) Run No. 2: 14,200' MD to TD in 8 1/2" hole (oil-based mud) Array Induction and GR Compensated Neutron Litho-Density with GR and Caliper Dipole/Array Sonic with GR and Caliper MDT (Pressures in N. Foreland Sand and Sunfish Sands) OBDT (Dipmeter) PHILLIPS PETROLEUM COMPANY WELL PROGNOSIS DATE' May 14, 1997 AFE No. P-X047 PHILLIPS PETROLEUM COMPANY LEASE: Well No. 1 NCIU-B SURFACE LOCATION: Tyonek Platform Leg 1, Slot 4: 1250' FNL and 979' FWL of Section 6-11, N-gW BOTTOM HOLE LOCATION: 1310' FSL and 1860' FEL of Section 7-11N-9W FIELD NAME OR WILDCAT: North Cook Inlet Unit (NCIU) - Deep Appraisal Wildcat PROJECT. ED TD'.-. 15,840' MD and 13,262' TVD ELEVATION. RKB= 132 ft., Water depth- 100' @ MLLW) CONTRIBUTORS OR WORKING INTEREST OWNERS: Phillips Petroleum Company (Operator) 100% NEAREST AND SIGNIFICANT WELL CONTROL: Arco/Phillips Sunfish #1 Section 12-11N-10W Pan Am'17589 State #1 Section 6-11N,gW Arco/Phillips N. Foreland #1 Section 13-11N-10W ANTICIPATED TOPS': Top MD (ft.) TVD (ft.) TVDSS (ft.) Cook Inlet "Stray" sand 4000 3579 -3447 Upper Beluga 5103 4482 -4350 Tyonek (eos.~u. Chuitna Gas sand within 2S0 91 20 7772 -7640 vertical feet below top of Tyonek) MGS 11,098 9392 -9260 "10,700' Coal" 1 2,673 10,682 '10,550 "C" Sand 13,131 11,057 -10,925 Sunfish Sand 14,380 1 2,082 -11,950 N. Foreland Sand 15,116 1 2,682 -1 2,550. NORTH COOK INLET UNIT "B" No. 1 PROGNOSED DRILLING CURVE -15 -2O 0 25 50 75 100 125 150 175 200 225 250 275 3OO DAYS 4-SF 3 ACTUAL -e-Base Curve 4-AFE Curve ==Stretch Top Stage Collar .OPOSED CASING & CEM( JT DIAGRAM 30" {~ 407' BPV(Make,Type, OD) Tbg. Hgr.(Make,Type) ABB Vetco-Gray ABB Vetco-Gray RKB-THF: RKB-BHF: RKB-MSL: 132.00 2 Strings 3/8 ' Q 374{7 [Annulus Fluid: ITOC: Water Depth 130.00 OD Coil [ Tcnsn ! Structural Casing: Dr~ve Pipe 20" Q 2600~ 30" I 501 4071 [ ] I [ [ Conductor Casing: PPCo. Allowable Ratings I 20" I 501 2,6001133.01b/it[ K-55 {BT&C] 28601 1410[ 17001 Surface Casing: ' 133/8" 501 4,5001 ~.Ol~/~l L-s0 I SL/X I 4730l 2520i 7611 ' Intermediate Casing: 95/8"l 50l 14,200l 5~.51~/~1 P-110 I ~;&c I 8710i 750011159 Production Liner:. 7"I t39001 15,8001 321b/il I L-a0 I aT&C I 81601 81101 528 13 3/8" ~ 4600' Cook Inlet Sar Upper Beluga ¢~ 88o(~ Lower Beluga CEMENTING PROGRAM ids ;Conductor Cement with 1530 ax H'burton Premium Cement with 3% gel + 0.25 % CFR-3 plus 1.0 % CaCI2 followed with 690 ax H'burton Premium + 2.0 % CaCi2 + 0.1% CFR-3, Circulate cement to surface. Surface Cement with 1245 sx H'burton Premium Cement with 3% [~el + 0.25 % CFR-3 plus 1.0 % CaCI2 followed with 1075 ax Il'burton Premium + 2.0 % CaCI2 + 0.1% CFR-3. Circulat~ cement to surface. Intermediate 1st Stage Cement with 215 ax Halliburton Premium Cement with 0.2% CFR-3 plus. 2nd St&sc '0.10~al/axHalad344L+0.15% HR-5. TOC ~ 13,600'. Cement with 100 ax l-fburton Premium Cement with 3% ~i + 0.20 % CFR-3 plus0.1. % HR-5 followed with 380 ax H'burtonPremium + 0.2%CFR-3 +0.1 Halad 344L + 0.10 % HR-5 . TOC (~ 4,000'. Production Cement with 380 ax H'ourton Premium + 0.2 % CFR-3 + 0.15 gal/ax I-lalad 344L + 0.25 % HR-5 . TOC ~ 13,600' ( 300' above Liner Top.) Top of Cement "C" Sand 9 5/8 "~ · ! Sdnfish Sand :; North Forelands NOTE: The two 2 3/8" tubing strings will be strapped securely to the 13 3/8" surface casing as it is being run., and well centralized. Cement evaluation will confirm the competency of the cement prior to utilizing the 2 3/8" tubings as disposal strings for cuttings injection. ~PlugBack t..<: ~i TD :~ 7"~ 15,800' PBTD: 15,760' [Supv: [TbS Wt: Well: North Cook Inlet Unit "B" No. 1 !Location: T,vonek Platform, Cook Inlet, Alaska IDat~: June 3, 1997 15,800' Field: North Cook Inlet PRD Well Name: North Cook Inlet Unit B No. 1 Field: North Cook Inlet Unit AFE No. AFE P-X047 Drill & Test Costs: Surface Location: 1,250' FNL & 980' FWL Sec. 6-T 11N-R09W Bottom Hole Loc. 1,310' FSL & 1,860' FWL Sec. 7-T 11N-R09W Depth: 15,840' MD 13,262' TVD AFE Days: Rig: Unocal Rig 428 with Pool Artic Alaska manpower Type: 2A $ 1 5,867,000 Leg 1; Slot4 146 OBJECTIVE- Drill and Test a 15,840' MD (13,262' TVD) Appraisal Exploration Well· CASING PROGRAM: 30" 407' Drive Pipe 20" 2600' (2365') 133 K-55 BT&C 2860 1410 1700 13 3/8" 4600' (4,000') 72 L-80 SL/X 4730 2520 906 3800 , 9 5~8" 14200' 53.50 P-110 BT&C 8710 7500 ' 1159 5000 (11900') 7" Liner 15840' 32 L-80 BT&C 8160 8110 528 5000 (13262') 3.5" (Alt) 15840' 12.95 P-110 PH-6 14240 17470 232 8000 Sec. I Sec. II . Sec. III 9. Sec. IVIO. 11. 12. 13. Sec. V 14. PROCEDURE SUMMARY · 1. MIRU Unocal Rig No. 428 over Leg No. 1, Slot No. 4. Install Cuttings Grinding Equipment. 2. Install riser and 30" diverter. Function test diverter. Install PVT equip. ,I- ~¢~,~&. 3. Drill a 24. directional conductor hole to. 2600, following directional. . plan. 4. Set 20 cond. csg, cmnt to surface, dlspl w/mud. Do a top job tf necessa~_~,~~ h~ p~ 5. Install riser and diverter. Function test diverter. 6. Drill out 20" shoe. Drill an 18 1/2" hole with directional assembly to 4500' MD. Log well with DIL/GR/Den/Neutron. 7. Run 13 3/8" with dual 2 3/8" tubings strapped in place. Cement to surface. Top out if necessary. Release diverter. Install wellhead packoff equipment, NU and test Multi-Bowl wellhead. Perforate the 2 3/8" tubings for cuttings disposal service. Establish pump-in rates. Connect to injection service Drill out 13 3/8" shoe with rotary assembly. Perform FIT to 13.0 EMW. Drill 12 1/4" hole to 11,900' TVD (14,200' MD) using Oil Base Mud. Circulate and condition hole for logs. Log well as per Geological Prognosis. Run 9 5/8" casing and hang off in multibowl wellhead. Cement 9 5/8" csg. Install packoff and test. Test BOPs. Install wear bushing. Drill out 9 5/8" casing shoe and perform FIT test to 16 ppg EMW. Drill 8 1/2" hole to 13,262' TVD (15,840' MD), holding angle and direction. Core the Sunfish and North Forelands Sands. 1 5. Circulate and condition hole for logs. Log hole as per Geological Prognosis. 16. Run and cement 7" production liner (or 3 1/2" production casing ( 3 1/2" monobore tubing )). 17. Clean out production liner to PBTD. 18. Completion testing program will be planned based upon log evaluation. o . . . . 1 DRILLING PROSPECTUS Location Phillips Petroleum Company's Tyonek Platform located in the North Cook Inlet of Alaska. Drilling will be from Leg No. 1, slot No. 4 ( See attached survey and schematics). Drilling Contract The drilling contract is a bare boat charter directly from Unocal for the use of the Rig No. 428. Pool Artic Alaska will provide the manpower and rig crews to install and operate the rig. Well Control Well control procedures will be in accordance with Phillips Petroleum Company's Well Control Manual and State of Alaska Oil and Gas Conservation Commission. An exception to the PPCo. Well Control Policy is requested to extend the BOP testing interval from 7 days to 14 days. Exception Approved: Govermental Reporting N. P. Omsberg Notify AOGCC (Blair Wondzell) @ (907) 279-1433 prior to moving in and rig up and prior to spud. Special Considerations This section is intended to clarify and discuss special drilling situations that may occur. Be alert for these potential problems and ready to implement the appropriate contingent actions. Oil Base Mud will be used to drill the interval from 4600' (4000' TVD) to TD. (Refer to Oil Based Mud Handling Procedures - attached). Extra precaution will be taken to insure that no runoff is allowed. Proximity to Other Wells A safety zone equal to 1.5% of the measured depth below mudline is to be maintained around the North Cook Inlet Unit" B" No. 1. If a producing well intersects this safety zone the producing well should be plugged with a wireline set plug below the potential point of intersection. The producing well will remain plugged until the risk of intersection has passed. The surface location is in the same wellroom as NCIU A-1 2, A-13 and the TA Sunfish No. 3. The A-12 was drilled as a vertical well to about 7000' where it was kicked off to the south east. There is a very slight drift to the south west in the vertical section above its kick off point. The NClU A-13 is vertical to 700' where it is kicked off to the West. The Sunfish No. 3 drifts to the North. The NClU B No. 1 wellbore will also cross paths with well No's. A-3, A- 9, A-6 and A-7.. To avoid any risk of A-12 intersecting the safety zone DO NOT PERMIT NCIU" B" NO. I TO DRIFT WEST ABOVE THE KICK OFF POINT. Take frequent surveys with MWD in this interval to insure it does not drift westerly. If it does show a tendency to drift to the west the kick off . 10. point will be moved up the hole to avoid any potential problem with intersecting A-12. There are five producing wells in close proximity to the NCIU "B "No. 1. These wells include the A-12 between mudline and the kick off point, the A-3, A-9, A-6 and A-7. The wellpath for the NCIU "B" No. 1 will cross each of these wells, and parallel A-7. The wellpath has been planned so that none of these wells will intersect the safety zone. Shallow Gas Shallow gas hazards can have catastrophic consequences. In view of these consequences, 'drilling to the first casing point should be done cautiously. There is no reason to expect a shallow gas hazard at North Cook Inlet based on the drilling history of the previous wells from the platform, the shallow hazards surveys recently performed for the Arco drilling program. While there are no indications of shallow gas at NClU, the consequences of a shallow gas event are such that a cautious approach is needed to insure such an event does not occur. A 24" hole will be drilled to the first casing point at 2350' TVD, 2600' MD. This hole should be control drilled to further reduce these risks and to maintain directional control. The rig crews, mud loggers, and mud engineer should be closely monitoring the mud returns. Prior to spudding the well, review the diverter procedure found on page 7-3 of Phillips Well Control Manual. Verify that the personnel on board understand the shallow gas plan for this well, and that piping is in place to permit pumping seawater into the pits at high rates to facilitate a dynamic kill procedure. Advise the supply boats to stay clear of the diverter line as much as possible. If a kick is indicated the driller should continue pumping, pick up the kelly above the rotary table, and check for flow. If the well is flowing the recommended procedure for killing a shallow gas kick is a dynamic kill procedure. This procedure involves pumping kill mud into the well at the highest rate possible. If this does not kill the well pump in seawater at the highest rate possible while continuing to mix kill mud. While attempting the dynamic kill preparations should be made to evacuate the platform. If the well cannot be killed a decision will be made whether to continue with the kill procedure, attempt to deplete the gas by flowing through the diverter or to evacuate the platform. Unconsolidated Sands and Gravel The top section of the hole is unconsolidated sand and gravel. These sands and gravels have a tendency to slough. Good hole cleaning is the best way to handle this problem. Pump high viscosity sweeps at frequent intervals while drilling above the 20" casing point. Cook Inlet and Beluga Sands The 12 1/4" hole section will include the Cook Inlet and Beluga sands that are produced on the platform. These sands are very permeable and have a relatively Iow pore pressure, 5.5 - 7.0 ppg. The mud used in drilling this section will be at least 3 ppg overbalanced. This leads to a risk for lost circulation and for differential sticking. Lost circulation is not expected to be a serious problem in this interval. The results from drilling the Sunfish wells and the sequence of workovers have shown these sands can tolerate a large overbalance without losing circulation, however caution is advised. An adequate stockpile of lost circulation material should be maintained on the rig. A large mud overbalance with permeable sands in a deviated well results in a high risk of differential sticking. To minimize this risk keep the pipe moving as much as possible, and use the minimum number of drill collars needed for directional control. The collars that are used should be well stabilized to minimize the potential contact area. Mud properties must be well maintained through this section. The fluid loss should be kept Iow. Soltex should be used to assist with borehole stability and to act as a lubricant. Use the solids control equipment, including the centrifuge., to keep drilled solids as Iow as possible. Avoid the temptation to increase mud weight based on high background gas. The formation being drilled is gas saturated sand and coal. A significant volume of gas will be drilled up. This will result in high gas readings. Raising mud weight will not reduce this and will increase the risk of losing returns or getting differentially stuck. 11. The Beluga sands are not continuous across the field, consequently there is the possibility of encountering a virgin Beluga sand. Virgin pressure in the Beluga was 8.5 - 9.5 ppg. A virgin stringer with a pore pressure of about 9,5 ppg was encountered in the Sunfish No. 2. Caution the drillers to be aware of this possibility and ready to react quickly in the event of a kick as the result of a virgin Beluga stringer. COAL SEAMS Stuck pipe due to coal beds has been a frequent occurrence in this and other fields in the Cook Inlet. These coals will be drilled throughout the well. The most difficult coals are expected to be drilled in the 12 1/4" hole section. The coals in the inlet seem to flow into the wellbore very shortly after they have been drilled. This can result in the bit or the lower portion of the BHA becoming stuck. This problem is best handled by reaming through the coal seam until it is stable. Previous studies have shown that the experience of the driller is the most important factor not getting stuck in the coal seams. The best way to drill the coal seams is to drill a few fe~t of the coal and then ream through the coal until it is stable, The sequence of drilling and reaming should be continued until the coal has been drilled and is stable. The coals may be fractured and have a tendency to cave into the well. A large chunk could result in mechanically sticking the drillstring. Mud weight and soltex have been used with some success to stabilize the coals. Raise mud weight as needed to control the coal seams. The pH of the mud should be maintained as Iow as practical to minimize the solubility of the coal. The penetration rate in the coals will be high. This can result in an attempt to drill a lot of fast hole. Experience in the Inlet shows that this fast hole may result in stuck pipe. The experience of the driller is important in avoiding this. The geologist and mud loggers can be helpful in predicting where coal seams may occur so the driller can be especially alert in areas where coal seams are about to be drilled. In the event the pipe does become stuck, spotting fluids have been successful in some cases in freeing the pipe where the mud was water based. The use of oil based mud should help in this regard. 12. 13. 14. 15. DIFFERENTIAL STICKING There are several sands in the 12 1/4" and 8 1/2" hole section that are expected to be normally pressured and permeable. If mud weight has been raised to stabilize the coal seams then these sands will present a risk for differential sticking. To minimize this keep the pipe moving as much as possible and insure that the drill collars in the BHA are well stabilized. During a fishing job on the Sunfish No. 2 even spiral-wate drillpipe became differentially stuck. Efforts should be made to avoid directional corrections by sliding with a mud motor. Use lost circulation additives at such as Barafiber or Steel Seal to reduce seepage losses and to minimize to differential sticking risk in these sands. OVERPRESSURED SANDS - THE NORTH FAULT BLOCK This well is intended to test the Sunfish sand and North Forelands sand in a southern fault block. Overpressured sands are present on both sides of the fault, however the overpressuring starts at a shallower depth on the North side of the fault, i.e. on the North side of the fault the overpressuring starts above the C sand, whereas on the South side of the fault overpressured sands are not encountered until the North Forelands sand. The planned well track will not cross to the North side of the fault. The precise location of the fault is difficult to determine, however, the planned well track should remain in the normally pressured section of the fault block so there should be no radical change in pore pressure at the fault. There are-two wells drilled in the northern fault block, the Shell Cook Inlet State No. 1 in section 29 of T12N-RgW, and the Sunfish No. 3. There is a relatively sharp pressure transition between the normally pressured sands and the overpressured sands. A 9-5/8 "intermediate casing string will be set near the base of the normally pressured interval, however, there will be normally pressured sands just below the intermediate casing shoe. The higher mud weight needed for the overpressured sands will result in a significant overbalance if any normally pressured sands are present. This presents risk of differential sticking and lost circulation as discussed above. HIGH BACKGROUND GAS The formations that will be drilled are gas saturated coal, sand, and silt. This will result in unusually high background gas readings. Mud weight should not be increased to suppress the high background gas. STUCK PIPE FISHING STRATEGY Obviously the best stuck pipe strategy is to not stick the pipe. Every effort should be made to avoid sticking incidents, however, history in the area has shown that stuck pipe situations can be expected. History has also shown that if the pipe cannot be freed quickly by jarring with the drilling jars in conjunction with a spotting fluid, it probably cannot be freed. Each stuck pipe situation should be considered on a case by case basis, however, in view of the history in the area the decision to sidetrack instead of attempting to fish should be made quickly. Since the probability of successfully fishing a stuck BHA is Iow, efforts should be made to minimize the cost of a stuck pipe incident. This is accomplished in 3 ways: a) Minimize the value of the stuck BHA. Use wireline retrievable MWD tools when possible. Use the minimum number of collars needed for directional control. b) c) Minimize the amount of lost hole. Again use the shortest possible BHA. Minimize the time spent fishing. Since the probability of successfully freeing stuck pipe is Iow, backing off to run fishing jars should be considered ONLY if the drilling jars will not function. If the drilling jars work and do not free the pipe then the well should be sidetracked quickly. Back off as deep as possible and set a sidetrack plug. An expensive fishing job to save $500,000 worth of hole and BHA cannot be justified unless there is no alternative. ARCO, PHILLIPS 3 - 31 - 98 ADL- 374O81 ARCO, PHILLIPS 3 - 31 - 98 ADL- 374O83 ARCO PHILLIPS 3 - 31 - 98 ADL- 374056 PHILLIPS HBP ADL- 1874O + + R10W ARCO PHILLIPS HBP ~L 37831~,~ I ARCO PHILLIPS HBP ADL- 17589 8 - 31 - 96 ADL- 3691O1 i ARCO ADL- 37831 ,I ARCO, PHILLIPS PHILE PS HBF ADL-, 759O - ~ R9W PHILLIPS HBP ADL- 18741 T 1 2 N T 1 1 N PHILLIPS PETROLEUM COMPANY /vcz'~ "~ " /,/o . / ................. 5~- ~ ~o~ 9 80 ~co ~_ COOK INLET BASIN OIL & GAS LEASE OWNERSHIP MAP o 2000 4000 sc,,,,~ {FEE'rI / ~'0 FNL ~ I?/~ FSL /~0 FEY.. G~ ,361 31 ,__ " T 12N I 6 · j TilN 6 I I ~ '~ I . · · · / t I~ ' ~ I I. I ' ' I I , i ' I · . _1 6 I ' :' 6 5 i i ii i i ~a 7 'SCAL~ "'~'~'~,000' 7 8 ~G Ng. I LEG N~. 4 LEG N~. 2 LAT. 61° 04' ~.~" LAT. 61° 04' ~6.89" LAT. 6P 04' 35.83" LAT. 61u 04' 36.~'.. LONG.150° 56' 55.~' ~NG. 15~ 56' 54.25" ~. 15~ 56' Y= 2~586~731 ~ 2~86~781 Y= ~6~ 674 Y=2~586,724 F~M N.W. COR.' ~OM N.W. C~. FROM N.W. COR. FROM NW. COR. ~250' SOUTH & 1,198' ~UTH & LSd' SOUTH & 975' EAST. . 1~045' EAST. ' · 1~018' E~T. L085~ EAST. CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and li.censed to practice land surveyihg in the State of Alaska 'and that this plat represents a location suwey made by me or under my supervision and that all dimensions and other details are correct. " / D A~'E NOTE The location of the platform legs was accomplished by using triangulation stations BELUGA,TERRACE,and TYONEK which are all U.S.C.~G.S. stations. AIl coordinates are Alaska State Plane, Zone,~. NOTE: Plat amended 7AUG.68' to show · r.v~sed leg numbering. · · . . . .. · · . . . , · , · , ..., , .; · , . ., · · . ,. . , o .. , 'PL AT--{3 · .... NORTH COOK I NL.E;TUNIT PLATFORM"A ' , ~,o. PHILLIPS PETROLEUM CO [D~TE.~, ~u,E~ l~.~:L,,os~'~'~sso~ "SCALE· I"~'1000' '~ Land & Hydrographic l' ~'11374 PP' i1-15 I Surveyor, [DRWN I~K~ ' JG= - j ~502 W. NO~THE~L~H~ ( ii i i i i i ( i i ii i i ii i i i i Leg I Leg 4 North Cook Inlet Unit A-5 N.C.I. Un. A-$ N.C.I. Un. N.C.I. Un. A-I N.C.I. Un. Leg ,3 N.p. L"Un. A-6 N.C.I. Un. , / : N,C,,'I. Un.A-2 ." __ IL i ii i PHILLIPS PETROLEUM COMPANY 516 "1[ STREET &NCHORAGIrI&LI,$KA .. . _ NOR:i'H COOK INLET TYONEK PLATFORM ¢001( INLE. T, ALA~;K,~ _ ~OTE_: Using PLATFORM NORTH, Slot No.I will be the furlhest plofform North slot In plofform North- west ctuodront of ony leg; Slott are numbered I I thru 8 In a counter-clock-wise direction. / [PLATIroRu LOC&TION." i,';.i. IIN-tW"IO~,TZ: 4~-IO.It ;_ - . l...w......~.....!l ' . '. .... . I.?T 1'0 ~.CAL. Z _ Flowline Bell Nipple Fill-up Line 30" 500 psi Annular Diverter 30" Structural Pipe 28" x 30" Swage. 28" Structural Pipe L II 16" Adapter Spool 30" Drilling ~ Spool . ~!$ "Hydraulic Valve Opens Automatically when Annular Diverter Closes 30" Riser Spool 30 "Adapter SpoolI t 30"Adapter Flange 30" ALT-2 Squnch Joint Connector Vetco-Gray 4" Valve for cement returns FIGURE I 30" WELLHEAD DIVERTER SYSTEM Use while drilling be~ 1997 - PHILLIPS PETROLEUM COMPANY North Cook Inlet Unit "B" No. 1 11 OPEN CLOSE FABt?I-VALVE FIG. $6 KNIFE VALVE ANSI 500 FLANGES TYP. I HYDRIL 29 1/2" 5ooPs ANNULAR I I UNOCAL Ri6-428 29-1/2' - 500 DIVERTER STACK 1. D/VERIER ANNULAR NOR~AI. LY OPEN. 2. DIVERTER VALVE NOR,tfALL¥ CLOSED. 3. SYSTEM DESIGNED $0 '[H4r WHEIV rt-lE ANNUD~R IS CLOSED, VALVE AU rO- A4TICALL Y OPEN& Flowline I I Fill-up Line 13 5/8" 5M Annular Preventer Kill Line 10M Blind Flange 10M Blind Flange 13 5/8" 5M Pipe or Variable Bore Pipe Rams 13 5/8" 5M Blind Rams e Choke Line ':'"' i 13 5/8" 5M Pipe Rams I _~ 13 5/8" 5M Flange 13 5/8" 1,0M .x 13 5/8" SM Adapter Flange I 13 5/8" 10M Riser ~ 13 5/8" 10M Flange Vetco NT.2 10M Connector Vetco MB-189 Multi-Bowl 10M Wellhead i'1 ~ Disposal Lines 21 Gate Valve . J ~ 114" 2M Offset Adapter Flange (13 3/8" x 2 3/8" x 2 3/8") 1 114" 2M Adapter Flange 20" Mandrel Hanger 1 28" Structural Pipe I.~'"-- -- .~ , ' ,- 13 5/8" 5M BOP and Riser System J PHILLIPS PETROLEUM COMPANY Use while Dnlhng below 13 318" and 9 5/8' cas .... .prd/ Ma~/08, 19;7 '' ' ings I' North Cooklnlet Unit B No. 1 ~OP STACK CONFIGURATION 13 5/'8 RSRRA HYDRIL '~ 3 5/8"-5000PSI GK ANNULAR BOP SCRD¥ HEAD ~3 5/8'-5,000PSI HUB BOTTOM CONNECTION I NYDRIL ~3 5/8"-5,000PSi DOUBLE RAM BOP HUB CONNECTIO.I'IS 4. '~/I ~'-5,00OPSI SIDE OUrLD'S WiTH MANUAL LOCKS CHOKE WING NCR ~NUAL HCR "KILL WING McEVOY 4:~/16"-10,000 TYPE E GATE VALVE I$ 5/8"-5,000 PS! HUB X 15 5/8"-5,000 PS/ FLue. ~cEVO¥ 3 1/16"-~o,ooo TYPE E GATE VALVE 4. I/'i6" 5M ,',¢ 4, l/'16"-t0M DSA ~xk-..- H~RIL 15 ,,,5/8"-5,000PSl . MPL RAM BOP HUB CONNECI'IONS 4. l/l 6"-5,000PSI SIDE OUTLETS WITH MANUAL LOCKS BLOW-OUT PREVENTER STACK UNOCAL RIG 428 Tyonek Deep I' Proposed Wellbore Schematic Injection zone 3350' TVD (3710' MD) Cook Inlet Sands 3700' 'i'VD (4140' MD) Beluga Sands 4482' TVD (5122' MD) Tyonek 'C' sand 11025' TVD (13138' MD) Sunfish sands 12082' TVD (14380' MD) North Forelands sands 12682' 'I'VD (15116' MD) 20" csg @ 2400' TVD (2600' MD) 2 3/8" tbg @ 3375' TVD (3740' MD) TOO @ 3500' TVD (3771' MD) 13 3/8" csg @ 4000' 'I'VD (4600' MD) .:..,-:.~ --.~...:*, -....,...-. ...~.,-.;, .- o .:i;,'. · . .., .. , · . ; ';,,--';'.~ · :' i '.;~',;:: .... ;.,~. ': '; :; - .:;i.I ...... ........ :'~..i!;:' '~,;t:,,:;.. ,;,;;;~:: ...... .... ,., ',.;,% '?!.: ,.i' ?i .,: :; .,, .., ,. ........ Stage tool @ 5000' TVD (5800' MD) TOL 7" @ 11600' TVD (13900' MD) 9 5/8" csg @ 11900' TVD (14200' MD) 7" liner @ 13280' 'i'VD (15800' MD) Top of CdmeAt i 30' ~ 40T Strings · a ' e 3740' Cook Inlet Sar : Upper Beluga .-.. '": & se~c Lower Beluga Top of Cement '~ ~' Sand g Sunfish Sand Ncr. h Forelands ~,~nl .: .! .. ..: .~ : ' ~ 15,80o' 15.800' =,PROPOSED 4r.(Make,Type) ~nnulus Fluid: CASING & CEM( NT ABB Vetco-~ray ABB Vetco-Gray I RKB-BHF: - DIAGRAM IRKB-THF: -- !RKB-MSL: 132.00 ITOC: ; OD iWater Depth 130.00 Top i Bottom I W'[' [ G~dc I Conn. [ [3umt ) Coil ) Tcttsn Structural Ca.~ing: Drive Pipe 407[ I [ ~ I I 20" Conductor C--in~: PPCo. Allowable Ratinqs 2.6001 133.0 Ib/R ) K-55 ) BT&C I 2860l 1410l 1700 13 3/8" 9 5/8" 7" Surface Casing: 5o] 4.5ool 72.0 i~11 I L-SO [ SL/X { 4730 Intermediate Casin{: 2520 } 761 501 14.2001 53.5 lb/RI P-il0 I ar&c ] 87101 75001 Production Liner:. ' 13~00l t5.8001 321~'R { L-80 { BT&C I 81601 81101 1159 528 CEMENTING PROGRAM ds Conductor Cement with 1530 sx Il'burton Premium Cement with 3% ge[ -~ 0.25 % CFI~-3 plus t.0 % CaCl2 £oilowed with 690 sx H"ourton Premium + 2.0 % CaCl2 + 0. 1% L;bK-3. Cimulatc cement to surface. Surface Cement with 1245 s.x H'burton Premium Cement with 3% scl + 0.25 % CFR-3 plus 1.0 % CaCI2 followed with 1075 sx Fl'burton Premium + 2.0 % CaCI2 + 0.1% CFR-3. Circulate ccmcnt to sm'face. ~tcrmcdiatc 1st Stage Cement with 215 sx Halliburton Premium Cement with 0.2% CFR-3 plus. 2nd StaSc '0.10Sai/sxHalad344L+0.15% HR-5. TOC (~ 13,600'. C~meut with 100 mx Il'burton Premium Cement with 3% gel + 0.20 % CFR-3 plus0.1. % HR-5 followed with 380 mx H'burton Premium + 0.2%CFR-3 +0.1 Production Halad 344L + 0. l0 % I-~.-5 . TOC ~ 4,000'. Cement with 380 ~x H'burton Premium + 0.2 % CFR-3 + 0.15 sal/sx Halad 344L + 0.25 % HR-5 . TOC ~ 13,600' (300' above Liner Top.) NOTE: The two 2 3/8" tubing strings will be strapped securely to the 13 318" surface casing as it is being run., and well centralized. Cement evaluation will confirm the competency of the cement pribr to utilizing the 2 3/8" tubings as disposal strings for cuttings injection. PBTD: 15,760' JSupv: {Tbs Wt: Well: North Cook Inlet Unit "B" No. 1 ,Location: T,vonek Platform, Cook Inlet. Alaska [Date: Juno 3, 1997 Field: North Cook Inlet PRD NORTH COOK INLET UNIT "B" No. 1 MUD WEIGHT / CASING POINT / PRESSURE PLOT (TVD) . 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O ! .... 4 . . i .... 1 - - i i i i ........ i ...... i ...... i ...... i-- ---- -r - - - .... -~ ~s~ ' ! i i i i i i i i i i .... l ...... i ...... i ...... i ...... I. ..... J _ i i i i i i i i i i i i ..... i ...... i ...... i ...... i ...... r ..... 't - ! i i ! i i i ! ! i i_ i i i i i i .... i ...... i ...... i ...... i. ..... d . i N~m-I , ! , i _ . .1 ...... - -..i ...... i i ! . . .i ...... i i - - -i ...... ! ! i 7'O l~E ' '1 ...... i ...... i ...... i ...... , ...... ! ...... r ..... ~ - - -i ...... , i i , i i , i i i , i i ! , i , i ! , i I i i i , , , , i i i j ..... .i ...... i ...... i ...... i ...... i ...... k ..... J . . . j ...... , i i i i , i i l , , ! i i i i i , i , , i i i i i i i i i i , i i i i , i , i , , i 8 9 10 11 12 13 14 15 16 17 MD 14200 18 Mud Weight(ppg) '='MUD WEIGHT wCasing --Series5 ~LEAK-OFFTEST ='CSG ~CSG ==CSG ,,,Series 10 ~S'Fish 1 ~N. F'Lnds 1 aS'Fish 2 ~S'Fish 3 DRILLING PROCEDURE SECTION I: 24" HOLE ( 20" CASING) - DEPTH 2600' MD-RKB (2400' TVD). A. GENERAL REMARKS 1. Intent- Drill a 24" hole to 2600' MD-RKB. The hole will be directional, with kick-off point at 500'. Build angle at 2 deg/100' until hole angle of 35 degrees is built. Shale interval between sands at this depth is minimal). Set and cement 20" casing back to the surface. (A Top Job is required if the cement falls back). Notify the AOGCC at (907) 279-1433 prior to spudding. 2. Litholoov and Anticipated Problems- The lithology is expected to be sand and shale. . The top section of the hole is unconsolidated sand and gravel. These sands and gravels have a tendency to slough. Good hole cleaning is the best way to handle this problem. Pump high viscosity sweeps at frequent intervals while drilling above the 20" casing point. Wellhead Proqram- Weld 30 "ALT-2 squnch joint onto 30 "conductor using the 28" x 30 "swage adapter. Install riser to drilling deck. Install flange for 30" 500 psi diverter, diverter and then bell nipple riser to rig floor and mud system. Maintain clearance for 16" diverter line. Install diverter line and function test annular and diverter valves. NOTE: Diverter lines are to be installed as straight as possible. Pump water through the diverter lines to insure they are clear. Shallow gas was not a problem in the previous wells, but must not be overlooked as a potential problem. 4. BOPE Test Pressures- Function test of diverter and valves. 5. Casinq Pressure Test & Leak-off Test- Not Required. 6. Directional Drilling Instructions- Follow directional drilling program. RIH with 24" mill to clean up burrs at 30 "casing shoe. RIH w/24" bit, steerable motor and BHA including MWD and drill 24" hole to kick off point at 500' RKB. With the steerable motor the hole can be nudged in a southerly direction above the planned kick off point. Control drill to minimize risk of overloading hole with drilled solids. Make high vis sweeps as needed to clean hole. Note: The NCIU A-12 well was drilled from a surface location 4' west of the planned NCIU "B" No. 1. This well is essentially vertical, with slight deviation south west. The Sunfish No. 3 was drilled from a surface location 4' east and 7' north of the NCIU "B" No. 1 and deviates to the north. The NCIU "A" No. 1 3 was drilled from a surface point 9' north and 4' west of NCIU "B" No. 1 and. There should be no proximity problems with any of the offset wells as long as the well does not deviate to the west. Since the kick-off point is shallow, the well will be nudged to the southeast. At kickoff point, begin sliding to kick well off per directional plan. Drill to 20" casing point at __+ 2400' TVD, __+ 2600' MD. This directional plan is based on a maximum build rate of 2°/100 ft. Dog leg severity in excess of 5°/100 ft could cause both drillpipe fatigue and excessive torque and drag. To minimize the potential for these problems THE DOG LEG SEVERITY CAN NOT BE PERMITTED TO EXCEED 3°/100 FT. CONTROL DRILL WHILE SLIDING TO MINIMIZE THE TENDENCY OF THE BHA TO BUILD ANGLE FASTER THAN DESIRED. A gyro steering tool should be considered to permit the survey instrument to be located closer to the bit than a magnetic tool such as a MWD tool would permit. Report surveys every 30' through the build section. SPECIAL INSTRUCTIONS A. Insure the following equipment is in place and fully operable prior to beginning drilling operations: a. Pit level monitor with audio and visual warning system. b. Mud return indicator. c. Gas detector with audio and visual warning system. d. Mud volume measuring device (trip tank, etc). B. Install a wear bushing before drilling to prevent wear in the casing head. B. DRILLING DETAILS ( 24" HOLE TO 2600 MD-RKB) 1. Bottom H01e Assemblv 24" Bit, Bit sub, 9 5/8" Steerable Motor, Float Sub, 10' 9 1/2" Monel, Stab, MWD, stab, 60' Non'-Mag collars, 150' HWDP, Jars, 25 jts. HWDP. 2. Bits, WOB. RPM - 24" 1-1-4; or 1-'1-5, 5- 25 M, 120-240 3. Hydraulics- Maintain adequate circulation rate to clean hole. Recommended Range: 800-1200 GPM 4. Mvd Prooram- Depth TVD Weight PPG Visc. PH PV YP FL Mud Type 300'-2400' 8.6 - 9.0 50 - 100 8.5-9.5' 10-15 20-40 10-20 Water (2600' MD) Base ,, . Use pre-hydrated bentonite and extender flocculated in inlet water. Use all solids control equipment, keeping LGS below 6 % if possible. Sweep hole as needed with 50 bbl pills made up of 25 ppb gel and 1/2 ppb caustic in fresh water. Treat system with Drispac if seepage problems occur. Maximize pump rates to provide increased annular velocity. * NOTE Have funnel viscosity 50 - 70 sec/qt while drilling through gravel and .when running casing. Survey ReQuirements and Deviation Restrictions A. MWD Surveys: MWD surveys every 30' drilled to 2600'. Run one survey at top of hole to confirm conductor isn't crooked. B. Deviation: Maximum 2 degrees per 100' from vertical through build section. Once angle is built, hold to casing point. 6. Samplina. Mud Loa_~ina & Electric Logs- None Required C. CASING AND CEMENTING DETAILS( 20" CASING) AT 2600' MD-RKB 1. Casing Specifications: (Top to Bottom) PPCo Pw Torque Depth Description Burst Coil Ten Opt fi-lb Drift 0-2600' 20"1331b/fiK-55BTC 2860 [ 1410 [ 1700 4230 18.54 , . Float Shoe : Float Collar & Loc · Centralizers : Connection Lock Cementing Plugs Circ, Mix, Displace Rate Lead Slurry ,' Slurry Weight ~''!~ ~'~''t''''':'/~¢ Mix Water - Type Pumping Time Desired TO~ Compressive Strength Weatherford Model 303 Sure Seal II (PDC drillable) Weatherford Model 371 Double Sure Seal with Model 154 stab-in stinger 1 jt. above shoe Weatherford Model ST-II Non-Weld: 1-7' above shoe;1 on FC;1 every 4th joint to surface Thread lock all connections on through top of Float Collar Top plug only Maximum practical 1530 sxs. Halliburton Premium +3% gel + 0.25% CFR-3 + 1.0% CaCI2 12.0 PPG 14.98 gal/sk. Inlet Water 3 - 4 hours Surface 12 Hours - . Tail Slurry : Slurry Weight : Slurry Yield : Mix Water - Type : Pumping Time : Compressive Strength : 690 sxs. Halliburton Premium + 2.0% CaCI2 + 0.10% CFR-3 15.9 PPG 1.16 cu.ft/sk 5.0 gal/sk. Inlet Water 3 - 4 hours 24 Hours - 2500 psi. Total cement volume based on 100% excess lead slurry and 50% excess tail slurry in open hole. Tail volume slurry based on 500' of casing cemented. SPECIAL INSTRUCTIONS A. Make wiper trip prior to running casing. Spot Hi-Vis pill prior to POOH. a. Run 20" conductor casing to 2600'. Fill each joint while RIH. Make up landing joint above 20" mandrel hanger spaced out so casing is at a convenient height above rotary table when landed. Set down and land casing on landing ring. Install false rotary table. C. Do TIH with stinger for stab-in float collar on drillpipe. Stab into float collar. Break circulation, checking the top of the 20" casing to insure stinger is sealing into stab-in collar. Circulate and condition, reducing mud viscosity to minimum possible for cementing. Circulate until returns are clean, then cement with casing stationary. Displace cement with mud, then unsting from float collar, POOH one stand and clear drill pipe. POOH with drill pipe. WOC a minimum of 8 hours and until surface samples have set up. Verify top of cement is above the top connection on the 20" casing, if it is not run 1" pipe into the 20" x 28" annulus and cement to surface. Perform top out cement job with 1" tubing if cement returns not apparent at surface.. E. Check slurry density with pressurized mud scales throughout the job. Catch samples of slurry and dry cement periodically while mixing. CEMENT TO BE USED MUST BE LAB TESTED PRIOR TO SENDING SAME TO THE LOCATION. Complete PPCO Casing and Cementing Report and send to the Houston Office. SECTION II: 18 1/2" HOLE ( 13 3/8" CASING) - DEPTH 4600' MD-RKB. A. GENERAL REMARKS 1. Intent- Drill an 18 1/2" hole to 4600' MD-RKB. (Consider under reaming to 22" to attain adequate clearance for 13 3/8" casing and dual disposal strings of tubing if hole appears tight). Note: Shale interval between sands at this depth is minimal), Set and cement 13 3/8" casing with dual 2 3/8" disposal tubings back to the surface. Perform a top job with 1" tubing if necessary, 2. Litholo_ov and Anticinated Problem,~- The lithology is expected to be thick sand intervals and shale. 3. Wellhead Pr0qram- Back off 20" landing joint from 20" mandrel hanger. Disconnect diverter line and release ALT-2 connector. Raise diverter and riser assembly enough to install 20" mandrel packoff. Re-Install ALT-2 connector and diverter assembly and reconnect diverter line. Function test diverter and valves. . BOPE Test Pressures- Function test 30" diverter and valves. Casino Pressure Test &~ Soecial Drillino Instructiqn.~- Install drill pipe protectors on drill pipe that will be rotating inside 20" casing. B. DRILLIN(~ DETAILS (18 1/2" HOLE TO 4500 MD-RKB) 1. Bottom Hole Assembly 18 1/2" Bit, Bit sub, 9 5/8" Motor, MWD, 2-9 1/2" NMDC's, XO, 30 its 5 1/2" HWDP 2. 'Bits. WOB, RPM - 1-1-4, 20-25M, 120-240 3. Hydraulics- Maintain adequate circulation rate to clean hole. Recommended Range: 800-1200 GPM 4. Mud Program- I Depth TVD Weight PPG Visc. PH PV YP FL Mud Type 2400'-4000' 8.8 - 9.2 40-50 8.5-9.5' 10-15 15-25 6-10 Water (4500' MD) Base Continue use of conductor mud system. Use fresh water for make-up mud. Continue use of all solids control equipment, sweeping hole as needed with 50 bbl pills. Continue the PAC treatments. Use Kwik- Seal and BaroFibre for any losses or excess seepage. Maximize pump rates to provide increased annular velocity. . . Survey Reouirements and Devietion Restrictions A, MWD Surveys: Continue MWD surveys every 30' drilled to 4500', B. Deviation: Maximum 2 degrees per 100', Hold angle to casing point. Sampling, Mud Loaoina & Electric Loq.~- DIL/GR/Density/Neutronand caliper at 4600'. Log from 4,600' to 2600'. C. CASING AND CEMENTING DETAILS( 13 3/8" CASING) AT 4600' MD-RKB 1. Casing Specifications: (Top to Bottom) PPCo Pw Torque Depth Description Burst Coil Ten Opt ft-lb Drift 13 3/8" 72 L-80 SL-X 4740 [ 2520 I 1231 4230 12.2575 I1 0- 4600' MD . . Float Shoe · Float Collar & Loc : Landing Base & Loc : Weatherford Model 323 (PDC drillable) Weatherford Model 402 NT (PDC) 1 jr. above shoe Weatherford 13 3/8" Landing Base w/welded fittings for 2 3/8" tubing to land in. Set at 3600' TVD. . Centralizers : 5. Connection Lock : 6 Cementing Plugs : Circ, Mix, Displace Rate : 1-7' above shoe; 1 on FC; 1 every joint for next 8 joints, then use modified eccentric rigid turbolators to space 2 3/8" tubings every joint to surface. Thread lock all connections through top of Float Collar. Top plug only Maximum practical Lead Slurry-- : Slurry Weight : Mix Water - Type : Pumping Time : Desired TOC : Compressive Strength : 1245 sxs. Halliburton Premium +3% gel + 0.25% CFR-3 + 1.0% CaCl2 12.5 PPG 12.63 gal/sk. Inlet Water 3 - 4 hours Surface 12 Hours ~ . Tail Slurry : Slurry Weight : Slurry Yield : Mix Water - Type : Pumping Time : Compressive Strength : 1075 sxs. Halliburton Premium + 0.10% CFR-3 + 1.0% CaCl2 15.9 PPG 1.16 cu.ft/sk 5.00 gal/sk. Inlet Water 3 - 4 hours 24 Hours - 2500 psi. Total cement volume based on 50% excess in open hole. Tail volume slurry based on 1500' of casing cemented with 50 % excess. Actual volumes to be determined from caliper log. Use caliper plus 20% excess. SPECIAL INSTRUCTIONS A. Make wiper trip prior to running casing. a. C. Run surface casing with 2 3/8" tubings, securely strapped from 13 3/8" landing base sub (3600') to surface (See attached equipment drawings). Install 13 3/8" mandrel landing hanger. Attach dual 2 3/8" x 13 3/8" isolation landing assembly, then lower hanger from RKB to 20" landing ring. Position the casing with landing joint so that hanger is slightly above landing ring and tubing strings are oriented correctly. Pump cement slurries, then set down and land on landing ring when plug bumps. Establish circulation and circulate one casing volume. Cement with casing stationary. Displace cement with mud. Bump plug with 500 psi over the final displacing pressure. If plug is not leaking, increase the pressure to 2000 psi and test casing for 30 minutes. Bleed pressure to 0 and check for backflow. 13 318" X DUAL 2 318 " ECCENTRIC CENTRALIZER !" TYP. ~ NOTES: 2-3/8' Fj rUB/~CG 18.542" ORIFI' 01,4 20" 1J$ PPF C,451NC 13-,3/8" CASINO // --~/z'-lflu~vc x I/2' Lc n'P. olcr~ ~HRS I-J ~) 'T A_ F -~ [1 _ .1' t- _ c 13 3/8" X DUAL 2 318 " LATCH - ON CLAMPS NOFE$: I. BAND ~41EROIL: d/16" I'HK. X ¢' WID£ Z. I!' IS R£CO~XlENO£O IHAf THIS ~aO BE PlJiCED ON lOP OF ~HE IS-Jla" COUPL INC. 2-J/8' FJ TUBIXG \\ · · 20' /Jd PPI' C4EING i i ~ i I I ! i ! i ~ i I [OK.I: 89704182 I/2"-~.,TUNC X I/2" LC. Z 0 ._ C OD (7 f'- (l {I uJ \ o J U (7 ~ u ~ L 0 > o o /.--15-$/8" 1/~" THK. PLATE FLARE I 56' 2-5/8' £J rUB/NC 2-$/8' BUtt PtUC CONNECTOR ....----J- .... 17-J/16' ~X. 0/~. l°~'t: ~?041~)' // \. \ I J-J/8' C~$7~¢ / / '\ I I "A' \.x,. I · \.'~,. /"/' 18.542" Ot~l,I:-£ OIA. '~'~. j I ./"/' 20" Ill PPF CASINO I J-J/8' CASING · . i $£6~ION " A" -'A" DI~rcNsIoNs ARE SHOWtt FOR RErERENC£ PURPOSES ONLY AND SUS,JECT T0 CHANC£ WITHOUT NOTICE. ,..~ ~. ~.~ .[s~=! ,~ ~.~,s,o.~ .[ - ,.~s I ~ .o~ ~ ~w,.~ I a~: lo,sc ....... Z' OU~INE I3-J/E X 2-3/~ ~NDINO V 04/30/9 I SE., FOR TRIPLE STRINa 0970418Y I'- '{. F, Notify the AOGCC a minimum of 24 hours prior to the casing job. Also, contact the AOGCC if no cement is circulated to the surface. Check slurry density with pressurized mud scales throughout the job. Catch samples of slurry and dry cement periodically while mixing. CEMENT TO BE USED MUST BE LAB TESTED PRIOR TO SENDING SAME TO THE LOCATION. Complete PPCO Casing and Cementing Report and send to the Houston Office. Nipple down the Riser, diverter and diverter lines. All cuttings grinding, handling and transporting equipment should be installed at this time because OBM will be used from this point to TD. SECTION III: 18 1/2" HOLE ( 13 3/8" CASING) - DEPTH 4600' A. GENERAL REMARKS - PREPARE WELL TO HANDLE CUTTINGS 1. Intent- Perforate 2 3/8" tubings and take pump-in test for disposal service. MID- RKB. 2. W~llh,ad Program- After running and cementing 13 3/8" casing, release mandrel running tool. ND diverter lines, diverter and release riser. Make finish cut on both strings of tubing. Slip the compression seal assemblies (3) over the tubings. Install pack-off seals and landing ring on 20" hanger. Install the 21 1/4" 2M studded flange (thread ring onto 20" mandrel hanger). Install ring gasket and 21 1/4" offset adapter with 13 3/8" and dual 2 3/8" preparations and ABB Vetco-Gray Multi-Bowl wellhead. Inject sealant and test 13 3/8" test port and 2 3/8" tubing test ports.. SPECIAL INSTRUCTIONS A, After testing wellhead seals, install APl 5-bolt flanges to dual tubing outlets. Install 2" 3M gate valves and manifold piping system to cuttings injection pump. Bo C. MIRU Schlumberger wireline. TIH with 1- 11/16" gauge ring and 30' sinker bar to 3600' TVD. Make Gamma Ray correlation run. Pick up Schlumberger Perforator Orientation Tool. Correlate with open hole logs and previously run GR correlation log. Perforate the disposal sands with the oriented perforating assembly. POOH with tools. With cuttings-injection pump, establish injection rates and pressures into the disposal horizon. D. Notify the AOGCC a minimum of 24 hours prior to the perforating and pump-in test so they may witness same if required. Perforator Oried .tion Tool (POT-CA) POT-C Shock absorber ,] Dual packer g string Tubing string Gun string Tubing ., Parallel string tubing string Gun AA Description The POT-CA is designed to allow oriented perforating in multiple string completions. This tool takes an electromagnetic measurement that will, in many situations, permit the operator to establish the orientation of the gun string relative to other pipe(s) in the hole. The gun string is rotated downhole and stopped at the desired orientation. Usually this is pointing away from the other tubing string. The POT-CA replaces the POT-B which used a radioactive source, in the tubing string not being perforated, as a reference to orient the guns. The POT-CA has been used many times in situations where the client wants to shoot through a tubing string in a multiple completion and not hit the parallel string'. This is done to get access to a reservoir that would otherwise only be available to perforate/produce after a workover. The POT-C is combinable with any of the Through Tubing Gurt..Systems. Depth control is achieved with a 8ollar Iocator. Specifications: Max. OD 1.7 in. Max. temperature 350OF Max. working pressure 15 kpsi Max gun length 20 ft Tool length (no EQF.) 19.2 ft Tool weight 122 lb The Tool comes complete with the downhole tools and a Module (POT-M). Software for the POT is part of the CP 38.0 baseline. http.'//www, rosharon, wirel/ne.$/b, com/$ptext/mar/Cdsheet$/tcpperfo/pot_ ca.pc// © $ch/umberger (7-Feb-.¢6) SECTION IV: 12. 1/4" HOLE ( 9 5/8" CASING) - DEPTH 11,900' TVD (14,200' MD) - RKB. A. GENERAl, REMARK-~ 1. Intent- Drill a 12 1/4" hole to 14,200' MD-RKB, holding angle and direction to casing point. Log well as per geological prognosis, then set and cement 9 5/8" casing. Stage tools will be required to isolate the Cook Inlet / Beluga Gas Sands. 2. Litholoqy and AnticiDal;ed Pr0blem~- The lithology is expected to be massive sands, shales and abundant sloughing coal seams. This hole section will include the Cook Inlet and Beluga sands that are produced on the platform. These sands are very permeable and have a relatively Iow pore pressure, 5.5 - 7.0 ppg. The mud used in drilling this section will be at least 3 ppg overbalanced. This leads to a risk for lost circulation and for differential sticking. Lost circulation is not expected to be a serious problem in this interval. The results from drilling the Sunfish wells and the sequence of workovers have shown these sands can tolerate a large overbalance without losing circulation, however, caution is advised. An adequate stockpile of Barafibre and Steelseal lost circulation material should be maintained on the rig. A large mud overbalance with permeable sands in a deviated well results in a high risk of differential sticking. To minimize this risk keep the pipe moving as much as possible, and use the minimum number of drill collars needed for directional control. The collars that are used should be well stabilized to minimize the potential contact area.. Mud prop-rti~.s must be well maintained through this section. The fluid loss should be kept Iow. Use the solids contr'b'Tequipment to keep drilled solids as Iow as possible. ' "' Avoid the temptation to increase mud weight based on high background gas. The formation being drilled is gas saturated sand and coal. A significant volume of gas will be drilled up, which will result in high background readings. Raising mud weight will not reduce this and will increase the risk of losing returns or getting differentially stuck. The Beluga sands are not continuous across the field, consequently there is the possibility of encountering a virgin Beluga sand. Virgin pressure in the Beluga was 8.5 - 9.5 ppg. A virgin stringer with a pore pressure of about 9.5 ppg was encountered in the Sunfish No. 2. Caution the drillers to be aware of this possibility and ready to react quickly in the event of a kick as the result of a virgin Beluga stringer. Stuck pipe due to coal beds has been a frequent occurrence in the other wells and fields in the Cook Inlet. Coal beds will be drilled throughout the well, with the most difficult coals expected in this 12 1/4" hole section. The coals in the inlet seem to flow into the wellbore shortly after they have been drilled. This can result in the bit or the lower portion of the BHA becoming stuck. This problem is best handled by reaming through the coal seam until it is stable. Previous studies have shown that the experience of the driller is one of the m~Jst important factors preventing sticking in the coal seams. The best way to drill the coal seams is to drill a few feet of the coal and then ream through the coal until it is stable. The sequence of drilling and reaming should be continued until the coal has been drilled and is stable. The coals may be fractured and have a tendency to cave into the well. A large chunk could result in mechanically sticking the drillstring. Mud weight and soltex (water base) have been used with some success to stabilize the coals. Raise mud weight, only as needed to control the coal seams. Penetration rates in the coals will be high. This can result in an attempt to drill a lot of fast hole. Experience in the Inlet shows that this fast hole may result in stuck pipe. The geologist and mud loggers can be helpful in predicting where coal seams may occur so the driller can be especially alert in areas where coal seams are about to be drilled. . . . There are several sands in the 12 1/4" and 8 1/2" hole section that are expected to be normally pressured and permeable. If mud weight has been raised to stabilize the coal seams then these sands will present a risk for differential sticking. To minimize this, keep the pipe moving as much as possible and insure that the drill collars in the BHA are well stabilized. Efforts should be made to avoid directional corrections by sliding with a mud motor. Use lost circulation additives to reduce seepage losses and to minimize to differential sticking risk in these sands. Wellhead Pro(]ram- Install the Vetco-Gray Multi-Bowl wellhead in Section II1. BOPE ReQuirements and Test Pressur~,~ 13 5/8" 5M BOPE is required. Test pressures are as follows: Initial Installation Rams: 5000 psi Annular: 3500 psi Casin(~ Pressure Test & Leek-off Test Weekly 2500 psi 2500 psi Pressure test 13 3/8" casing to 4000 psi. GIH with BHA. Drill the float equipment and 10' of new formation. Perform a Formation Integrity Test as per well control manual to an EMW of 13.5 ppg. Contact Drilling Superintendent if FIT leak-off occurs before 13.5 ppg EMW. Soecial Drillinq Instructions A. B. C. D. Install__ a wear bushing before drilling to prevent wear in th.e. casing head. Drill 13 3/8" shoe and float equipment with PDC bit and rotary ~ssembly, Use minimum surface RPM while drilling out to keep from breaking up shoe cement job. Suspend drilling operations when a mud wt. of 12.0 ppg or 11,200' TVD is reached, whichever occurs first. Contact Drilling Superintendent if mud weight requirements exceed 11.0 lb/gal. At TD, circulate hole clean, C&CM for logging. 13. ORILLIN~ DETAILS (12 1/4" HOLE TO 11900TVD (142-00 MD-RKB) 1. BQttom Hole Assembly 12 1/4" Bit, Motor, stab, MWD, 2 -8" Non-Mag DC's, XO, 5 jts HWDP, Jars, 25 jts. HWDP, DP. 2. Bits. WOB, RPM - 1-1-4, 20-25M, 120-240 PDC 20-25M, 60-150 Detailed Bit Program being finalized. 3. Hydraulics- Maintain adequate circulation rate to clean hole. Recommended Range: 600-1000GPM 4. Mud Program !DepthTVD IWeightPPG [Oil/Wtr IPVRatio IYP LossHPHTFluid Mud Type 4000'-9300 9.5-10.0 70/30 10-30 < 20-25 3-5 Oil Base (11000' MD) 75/25 Invermul 9300-11900 10.0-12.0 80/20 25-35 15-20 3 - 5 Oil-Base ( 14200' MD) Invermul o Drill out with 9.0 ppg mud. Use soltex for HTHP fluid loss control. Keep Iow gravity solids below 8 %. Increase mud. weight as required below 9000', keeping a supply of Barofi.b. re and Steelseal for potential seepage pr~l~lems. It is very important to have flat gels, 10 for runnin~ pipe. $~rvey Reovir~ment~ and Deviation Restrictions A. MWD Surveys: B. Deviation: Run one survey every 30' to insure well is tracking proposed wellpath. Once path is predictable, survey frequency may be increased to every 90'. Maximum 2 degrees per 100'. Samplina. Mud Loaqincl & Electric Logs Mud loggers on at 2,600'. 30' samples, washed and dried (4 sets). Electric logging program: IND/Sonic/GR; Neu/Density/GR; RFT and Sidewall Cores Possible. For additional information, see attached Geological Prognosis. C. CASING AND CEMENTING DETAILS (9 5/8" CASING) AT 11,900 TVD (14,200 MD-RKB) 1. Casing Specifications: (Top to Bottom) TVD PPCo Pw Torque Depth Description Burst Coil Ten Opt fMb Driftt 0 - 11,900 9 5/8" 53.5 lb 8920 7480 1159 to triangle 8.53 14,200' MD P- 110 BTC Note: Air weight for this casing string is 760,000 lbs. . . . , Float Shoe : Float Collar & Loc : Stage Collar : Centralizers : Connection Lock · Cementing Plugs : Circ, Mix, Displace Rate : Spacer --- : Weatherford Model 323 (PDC drillable). Weatherford Model 402 Sure Seal - 1 joint above shoe. Weatherford 5,000' TVD (5800 MD) 1-7' above shoe; next 2 collars; every second collar for 400'. Every joint from stage collar to 4400' MD Thread lock all connections on fit shoe thru top of Float Collar, stage collar. Top plug only Maximum practical 20 bbls of Diesel/20bbl of HiV"i~ FW (Flozan and barite) FV = 100. Mix at 12.5 ppg (actual mud weight). Actual volume TBA First Stage Cmt Slurry Slurry Weight : Mix Water - Type : Pumping Time : Desired TOC : Compressive Strength : Calc 215 sx Halliburton Premium + 0.20 % CFR-3 + 0.10 gal/sx Halad 344L + 0.15 % HR-5 15.8 PPG 4.85 gal/sk. Fresh 3-4 hours 13600' (use 20% excess) 24 Hours - 2140 psi. Second Stage Lead Slurry Slurry Weight : Mix Water - Type Pumping Time : Desired TOC : Compressive Strength : Calc 100 sx Halliburton Premium + 0.20 % CFR-3 + 3 % gel + 0.10%HR-5 12.5 PPG : 11.98 gal/sk. Fresh 3-4 hours 4000' (use 20% excess) 24 Hours - psi. Second Stage Tail Slurry : Slurry Weight Mix Water - Type Pumping Time Desired TOC Compressive Strength Calc 380 sx Halliburton Premium + 0.20 % CFR-3 + 0.10 gal/sx Halad 344L + 0.10 % HR-5 : 15.5 PPG : 5.21 gal/sk. Fresh : 3-4 hours : 4600' (use 20% excess) : 24 Hours - 2140 psi. NOTE: 1) 2) CEMENT DESIGN IS SUBJECT TO CHANGE IF GAS IS PRESENT All OBM will be circulated out of annulus. Flush and volumes TBA. SPECIAL INSTRUCTIONS A. Make +/- 20' of rat hole below casing setting depth to space out mandrel hanger. B. Notify the AOGCC a minimum of 24 hours prior to the casing job. C, Check MB hanger assembly on rig and stand back, on a stand of DC, in the derrick prior to running 9 5/8". Running tool is 8rd. D, It is important that Hole-is not surged while running casing. The casing running speed should be 1 minute / joint, or less. Run casing utilizing Weatherford's fillup tool. Verify all Iockdown screws in the Multi-bowl assembly are fully retracted. Hang off casing on Vetco MB-S mandrel hanger on profile in well head. Insure that hanger is properly landed by visually inspecting through the inspection plug. Circulate one annular volume prior to cementing, if losses are experienced, immediately start cementing. Cement casing. Fo G. Displace cement with OBM. Bump plug with 500 psi over the final displacing pressure. If plug is not leaking test the casing to 5000 psi for 30 rain (Interm csg test). Bleed pressure to 0 and check for backflow. Open stage tool and circulate a minimum of 4 hours while WOC. After 4 hours, begin reducing mud weight from 12 lb/gal to 10 lb/gal while circulating. Ho Displace oil based mud from annulus with same weight fresh water system prior to pumping 2nd stage. Perform 2nd stage cement job through stage tools. Use recon3~ended spacer. Displace with OBM. Check slurry density,..with pressurized mud scales throughout-t~ie job. Catch samples of slurry and dry cement periodicallY/while mixing. NOTE: CEMENT TO BE USED SHOULD BE LAB TESTED PRIOR TO SENDING SAME TO THE LOCATION. ACTUAL CEMENT TO BE USED SHOULD BE TESTED. J. Complete PPCO Casing and Cementing Report and send to the Houston Office. Section V: 8 1/2" Hole (7" Casing) to 13,262'TVD 15,800' MD-RKR A. GENERAL REMARKS 1. Intent Drill an 8 1/2" hole through the Sunfish and North Forelands Sands to 13,262' TVD (15,800' MD). Take 60' cores of Sunfish and North Forelands Sands as requested by geologists. If productive intervals are indicated, set and cement a 7" production liner. 2. Litholoo¥ and Anticioated Problems . Continuation of the sand and shale with interbedded coal seams is prognosed. There is a pressure transition that occurs slightly above the Sunfish Sands at + 12,000' TVD, _% 14,300' MD,. Pore pressures may increase from 9.8 ppg to about 13.2 ppg dur~'ng this transition. This abnormal pressure trend is expected to continue to TD. Actual mud weights could be as high as 14.5 ppg. Wellhead Proaram . Install casing hanger seal assembly and test to 5,000 psi. Wellhead is same multibowl already in place. BOPE Reauirements and Test Pressure~ 13 5/8" 5 M BOPE is required. Test pressures are continued frome previous section as follows: Initial Installation Weekly ---- Rams: 5000 psi 2500 psi - Annular: 3500 psi 2500 psi Casinc~ Pressure Test & Leak-off Test Pressure test 9 5/8" casing after drilling stage collar and tagging float collar to 5000 psi. GIH with BHA. Drill the float equipment and 10' of new formation. Perform a Formation Integrity Test as per well control manual to an EMW of 16.0 ppg. (anticipated L/O -- 17.5 -19.0 ppg EMW). Maximum anticipated mud weight in this hole section will be 15.0 ppg. Consider squeezing the shoe if the leakoff is less than 15.0 ppg EMW. Raise MW only as required. Contact Drilling Superintendent if FIT leak-off occurs before 15.5 ppg EMW. ·., 6. Special Drilling Instructions ke C. D. Install a wear bushing before drilling to prevent wear in the casing head. Drill 9 5/8" stage collar, shoe and float equipment with PDC bit and rotary assembly. Use minimum surface RPM while drilling out to keep from breaking up shoe cement job. Drill ahead with motor and hold assembly, maintaining angle and direction to the targets. To prevent differential sticking, keep pipe moving as much as possible, especially while making connections. Drilling Jars should be used in this section of the hole. Core Sunfish Sands (60' core anticipated) and North Forelands Sands as requested by geological and reservoir personnel. At TD, circulate hole clean, C&CM for logging. B. DRILLING DETAIL~ ( 8 1/2" HOLE TO 15.800 MD-RKB) 1. Bottom Hole Assembly . . (Continue Hold Assembly) 8 1/2" PDC bit, Anadrill 6 3/4" 6 stage extended length performance motor, float sub, 1-10' NMDC, string stab, MWD, 60' NMDC, 5 its. HWDP, Drlg. Jars, 25 jts. HWDP, Drill Pipe. Bits. WOB, RPM IADC Bit Code: PDC Tvoe WOB: 10 - 20 M RPM: 60 -150 Jets:. 20-20-20-20 Hvdraulic~ to be Determined As required for smooth drilling Maintain flowrate at 300 - 400 GPM. Maintain stable pump pressure.- 3600 - 4000 psi (with motor). Maintain good mud properties. Yield point should be as Iow as possible to keep the ECD as Iow as possible. 4. Mud Proa~ rarrt ( 14200- ;580 Continue program from previous section. Mud weight will need to be brought up to 13.0 - 14.0 after coring the Sunfish Sands. Non progressive gels important. THESE ARE APPROX RHEOLOGICAL VALUES, and WILL VARY DEPENDING ON OWR & TYPE OF SUSP AGENTS. 5. Survey Reouirements and Deviation Restrictiqn~ A. Continue with directional plan, using MWD surveys for directional control. 6. Samolino. Mud Loooin~, and Electric A. Mud logging to be continued fr-om 11,900' TVD to 13,300' TVD (15,800' MD). B. Fax reports every morning to (713) 669-3754 by 7:30 and follow with phone report at 8:15 a.m. Openhole logs from 11,900'- TVD to 13,300' TVD (15,800' MD): Ar. ray Induction / GR; Compensated Neutron / Litho-Density with GR and Caliper; Dipole Array / Sonic with GR and Caliper; MDT Tools, Dipmeter. Circulate and condition hole for logs. NOTE: See Attached Geological Prognosis . Corinq A. B. Conventional 60' core (s) to be taken from 12,080'-12,180' TVD. Conventional 60' core (s) to be taken from 12,632'-12,750. TVD Bits and vendors TBA. 8. Environmentel A. Do not spill any Oil Mud. Insure that no mud escapes from platform area. If any accidents occur advise Houston Office Immediately. An SPCC plan is required on rig at all times. C. CASING AND CEMENTING DETAILS ~9 5/8" CASING) AT 11,900 TVD {1.4,200 MD-RKB) 1. Casing Specifications: (Top to Bottom) TVD PPCo Pw Torque Depth Description Burst Coil Ten Opt fi-lb Drifft __ 13,900 7" 32 lb/ft 8160 8110 528 6.0 15,800' MD L-80 BT&C Speci al ,, , Float Shoe : Float Collar & Loc : Centralizers : Connection Lock : Cementing Plugs : Circ, Mix, Displace Rate : To be Determined. To be Determined. 1-7' above shoe; next 2 collars; every second collar for 400'. Every joint to intermediate shoe. Thread lock all connections on fit shoe thru top of Float Collar. Drill pipe wiper plug. Maximum practical , Spacer m : First Stage Cmt Slurry Slurry Weight : Mix Water - Type : Pumping Time : Desired TOC : Compressive Strength : 20 bbls of Diesel/20bbl of I-[iVi~ FW (Flozan and barite) FV = 100. Mix at 14.0 ppg (actual mud weight). Actual volume TBA Calc 380 sx Halliburton Premium + 0.20 % CFR-3 + 0.15 gal/sx Halad 344L + 0.25 % HR-5 15.6 PPG 5.03 gal/sk. F~esh 3-4 hours 13600' (use 20% excess) 24 Hours - 2140 psi. NOTE: 1) 2) SPECIAL INSTRUCTIONS A. B. C. D. E. CEMENT DESIGN IS SUBJECT TO CHANGE IF GAS IS PRESENT All OBM will be circulated out of annulus. Flush and volumes TEA. Make +/- 20' of rat hole below casing setting depth to space out liner hanger. Notify the AOGCC a minimum of 24 hours prior to the casing job. Check liner hanger assembly on rig. It is important that hole is not surged while running casing. Auto-Fill equipment will be used. The casing running speed should be 1 minute { joint, or less. NOTE: A special liner running procedure will be provided at the appropriate time. SOLIDS CONTROL PROGRAM F{~g Eauiomen~: Linear shakers - 3 Derrick Model 58 FID-Line Cleaners Oesander Pioneer Model T-86 with 8-6" cones Mud Cleaner Derrick with 16-4" cones Degasser Drilco See-Flow DSM Cuttines HandlinQ: Apollo Services will vacuum the drill cuttings to their catch tank. From there, the cuttings will be ground and disposed into the non-productive sands at a TVD of approximately 3300' TVD. Disposal will be down one of the two 2 3/8" tubing strings attached to The 13 3/8" surface casing. /Xdditional .Eouioment Needed: 1 ) A dedicated steam cleaner is needed at the shakers to allow for screen cleaning at any time. 2) Coarse (e.g., expanded metal) cages will be installed over the pump intakes in the pits to prevent trash from fouling the valves. 3) A dedicated pump capable of pumping liquids out of the cuttings catch tank back over the shakers will be furnished by Apollo Services. 4) Use Pyramid Plus screens as the first 2 screens on the Derricks. The Plus feature is merely taller corrugations, which allows for more separation in the deep pool section of the shakers. NOTE: Ensure all e~ipment is fully operational before drilling ahead with oil base.:fluids. Install an operational pressure gauge on the hydroclone headers, Pressure should be 4 x I~1,W~.~n psi. Upgrade feed pump impeller if ne-~essary. Be sure cones are clean and in spray discharge. Conductor and Surface Hole: Use all rig solids control equipment. Run 2_10 mesh pyramids on the Derricks. Run desander and desilter on surface hole. Intermediate Hole: The goals during the OBM sections are to produce dry cuttings (to reduce cuttings slurry volumes), and yet keep Iow gravity solids figs) less than 8 vol% with existing rig equipment. In past wells, < 8% Igs has been achieved using 210's on the Derricks, Again, the goal is to produce dry cuttings, even during upsets and startups with cold mud. During switch out to OBM, put coarse flat screens on Derricks (e.g. 80 mesh). After several circulations, start the Derricks with 140 mesh screens. Use Pyramid Plus screens on the first 2 screens, and a regular Pyramid on the last screen. Screen down to 210's in the same arrangement consistent with dry cuttings as soon as possible. · · A major goal is to produce dry cuttings. To prevent whole mud going over the shakers, it may be necessary to bypass the Derricks for the first half circulation after a trip into the hole. When the mud warms up, immediately switch back over the Derricks. Pump liquids that collect in the catch tanks back over the shakers. Lost circulation is possible at any time. It may be necessary to bypass the Derricks for a short time to allow bridging size LCM (e.g., sized calcium carbonate and Steel Seal) to build up in the mud to plug the problem zone. Return flow to the Derricks as soon as possible to prevent buildup of Igs. It is better to have to keep adding LCM than to let the Igs build up over 8 vol%. Production Hole: Continue with previous program. Lower pump rates may allow 250's on the Derricks. DRILLING FLUID PROGRAM I Depth TVD Weight PPG Visc. PH PV YP FL Mud Type 300'-2400' 8.6 - 9.0 50- 100 8.5-9.5* 10-15 20-40 10-20 Water (2600' MD) Base Use pre-hydrated bentonite and extender flocculated in inlet water. Use all solids control equipment, keeping LGS below 6 % if possible. Sweep hole as needed with 50 bbl pills made up of 25 ppb gel and 1/2 ppb caustic in fresh water. Treat system with Drispac if seepage problems occur. Maximize pump rates to provide increased annular velocity. * NOTE Have funnel viscosity 50 - 70 sec/qt while drilling through gravel and when running casing. Depth TVD Weight PPG Visc. PH PV YP FL Mud Type 2400'-4000' 8.8 - 9.2 40-50 8.5-9.5' 10-15 15-25 6-10 Water (4500' MD) Base Continue use of conductor mud system. Use fresh water for make-up mud. Continue use of all solids control equipment, sweeping hole as needed with 50 bbl pills. Continue the PAC treatments. Use Kwik- Seal and BaroFibre for any losses or excess seepage. Maximize pump rates to provide increased annular velocity. Depth TVD Weight PPG Oil/Wtr PV YP HPHT Fluid Mud Type Ratio Loss 4000'-9300 9.5-10.0 70/30 10-30 < 20-25 3-5 Oil Base (11000' MD) 75/25 Invermul 9300-11900 10.0-12.0 80/20 25-35 15-20 3 - 5 Oil-Base (14200' MD) Invermul Drill out with 9.0 ppg mud. Use soltex for HTHP fluid loss control. Keep Iow gravity solids below 8 %. Increase mud weight as required below 9000', keeping a supply of Barofibre and Steelseal for potential seepage problems. It is very important to have flat gels, 10 for running pipe. Depth TVD Weight PPG Oil/Wtr PV YP HPHT Mud Type Ratio Fluid Loss 11,900' - 13,300' 12.5 - 80/20 35-40 15-20 3-6 Oil Base (14200-15800' MD) 15.0 85/15 Invermul Continue program from previous section. Mud weight will need to be brought up to 13.0 - 14.0 after coring the Sunfish Sands. Non progressive gels important. THESE ARE APPROX RHEOLOGICAL VALUES, and WILL VARY DEPENDING ON OWR & TYPE OF SUSP AGENTS. SUCTION CENTRIFUGE PIT UUO CLEANER PIT ~0 88I. OESANOER PIT 80 BSL OEC. vISSER PIT 105 BBL POWER UNITS CENTRIFUGE PUMPS ~ID TR~ I ! ' UNOCAL RIG 428 MUD SYSTEM LAYOUT .... 255 BBL VOLUME//COMPLETION255 BBL 90 BBL VOLUME PIT SUCTION PIT , PIT . ~,~ [. ~ ' i ~l ]., PIT _ ,, .... :. PHILLIPS' TYONEK PLATFORM MUD SYSTEM LAYOUT II Phillips Petroleum Company Tyonek Platform slot ~1 Alaska Alaska PROPOSAL LISTING Well name : Tyonek Deep Prospect Your ref : Proposal Rev 0 Our ref : prop4325 Date printed : Date created : Last revised : 7-Mar-97 .6-Mar-97 7-Mar-97 Field is centred on 0.000,0.000 Structure is centred on 331995.770,2586725.700 UNCONTROLLED Phillips Petrole~." ,mpany Tyonek Platform ,Tyonek Deep Prospect Alaska,Alaska PROPOSAL LISTI~ Page 1 Your ref : Proposal Rev 0 Last revised : 7-Mar-97 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100Ft Sect 0.00 0.00 165.55 0.00 0.00 N 0.00 E 0.00 200.00 0.00 165.55 200.00 0.00 N 0.00 E 0.00 500.00 0.00 165.55 500.00 0.00 N 0.00 E 0.00 600.00 0.00 165.55 600.00 0.00 N 0.00 E 0.00 700.00 2.00 165.55 699.98 1.69 S 0.44 E 2.00 0.00 0.00 30" Casing Point 0.00 0.00 KOP Begin 2.00 deg./100' B~ 1.75 800.00 4.00 165.55 799.84 6.76 S 1.74 E 2.00 900.00 6.00 165.55 899.45 15.20 S 3.92 E . 2.00 1000.00 8.00 165.55 998.70 27.00 S 6.96 E 2.00 1100.00 10.00 165.55 1097.47 42.15 S 10.86 E 2.00 1200.00 12.00 165.55 1195.62 60.62 S 15.62 E 2.00 6.98 15.69 27.88 43.52 62.60 1300.00 14.00 165.55 1293.06 82.40 S 21.23 E 2.00 1400.00 16.00 165.55 1389.64 107.47 S 27.69 E 2.00 1500.00 18.00 165.55 1485.27 135.78 S 34.99 E 2.00 1600.00 20.00 165.55 1579.82 167.30 S 43.11 E 2.00 1700.00 22.00 165.55 1673.17 202.00 S 52.05 E 2.00 85.10 110.98 140.21 172.77 208.60 1800.00 24.00 165.55 1765.21 239.84 S 61.80 E 2.00 1900.00 26.00 165.55 1855.84 280.76 S 72.35 E 2.00 2000.00 28.00 165.55 1944.94 324.72 S 83.68 E 2.00 2100.00 30.00 165.55 2032.39 371.67 S 95.78 E 2.00 2200.00 32.00 165.55 2118.11 421.54 S 108.63 E 2.00 247.67 289.93 335.33 383.81 435.31 2300.00 34.00 165.55 2201.97 474.28 S 122.22 E 2.00 2361.92 35.24 165.55 2252.92 508.34 S 130.99 E 2.00 2500.00 35.24 165.55 2365.70 585.49 S 150.88 E 0.00 2598.31 35.24 165.55 2446.00 640.42 S 165.03 E 0.00 3000.00 35.24 165.55 2774.08 864.85 S 222.87 E 0.00 489.77 524.95 Begin 35.24 deg. Tangent S~ 604.62 661.34 20" Casing Point 893.11 3500.00 35.24 165.55 '3182.46 1144.22 S 294.86 E 0.00 4000.00 35.24 165.55 3590.84 1423.58 S 366.84 E 0.00 ~500.00 35.24 165.55 3999.22 1702.94 S 438.83 E 0.00 4500.95 35.24 165.55 4000.00 1703.47 S 438.97 E 0.00 5000.00 35.24 165.55 4407.60 1982.31 S 510.82 E 0.00 1181.60 1470.09 1758.58 1759.13 13 3/8" Casing Point 2047.06 5500.00 35.24 165.55 4815.98 2261.67 S 582.81 E 0.00 6000.00 35.24 165.55 5224.36 2541.03 S 654.80 E 0.00 6500.00 35.24 165.55 5632.74 2820.39 S 726.79 E 0.00 7000.00 35.24 '165.55 6041'.12 3099.76 S 798.78 E 0.00 7500.00 35.24 165.55 6449.50 3379.12 S 870.77 E 0.00 2335.55 2624.04 2912.53 3201.02 3489.51 8000.00 35.24 165.55 6857.88 3658.48 S 942.76 E 0.00 8500.00 35.24 165.55 7266.26 3937.85 S 1014.75 E 0.00 9000.00 35.24 165.55 7674.64 4217.21 S 1086.74 E 0.00 9500.00 35.24 165.55 8083.02 4496.57 S 1158.73 E 0.00 10000.00 35.24 165.55 8491.40 4775.93 S 1230.72 E 0.00 3778.00 4066.49 4354.98 4643.47 4931.96 10500.00 35.24 165.55 8899.78 5055.30 S 1302'.71 E 0.00 11000.00 35.24 165.55 9308.16 5334.66 S 1374.70 E 0.00 11500.00 35.24 165.55 9716..54 5614.02 S 1446.69 E 0.00 12000.00 35.24 165.55 10124.92 5893.39 S 1518.68 E 0.00 12500.00 35.24 165.55 10533.29 6172.75 S 1590.67 E 0.00 5220.45 5508.94 5797.43 6085.92 6374.41 13000.00 35.24 165.55 10941.67 6452.11 S 1662.66 E 0.00 13500.00 35.24 165.55. 11350.05 6731.48 S 1734.65 E 0.00 14000.00 35.24 165.55 11758.43 7010.84 S 1806.63 E 0.00 14173.33 35.24 165.55 11900.00 7107.68 S 1831.59 E 0.00 14396.16 35.24 165.55 12082.00 7232.18 S 1863.67 E 0.00 6662.90 6951.38 7239.87 7339.88 9 5/8" Casing Point 7468.45 Sunfish Sands 14500.00 35.24 16.5.55 12166.81 7290.20 S 1878.62 E 0.00 15000.00 35.24 165.55 12575.19 7569.56 S 1950.61 E 0.00 15500.00 35.24 165.55 12983.57 7848.93 S 2022.60 E 0.00 15742.95 35.24 165.55 13182.00 7984.67 S 2057.58 E 0.00 15865.38 35.24 165.55 13282.00 8053.07 S 2075.21 E 0.00 7528.36 7816.85 8105.34 8245.52 North Foreland Sands 8316.16 PBHL/TD All data is in feet unless otherwise stated Coordinates are from slot 91 and TVDs are from RKB. Vertical section is from wellhead on azimuth 165.55 degrees. Calculation uses the minimum curvature method. UNCONTROLLED Phillips Petrole~ mDany Tyonek Platform ,Tyonek D~eD Prospect Alaska,Alaska Measured Inc. Azi. True Vert. Depth Degs Degs Depth RECTANGULAR COORDINATES 0.00 0.00 165.55 200.00 0.00 165.55 500.00 0.00 165.55 600.00 0.00 165.55 700.00 2.00 165.55 0.00 0.00n 0.00e 200.00 0.00n 0.00e 500.00 0.00n 0.00e 600.00 0.00n 0.00e 699.98 1.69s 0.44e 800.00 4.00 165.55 799.84 900.00 6.00 165.55 899.45 1000.00 8.00 165.55 998.70 1100.00 10.00 165.55 1097.47 1200.00 12.00 165.55 1195.62 6.76s 15.20s 27.00s 42.15s 60.62s 1300.00 14.00 165.55 1293.06 1400.00 16.00 165.55 1389.64 1500.00 18.00 165.55 1485.27 1600.00 20.00 165.55 1579.82 1700.00 22.00 165.55 1673.17 82.40s 107.47s 135.78s 167.30s 202.00s 1800.00 24.00 165.55 1765.21 1900.00 26.00 165.55 1855.84 2000.00 28.00 165.55 1944.94 2100.00 30.00 165.55 2032.39 2200.00 32.00 165.55 2118.11 239.84s 280.76s 324.72s 371.67s 421.54s 2300.00 34.00 165.55 2201.97 2361.92 35.24 165.55 2252.92 2500.00 35.24 165.55 2365.70 2598.31 35.24 165.55 2446.00 3000.00 35.24 165.55 2774.08 474.28s 508.34s 585.49s 640.42s 864.85s 3500.00 35.24 165.55 3182.46 1144.22s 4000.00 35.24 165.55 3590.84 1423.58s 500.00 35.24 165.55 3999.22 1702.94s ~00.95 35.24 165.55 4000.00 1703.47s 5000.00 35.24 165.55 4407.60 1982.31s 5500.00 35.24 165.55 4815.98 2261.67s 6000.00 35.24 165.55 5224.36 2541.03s 6500.00 35.24 165.55 5632.74 2820.39s 7000.00 35.24 165.55 6041.12 3099.76s 7500 00 35.24 165.55 6449.50 3379.12s PROPOSAL LISTIN(. Page 1 Your ref : Proposal Rev 0 Last revised : 7-Mar-97 1.74e 3.92e 6.96e 10.86e 15.62e 21.23e 27.69e 34.99e 43.11e 52.05e 61.80e 72.35e 83.68e 95.78e 108.63e 122.22e 130.99e 150.88e 165.03e 222.87e GRID COORDINATES GEOGRAPHIC Easting Northing COORDINATES 331995.77 2586725.70 N61 4 36~34 W150 56 55.61 331995.77 2586725.70 N61 4 36.34 W150 56 55.61 331995.77 2586725.70 N61 4 36.34 W150 56 55.61 331995.77 2586725.70 N61 4 36.34 W150 56 55.61 331996.21 2586724.01 N61 4 36.32 W150 56 55.60 331997.51 2586718.94 N61 4 36.27 W150 56 55.57 331999.69 2586710.50 N61 4 36.19 W150 56 55.52 332002.73 2586698.70 N61 4 36.07 W150 56 55.46 332006.63 2586683.55 N61 4 35.92 W150 56 55.37 332011.39 2586665.08 N61 4 35.74 W150 56 55.27 332017.00 2586643.30 N61 4 35.53 W150 56 55.15 332023.46 2586618.23 N61 4 35.28 W150 56 55.01 332030.76 2586589.92 N61 4 35.00 W150 56 54.85 332038.88 2586558.40 N61 4 34.69 W150 56 54.68 332047.82 2586523.70 N61 4 34.35 W150 56 54.49 332057.57 2586485.86 N61 4 33.98 W150 56 54.28 332068.12 2586444.94 N61 4 33.58 W150 56 54.05 332079.45 2586400.98 N61 4 33.15 W150 56 53.81 332091.55 2586354.03 N61 4 32.69 W150 56 53.55 332104.40 2586304.16 N61 4 32.20 W150 56 53.27 332117.99 2586251.42 N61 4 31.68 W150 56 52.98 332126.76 2586217.36 N61 4 31.35 W150 56 52.79 332146.65 2586140.21 N61 4 30.59 W150 56 52.37 332160.80 2586085.28 N61 4 30.05 W150 56 52.06 332218.64 2585860.85 N61 4 27.85 W150 56 50.82 8000 00 35.24 165.55 6857.88 3658.48s 942.76e 8500.00 35.24 165.55 7266.26 3937.85s 1014.75e 9000 00 35.24 165.55 7674.64 4217.21s 1086.74e 9500.00 35.24 165.55 8083.02 4496.57s 1158.73e 10000 00 35.24 165.55 8491.40 4775.93s 1230.72e 10500 00 35.24 165.55 8899.78 5055.30s 1302.71e 11000.00 35.24 165.55 9308.16 5334.66s 1374.70e 11500 00 35.24 165.55 9716.54 5614.02s 1446.69e 12000.00 35.24 165.55 10124.92 5893.39s 1518.68e 12500.00 35.24 165.55 10533.29 6172.75s. 1590.67e 13000.00 35.24 165.55 10941.67 6452.11s 1662.66e 13500.00 35.24 165.55 11350.05 6731.48s 1734.65e 14000.00 35.24 165.55 11758.43 7010.84s 1806.63e 14173.33 35.24 165.55 11900.00 7107.68s 1831.59e 14396.16 35.24 165.55 12082.00 7232.18s 1863.67e 14500.00 35.24 165.55 12166.81 7290.20s 1878.62e 15000.00 35.24 165.55 12575.19 7569.56s 1950.61e 15500.00 35.24 165.55 12983.57 7848.93s 2022.60e 15742.95 35.24 165.55 13182.00 7984.67s 2057.58e 15865.38 35.24 165.55 13282.00 8053.07s 2075.21e 294.86e' 332290.62 2585581.49 N61 4 25.11 W150 56 49.28 366.84e 332362.61 2585302.12 N61 4 22.37 W150 56 47.73 438.83e 332434.60 2585022.76 N61 4 19.63 W150 56 46.19 438.97e 332434.74 2585022.23 N61 4 19.63 W150 56 46.18 510.82e 332506.59 2584743.40 N61 4 16.89 W150 56 44.64 582.81e 332578.58 2584464.04 N61 4 14.15 W150 56 43.09 654.80e 332650.57 2584184.67 N61 4 11.41 W150 56 41.55 726.79e 332722.56 2583905.31 N61 4 08.67 W150 56 40.01 798.78e 332794.55 2583625.95 N61 4 05.93 W150 56 38.46 870.77e 332866.54 2583346.59 N61 4 03.19 W150 56 36.92 332938.53 2583067.22 N61 4 00.45 W150 56 '35.37 333010.52 2582787.86 N61 3 57.71 W150 56 33.83 333082.51 2582508.50 N61 3 54.97 W150 56 32.28 333154.50 2582229.14 N61 3 52.22 W150 56 30.74 333226.49 2581949.77 N61 3 49.48 W150 56 29.19 333298.48 2581670.41 N61 3 46.74 W150 56 27.65 333370.47 2581391.05 N61 3 44.00 W150 56 26.10 333442.45 2581111.69 N61 3 41.26 W150 56 24.56 333514.44 2580832.32 N61 3' 38.52 W150 56 23.02 333586.43 2580552.96 N61 3 35.78 W150 56 21.47 333658.42 2580273.60 N61 3 33.04 W150 56 19.93 333730.41 2579994.24 N61 3 30.30 W150 56 18.38 333802.40 2579714.87 N61 3 27.56 W150 56 16.84 333827.36 2579618.03 N61 3 26.61 W150 56 16.30 333859.44 2579493.53 N61 3 25.39 W150 56 15.62 333874.39 2579435.51 N61 3 24.82 W150 56 15.30 333946.38 2579156.15 N61 3 22.08 W150 56 13.75 334018.37 2578876.79 N61 3 19.34 W150 56 12.21 334053.35 2578741.05 N61 3 18.01 W150 56 11.46 334070.98 2578672.64 N61 3 17.33 W150 56 11.08 feet unless otherwise statedUNCONTROLLEE All data is in Coordinates are from slot %1 and TVDs are from RKO. Vertical section is from wellhead on azimuth 165.55 degrees. Grid coordinates are in FOOT on grid: "Alaska State Plane, Zone 4" Calculation uses the minimum curvature method. Phillips Petrole,U~{ mpany Tyonek Platform ,Tyonek ~ap Prospect Alaska,Alaska PROPOSAL LISTIN( Page 2 Your ref : Pruposal Rev 0 Last revised : 7-Mar-97 MD TVD Rectangular Coords. Comments in wellpath Comment 200.00 200.00 0.00 N 0.00 E 30' Casing Point 600 00 600.00 0.00 N 0.00 E KOP Begin 2.00 deg./100' Build 2361 92 2252.92 508.34 S 130.99 E Begin 35.24 deg. Tangent Section 2598 31 2446.00 640.42 S 165.03 E 20" Casing Point 4500 95 4000.00 1703.47 S 438.97 E 13 3/8" Casing Point 14173 33 11900.00 7107.68 S 1831.59 E 9 5/8" Casing Point 14396 16 12082.00 7232.18 S 1863.67 E Sunfish Sands 15742 95 13182.00 7984.67 S 2057.58 E North Foreland Sands 15865 38 13282.00 8053.07 S 2075.21 E PBHL/TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD 0.00 0.00 0.00N 0.00 0.00 0.00N 0.00 0.00 0.00N 0.00 0.00 0.00N 0.00E 200.00 200.00 0.00E 14173.33 11900.00 0.00E 4500.95 4000.00 0.00E 2598.31 2446.00 Rectangular Coords. Casing 0.00N ~0.00E 30" Casing Point 7107.68S 1831.59E. 9 5/8' Casing Point 1703.47S 438.97E 13 3/8' Casing Point 640.42S 165.03E 20" Casing Point Target name Targets associated with this wellpath Position T.V.D. Local rectangular coords. Date revised Sunfish Sands 333859.440,2579493.530 12082.00 7232.18S 1863.67E 6-Mar-97 UNCONTROLLED Ail data is in feet unless otherwise stated Coordinates are from slot %1 and TVDs are from RKB. Vertical section is from wellhead on azimuth 165.55 degrees. Calculation uses the minimum curvature method. FEB-19-199? 08:19 PPCO DRILLING SERVICES 713 669 3793 PHILLIPS PETROLEUM COMPANY Box 1967 Houston, Texas 77251-1967 North America Production Phillips Building 6330 West Loop South Bellaire, Texas 77401-2901 Fax No. (713) 659-3703 Drilling Sewices TELECOPY COVER SHEET From: RoomlF...xt: . .. 713 669.,, ~ 5 2_..-q ....... Number of Pages ~ __. lnoluding Cover Sheet P. 01/0:~ MESSAGE FOR INTERNAL USE ONLY Transmitted By: 19 1997 Alaska Oil & Gas Cons. Commission' Anchorage .. FEB-19-199? 08:19 PPCO DRILLING SERVICES 71~ 669 ~79~ February 15, 1997 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission Dear Mr. Wondzell, Phillips Petroleum Company is requesting approval of the injection of oil base cuttings in the proposed North Cook Inlet #B-1 well. The injection zone is in the Sterling formation and is at a depth of approximately 3350' TVD. Because this zone is not a hydrocarbon producing zone, there has not been a water sample analyzed at this depth. For this reason, an E-log has been used to estimate chloride content. An offset well off of the Tyonek platform Is the ~A-IO. This well produces from 3700' TVD to 4000' TVD. This well produces from the shallowest zones and produces the most water. This well's most recent water sample test was on October 6, 1996 (Figure 1 ), !._ chili;ideS (actual 'sample) .... -chi'oHde'~"'{~iculated from Io9) · TDS (actual sample) I TDS (calc,,u,!ated for Injection zone) 2800 '6229.776 5933.12 'A simple ratio calculation was used and is shown below. TD8 actual Chlorides actual ,,TDS cal~!ated.for in!ection zon.~ Chlorides calculated from log over injection zone 6229.7'76 oorrl 2940 ppm TDS calculated for iniectionzone 2800 ppm TDS calculated for injection zone = 5933.12 ppm This calr.'ulated TDS content is over the required 3000 ppm. If there are any questions, please contact 8honna Boyer at (713) 669-7980. P.02/02 "1 Regards, NPOIsmb cc: J.W. Konst ~ S.M. Boyer N. P. Omsberg Drilling Engineering Manager Phil'lips Petroleum Company 1997 Alasl~ Oil & Gas Cons. Commission Anchorage TOTRL P, 02 FEB-17-199? 08:33 PPCO DRILLING SERVICES I' ..... C._T&E En__vironm___~_l servi_O_e_s Inc. 713 669 3793 P.02 965422001 Phillips Petrolemn Tyonek Plat~nn T~onck Pla~on ~u. A-I ~ ' Client PO~ Paid by VISA Print~ Date/'llme 11125/~6 17:05 ColL__-?t~l_ DatWTune 10/06/96 00:00 Received Date/lime 10/08/96 14:30 Technical Director:. Stephen C. Ede Released Sy_~._.~ ltl II Par~eter Sodium Catciun garl~n $trontiu. Nag~sf~ Sutfide Atkmtfn~Cy m~ Biotite AlkaLinity chloride Sutfate ResuLts PQL Units 1670 2.50 mg/L 142 I.O0,WL 3.31 0.100m/L 90,6 22,5 mg/L 1.62 0.150~/L 0,~$2 0.100 mg/L 71.2 1.OOm/L O,SO0 U 0.500~J/L O.?1& 0.2S0 ~/L 0.100 0,0~00 ~/L ~2' 1.00~L ~2 1.00 mg/L 2~0 20,0 mg/L 5.2 0,200~/L #ethod EPA Z00.7 EPA 200.? EPA 200.? EPA EPA ~00.? EPA 200.? EPA 200.7 ~A 200.7 EP~ EPA 376.2 ~ ~ZOB SM EPA ~00.0 EPA ~00,0 Attoeabte Prep Anatysis . Limits Da~e Date Init 11119/96 m 11/19/96 11/19/9& 11/19/96 11/19/96 Iq4M 11/'19~ 11/19/~ E~ 11119/96 10/ZS/96 10/~1/96 ~P IOI10/96 10/10/96 ~E RECEIVED FEB 18 1997 Alaska Oi! & ~as Cons. ~L~Jt)~ TOTAL P. 02 FEB-l?-199? 08:32 · PHILLIPS PETROLEUM COMPANY Box 1~7 Houston, Texas 77251-1967 North America Produ,;'tion PPCO DRILLING SERUICES Drilling Services ., 713 S69 ~793 P.01 Phillips Building 8330 West Loop South Bellalre, Texas 77401-2901 Fax No. (713) 669-3793 TELECOPY COVER SHEET · elecopy Number: ((::~.,~)D~ -- ~4 ~ Number of Pages, Including Cover Sheet MESSAGE · ,__ ,,,..,~.... _/~'~, 0 ~" ~ ill ii ii i, .... FOR INTERNAL UEE ONLY · Transmitted By: · RECEIVED FEB 18 I9~7 Naska Oil & G~ Con~. Commi~iofl An~h'orag'~ FEB-14-1997 11: 35 PHI LL I PS PETROLEUM ,.. " ( 'Z~d~ ~T~ ~ Envir °-n m-ent-~-f- S-e- -r~ic-e' ! n-c-' CT&E R~f.# Cliem Name Pro, eot Nan--# Client Sample ID Ordered S~ 96.6422001 Phillips Petroleum Tyon~k Platform Tyo~.k t~tronn WaUn' (Surface, Eft., CiJem PO// Paid by ~sA Printed Date/Time 11/25196 17:05 Collected Dnt~Time 10106196 00:00 Received Dine/Time 10/08/96 14::30 Tedmir~ Dir~___or: Stephen C. Ede COtcjl~ Barium Potas$i~n Stront{LIn ltangar~se .it~ Su~fSde Atkatin~y es 8icae~ate At~t Surf ate ResuLts 1670 142 3.31 90.6 1.62 0.5~2 71.2 O.SO0 U 0.714 O. 100 29~0 PQL Units ._ 2.50 M/f. t.00 mn/L 2~.5 m~/L 0.150 n~/L 0,100 ~/L 1.00 nO/L O.SO0 fllg/L 0.250 mg/L 0.0500 I~I/L 1.00 n~/L t.00 mg/L ZO.O ng/L 0,200 mg/L Attouubte Prep AnaLysis . Method Limits Date Date Init -- ~j_ mmimmmIp~m~ .... ,m~.iI~mmm~ ~ EPA RO0.7 11/19/9~ EPA 200.? 11/19/96 EPA 200.7 11/19/96 EPA 200.7 11/19/96 ~A ~,T 11/19/96 EPA 200,7 11/19~6 EPA 2~.7 11/19/96 EPA 200.7 11/19/96 ~A 200.7 11/19~6 EPA 376.2 10/23/96 EPA ~00.0 ~0/10/~ EPA 300.0 10/10/9~ RECEIVED FEB 14 1997 A~ask. a Oil & Gas Cons. Commissio~ Aflchorsge TOTI~_ p. 02 PHILLIPS PETROLEUM PHILLIPS PETROLEUM COMPANY Box 1967 Houston, Texas 77251-1967 North America Produclion Drilling Services Phillips Building 6330 West Loop South Bellaire, Texas 77401-2g01 Fax No. (713) 669-3793 Pi TErECOPY COVER SHEET Numar of Pages ~ Includi~ Co~r Sheet FOR INTERNAL USE ONLY Transmitted By::._ _.. _ RECEIVED F£8 141997 ' Oil & (~aS COilS. Commission ~horag8 PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY February 5, 1997 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING RECEIVED Dear Mr. Wondzell, This letter is an application for injection of oil base cuttings. Phillips Petroleum Company requests approval to inject cuttings in the proposed North Cook Inlet Unit #B-I. The location of this well is the PPCo. operated Tyonek Platform in the North Cook Inlet. The use of oil base mud below 3586' TVD (4000' MD) is required to reduce hole problems and pipe sticking which was prevalent in previous wells. The proposed method of cuttings disposal is to grind and re-inject them through the two proposed 2 318" tubing strings strapped to the 13 318" casing string and cemented (Figure 1). The desired injection zone is in the Sterling formation. It is a 50' thick sand occurring at approximately 3350' TVD. This zone is confined by a 50' shale above and a 40' shale below. This same zone is seen in all offset wells. A log section from the A-11 well is attached to demonstrate the injection zone (Figure 2). The shallowest producing Cook Inlet sand in the A-11 is at 4657' MD. This log is representative of the depths at which the injection zone occurs in the other offset wells. When viewing the log, it is apparent there is no risk of the drilling waste affecting the producing zones. The mud log contains the lithologic description as follows. The shale is described as a firm, sticky clay. The sand is described as unconsolidated, medium coarse grains, subrounded and subangular. Dipole sonic logs are currently being evaluated to determine rock strength in the confining zones. The injection zone water has not been sampled for the total dissolved solids content. Electric logs were Used in conjunction with two independent methods to calculate the sodium chloride content (Figure 3). The calculations resulted in 2800 ppm NaCI content. Adding the other constituents brings the TDS level above the required 3000 ppm. Water samples taken from producing sands a few hundred feet below are more than the 3000 ppm requirement. dried and ground. The cuttings will weigh about 17 ppg and will be diluted to 14 ppg using sea water, for injection purposes. There will be 3-4 bbls of water per bbl of cuffings. One barrel of cuttings contains about 30% volume mud and 70% volume shale or sand. One barrel of mud contains about 60% volume diesel, 20% volume CaCI2 water, 15% volume barite and 5% volume drill solids (fine shale and sand). The source of diesel will be local fuel sources' in the Inlet. Number 4 diesel is a possibility. We are also evaluating the use of Iow toxicity mineral oil. All wells within a 114 mile radius are operated by Phillips Petroleum Company. There are 14 wells in this area. The wells include the A#1 through the A~13 and the Sunfish #3. There is a spider diagram, showing all of the wells (Figure 5). Because all of the wells are close together, the casing collapse rating for the offset wells was taken into consideration because injection will occur outside of the casing strings. After reviewing the ratings, there is no chance of collapsing the offset casing strings with the expected injection pressure. The tubing that will be used as the injection string will be 2 318" tubing with a collapse rating of 8100 psi and a burst rating of 7700 psi. Normally, the maximum anticipated injection pressure can be estimated as 0.5 psi/ff. At a depth of 3350', the maximum injection pressure is 1675 psi. An average injection pressure will be about 1000 psi. This estimate was compared to a leak-off test from an offset well at the same depth. That leak-off test broke down the formation at 700 psi using 8.7 ppg mud at a depth of 3500' (12.5 ppg EMW). It is intended to run tracer surveys from time to time to ensure the injected fluids are not moving up and down the hole to unacceptable levels. On site downhole injection is an environmentally sound method of disposing of drilling wastes. If this method proves viable, we may use it for drilling future development wells in the area. If any other information is required in order to make a decision, please contact Shonna Boyer at (713) 669-7980. Regards, N. P. Omsberg Drilling Engineering Manager Phillips Petroleum Company NPO/smb cc: J. W. Konst ® S. M. Boyer · W.L. Carrico J. A. Landrum ® J. D. Admire RECEIVED FEB Alaska Oil & Gaa Ce~a, Gommi~sioJ't Ancho~aoe FEB-II-199? 1~:43 · . PPCO DR ILL I NG SERU ICES , PHILLIPS PETROLEUM COMPANY Box 1967 Houston, Texas 77251-1967 North Afnerica Production Drilling Sendces 713 669 3?93 P.01 Phillips Building 6330 West Loop South Bellalre, Texas 77401-2901 Fax No. (713) 669-3793 TEILECOPY COVER SHEET · o: From: S~On~~0 ~r Company: ./~2) ~. C-C ........... Room/Ext:.. 713 669- _~ _. Number of Pages ~ Including Cover Sheet MESSAGE FOR INTERNAL USE ONLY Transmitted By: RECEIVED FEB 11 1997 Naska 0il & (las Cons. Commission Anchorage FEB-ii-199? 13:43 PPCO DRILLING SERVICES 713 669 3?93 P.02 The estir~ated total volume of cuttings to be injected is 7472 bbls. This estimate is based on using water base mud until 4000' (Figure 4). The cuttings will be dried and ground. The cuttings will weigh about 17 ppg and will be diluted to 14 ppg using sea water, for injection purposes. There will be 3-4 bbls of water per bbl of c~ttiflgs. One barrel of cuttings contains about 30% volume mud and 70% volume shale or sand. One barrel of mud contains about 60% volume diesel, 20% volume CaCl2 water, 15% volume barite and 5% volume drill solids (fine shale and sand). The source of diesel, will be local fuel sources in the Inlet. Number 4 diesel is a possibility. We are also evaluating the use of Iow toxicity mineral oil. All wells within a 114 mile radius are operated by Phillips Petroleum Company. There are 14 wells in this area. The wells include the .A~I through the A#13 and the Sunfish #3. There is a spider diagram showing all of the wails (Figure, 5). Because all of the wells are close together, the casing collapse rating for the offset wells was taken into consideration because injection will occur outside of the easing strings. After reviewing the ratings, there is no chance of collapsing the offset casing strings with the expected injection pressure, The tubing that will. be used as the injection string will be 2 318' tubing with a collapse rating of 81130 psi and a burst rating of 7700 psi. Normally, the maximum anticipated injection pressure can be estimated as 0.5 psi/fi. At a depth of 3350', the maximum injection pressure is 1675 psi. An average injection pressure will be about 1000 psi. This estimate was compared to a leak-off test from an offset well at the same depth. That leak-off test broke down the formation at 700 psi using 8.7 ppg mud at a depth of 3500' (12.5 ppg EMW). It is intended to run tracer surveys from time to time to ensure the injected fluids are not moving up and down the hol,e to unacceptable levels. On site downhole injection is an environmentally sound method of disposing of drilling wastes. If this method proves viable, we may use it for drilling future development walls i'n the area. If any.other information is required in order to make a decision, please contact Sh0nna Boyer at (713)669-7980. Regards, NPOismb cc: J. W. Konst ® $. M, Boyer W.L. Carrico J. A. Landrum ® J. D. Admire N. P. Omsberg 1~ ~ ¢6 ~ ~'5,1'o Drilling Engineering Manager Phillips Petroleum Company RECEIVED FEB 11 1997 Alaska 0il & Gas Cons. (;or.m~ss~ Anchorage TOTAL P, O2 N.C.I.U. #B-1 Proposed Wellbore Schematic Figure 1. Injection zone 3350' TVD (371~ MD) Cook Inlet Sands 3700' TVD (4140' MD) Beluga Sands 4500' TVD (512Z MD) Tyonek 'C' sand 11025' TVD (13138' MD) Sunfish sands 1202(7 TVD (14397 MD) North Forelands sands 12650' TVD (15134' MD) .... :.~ ~ · ,: :;..<. ,~:=: ,.. ~ ....,.~ ...~-~. I' · .... ,.~ ....., ..... .~r.~ : · .~.1 F~J:: . .-...~. i~'.. ~ ,,.... ::..j.' ~.: ..'...~ :.::: ...... ~.. ... .'-i ... · :~:: ..... ..... i.%:: :..%. ::: -.. :j.: :-'..', 2 3/8" tbg ~ 3375' TVD (3740' MD) !TOC ~ (3800' MD) 3424' TVD ~ 13 3/8" csg e 3586' TVD (4000' MD) TOC ~ 7168' TVD (8400' MD) TOL 7" ~} 7412' TVD (8700' MD) 9 5/8" csg ~ 7657' TVD (9(X)O' MD) RECEIVED FEB 11 Alasl~ 0il & Gas Cons. Commission Anchorag.~ TOC ~ 11238' TVD (13400' MD) TOL 5" ~ 11483' TVD (1370(~ MD) 7" liner ~) 1172~ TVD (1400(~ MD) 5 1/2" liner ~ 13192' 'I'VD (15800' MD) 2-5-97 ,p 1 . . CUTTINGS RE-INJECTION REQUIREMENTS SUMMARY The requirements for injecting oil base cuttings have been reviewed. The requirements as shown in the Alaska Oil & Gas Conservation Commission Administrative Code are outlined below. . The injection zone must have more than 3000 ppm total dissolved solids. The proposed well's injection zone is at a depth of +/- 3350' TVD. Because this zone is not a hydrocarbon producing zone, them has not been a water sample taken at this depth. The A-10 well is a nearby offset. The A-10 produces from the shallowest zone at 3700' - 4000' TVD. This well also produces the most water. The A-10's most recent water sample test was October 6, 1996 (Figure Chlorides (actual sample) Chlorides (calculated from log) TDS (actual sample) TDS (calculated for injection zone) 2940 ppm 2800 ppm 6230 ppm 5933 ppm A simple ratio calculation was used and is shown below. TDS actual Chlorides actual = TDS calculated for injection zone Chlorides calculated from log 623_0_ppm = TDS calculated for injection zonP 2940 ppm 2800 ppm The calculated TDS content of 5933 ppm for the injection zone is over the required 3000 ppm. Designation of the well to receive drilling waste. The proposed N.C.I.U. B-1 well will be receiving the drilling waste. Depth to the base of freshwater. As shown previously, at a depth of 370.0' TVD in the offset A-10 well, the water is not fresh. The base of freshwater is shallower than this, but is not defined. Depth and thickness of the receiving and confining zone and information to demonstrate confinement. The proposed injection zone is the upper sand of a pair of sandstones that are found between 3460' MD and 3485' MD on the Sunfish #3 well log (Figure 2). The sands are 50'- 60' thick and are continuous across the field (Figure 2). The . . . sands are separated by a 10' layer of clay and are confined below by a laterally continuous zone of interbedded clay, siltstone, volcanic ash and coal that averages 170' thick. The injection sand is overlain by a bed of clay and thin coals found at 3400' MD - 3460' MD on the Sunfish 3 well log (Figure 2). This confining bed is continuous and averages 30'- 50' thick (Figure 2). An additional confining bed lies above this at 3255' MD - 3360' MD and is separated from the first bed by a discontinuous sandstone. The upper confining bed is composed of clay, siltstone and thin coals and is laterally continuous (Figure 2). Schlumberger is performing an analysis of the strength and mechanical properties of the confining units based on the dipole sonic log from Sunfish 3 to confirm confining properties. List of all wells within 114 mile. All of the wells in this vicinity are Phillips operated wells on the Tyonek Platform. The wells include the A-1 through A-13 and Sunfish #3. Estimate of maximum volume and density of waste slurry. The estimated total volume of waste slurry is 9547 bbls. The density of the slurry will beiil0.5- 11.5 ppg. Description of waste. One barrel of cuttings will be diluted with 3-4 barrels of seawater. One barrel of cuttings contains about 30% volume mud and 70% volume shale or sand. One barrel of mud contains about 60% volume diesel, 20% volume CaCl2 water, 15% volume barite and 5% volume drill solids (fine shale and sand). The source of diesel will be local fuel sources in the Inlet. Number 4 diesel is prognosed. Estimate of maximum pressure at the outer casing shoe and calculation showing how that value was determined. The maximum pressure at the 13-3/8" outer casing shoe is 2284 psi. This was determined from a leak-off test in the Sunfish #3 well at a depth of 3500'. The formation broke down at 700 psi with a mud weight of 8.7 ppg. Maximum pressure = 0.052*(8.7 ppg)*(3500') + 700 psi = 2284 psi Details to show that the shoe of the outer casing is set below the base of any freshwater and cemented to provide zone isolation. The surface casing will be set at a depth of 3700' TVD which has 5933 ppm TDS which is not considered fresh water. This casing will be cemented to surface. 10. Details that show that the inner and outer casing strings have sufficient strength. The waste slurry will be injected through the 2-3/8" injection string run in tandem with the 13-3/8" casing string. The affected string is the 2-3/8" injection string. The burst rating for this is 7700 psi. The maximum pressure exerted on this will be 3850 psi. smb OOZ~ OC;;':. 000~ 006; 009; OOZ; 009; .. 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'% . 1~0 I I I I I I s , , . , . , , , . , I 1380 0H 900 910 930 930 ~40 9~0 ~60 970 900 990 1000 1010 10'20 1030 1040 105.0 11)~0 1070 10e0 1090 1100 1110 1120 1110 1140 1150 1160 1170 1100 Scale I Inch = 10 fl East (feet) -> WELL PERMIT , FIELD & POOL INIT'C'r.A'~S _/~_~, ~J~_~? ~ ' ' ADMI N I STRATION ~TE ) ENGINEERING DATE 1 2 3. ~--/ PROGRAM: exp~dev [] redrlQ serv[] wellbore seg[] ann disp para req~ G~.o,. ~A ~. ~ u,I~# //%/~C~ o,/o~ SHO~~ - . Permit fee attached .................. .Lease number a99ropria,e ............... Unique well name and number .............. Well loca,ed proper d,s,ance from drlg un't 'ou~da'y. · .Y ~' ' If devia=ed, is wellbore 91a~ included ........ Opera[or has appropriate bond in force ......... Permi~ can be issued wtthou= conservation order ..... Y ~ -- ' ' ~ /' -" .... ~ ........ ~' -- Perm,[ can be issued w~thou~ admtnistra=ive approval.. Can 9ermi[ be approved before 15-day wa~= ........ Y 4. 5. 6. 7. 8. g. 10. 11. 12. 13. Conductor string provided ............... Surface casing protects all known USDWs ........ CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . · Y 14. 15. 16. 17. 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to psig. 27. Choke manifold complies w/AP! RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures...~ N 31. Data presented on potential overpressure zones .... i~ N 32. Seismic analysis of shallow gas zones .......... N 33. Seabed condition survey (if off-shore) . /~/-~ .... ~Y N 34. Contact name/phone for weekly progress reports .... ~ N [explorator~ only] GEOLOGY: ENGINEERING: COMMISSION: ...... i JDH _ ~ mcm..~__.~9~ CORMS%cheklist rev 01197 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To imp'rove the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS Tape Verification Listing ~chlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: **** REEL HEADER **** SERVICE NAMIE : EDIT DATE : 97/11/ 5 ORIGIN : FLIC REEL NAHE : 97437 CONTINUATION # : PREVIOUS RR~.L : COMMENT : PHILLIPS PETROLEUM, NORTH COOK INLET UNIT B NO. 1, 50-883-20093-0 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/11/ 5 ORIGIN : FLIC TAPE NAME : 97437 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT : PHILLIPS PETROLEUM, NORTH COOK INLET UNIT B NO. 1, 50-883-20093-0 **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01AiO DATE : 97/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ******************************************************************************* ******************************************************************************* ** ** ** SCHLUMBERGER WELL SERVICES ** ** ******************************************************************************* ******************************************************************************* COMPANY NAME: Phillips Petroleum Corp. WELL: NORTH COOK INLET UNIT "B" No. 1 FIELD': NORTH COOK INLET BOROUGH: KENAI STATE: ALASKA API NUMBER: 50-883-20093-00 LOCATION: 1250' FNL & 980' FWL SECTION: 6 TOWNSHIP: liN RANGE: 9W PERMANENT DATUM: MSL ELEVATION: O' LOG MEASURED FROM KB 132' ABOVE PERMAN~ DATUM LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: ELEVATIONS KB: 132' DF: 131' ******* RUN NUM~BR: 1 ******* DATE LOGGED: 3-SEP-97 TDDRILLBR: 10380' CASING : 13.375" ~ DRILLER DEPTH OF 3760' AND LOGGER DEPTH OF 3762' BIT SIZE 1: 12.25" TYPE FLUID IN HOLE: WATER BASED MUD DENSITY: 11.2 VISCOSITY: 55 PH: 9.4 FLUID LOSS: 4.4 MUD RESISTIVITY: 1.93 @ 66 DEGF FILTRATE RESISTIVITY: 1.23 ~ 66 DEGF MUD CAKE RESISTIVITY: 4.6 ~ 66 DEGF TIME CIRCULATION ENDED: 20:00 2-SEP-97 TiME LOGGER ON BOTTOM: 10:30 3-SEP-97 MAXIMUM T~P RECORDED: 154 DEGF ******* RUN NUM~ER: 2 ******* DATE LOGGED: 8-0CT-97 TDDRILLER: 15500' CASING 2: 9.625" ~ DRILLER DEPTH OF 10376' AND LOGGER DEPTH OF 10375' BIT SIZE 2: 8.5" TYPE FLUID IN HOLE: iNVERMUL OBM DENSITY: 14.6 VISCOSITY: 61 FLUID LOSS: 4.4 TIME CIRCULATION ENDED: 10:30 8-0CT-97 TIME LOGGER ON BOTTOM: 03:44 9-0CT-97 MAXIMUM T~PRECORDED: 196 DEGF LOGGING DISTRICT: Kenai LOGGING ENGINEER: Rachel Walsh WITNESS: Mark Kingsley DATE JOB STARTED: 30-0CT-97 AKICS JOB REFERENCE NO: 97437 COMPUTING CENTER REMARKS: ******************************************************************** THE LDT/CNT/GAMMA RAY ARE THE ONLY TOOLS CO~ON TO BOTH RUNS 1 AND 2. THE GAMMA RAY CURVE ACQUIRED ALONG WITH THE LDT/CNT FROM BOTH RUNS WAS MERGED AT 9600' TO PROVIDE A CONTINUOUS GAMMA RAY CURVE. PRIOR TO MERGING THE GAMMA RAY FROM RUN #2 WAS SHIFTED TO BE ON DEPTH AT THE MERGE POINT OF 9600'. ALL OTHER TOOLS FROM RUN #2 WERE CARRIED ALONG WITH THIS SHIFT. .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1997 PAGE: THE DT COMPRESSIONAL (DTCO), AND DT SHEAR (DTSM) WERE RELABELED BY SCHLUMBERGF~ GEOQUEST OFFICE IN ANCHORAGE ALASKA. THE DATA CONTAINED IN THE FIRST FILE OF THIS TAPE IS THE MERGE OF RUNS 1 AND 2. THE CURVES HAVE BEEN TRIF~ED OF INVALID DATA PRIOR TO FIRST TOOL READING AND LAST TOOL READING. THE NEUTRON POROSITY (NPHI) WAS RECOMPUTED USING A SANDSTONE MATRIX SO THE NPHI FROM RUN #1 AND THE NPHI FROM RUN #2 WOULD BE ABLE TO BE MERGED. FILE - EDIT. 001 "RUNS 1 & 2 MAIN LOGS" DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - EXTENSION USED TOOL NAME .AIT . DTE .LDT . CNT . DSI .MLL ARRAY INDUCTION (RUN #2 ONLY) PHASOR INDUCTION (RUN #1 ONLY) LITHO DENSITY TOOL (RUNS 1 AND 2) COMPENSATED NEUTRON (RUNS 1 AND 2) DIPOLE SONIC IMAGER (RUN 2 ONLY) MICRO LOG (RUN 1 ONLY) ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 300 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing 'Schlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: TYPE REPR CODE VALUE 11 66 3 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1088392 O0 000 O0 0 1 1 1 4 68 0000000000 AO10 AIT 0~4~1088392 00 000 00 0 1 1 1 4 68 0000000000 A020 AIT 0~1088392 O0 000 O0 0 1 1 1 4 68 0000000000 A030 AIT 0I~4~I1088392 00 000 00 0 1 1 1 4 68 0000000000 A060 AIT 0~11088392 00 000 00 0 1 1 1 4 68 0000000000 A090 AIT 0I-1b~41088392 00 000 00 0 i 1 1 4 68 0000000000 AT10 AIT 0I'~4~1088392 00 000 00 0 1 1 1 4 68 0000000000 AT20 AIT 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 AT30 AIT 0~1088392 00 000 O0 0 1 1 1 4 68 0000000000 AT60 AIT 0I-Ib~1088392 00 000 00 0 1 1 1 4 68 0000000000 AT90 AIT 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 AFl0 AIT 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 AF20 AIT 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 AF30 AIT 0HF~I1088392 00 000 00 0 1 1 1 4 68 0000000000 AF60 AIT 0I'~4~1088392 00 000 00 0 1 1 1 4 68 0000000000 AF90 AIT 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 CIDP DTE ~0 1088392 00 000 00 0 1 1 1 4 68 0000000000 IDPH DTE 0~4~1088392 00 000 O0 0 1 1 1 4 68 0000000000 CIMP DTE ~4~0 1088392 00 000 00 0 1 1 1 4 68 0000000000 IMPH DTE 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 CILDDTE I~4~0 1088392 00 000 00 0 1 1 1 4 68 0000000000 ILD DTE 0}~4~1088392 00 000 00 0 1 1 1 4 68 0000000000 CILMDTE ~4}I0 1088392 00 000 O0 0 1 1 1 4 68 0000000000 ILM DTE 0~4~1088392 00 000 00 0 1 1 1 4 68 0000000000 IFRE DTE HZ 1088392 00 000 00 0 1 1 1 4 68 0000000000 IDQF DTE 1088392 00 000 00 0 1 1 I 4 68 0000000000 IMQF DTE 1088392 00 000 00 0 1 1 1 4 68 0000000000 IIRDDTE Fl~l~O 1088392 00 000 00 0 1 1 1 4 68 0000000000 IIXDDTE F~4~O 1088392 00 000 00 0 1 1 i 4 68 0000000000 IiRMDTE 1~4~0 1088392 00 000 00 0 1 1 1 4 68 0000000000 IIX~DTE l~-IO 1088392 00 000 00 0 1 1 1 4 68 0000000000 SFLU DTE 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 SP DTE MV 1088392 00 000 00 0 1 1 1 4 68 0000000000 BMINI~LL 014F~I1088392 00 000 00 0 1 1 1 4 68 0000000000 BFINO~L 0~1088392 00 000 00 0 1 1 1 4 68 0000000000 DTCO DSI US~Fl088392 00 000 00 0 1 1 1 4 68 0000000000 DTSM DSI US~F1088392 00 000 O0 0 1 1 1 4 68 0000000000 PR DSI 1088392 00 000 00 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing ~chlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: 5 NAME SERV UNIT SERVICE API API API API FILE NUMB NUb~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) RSHC DSI 1088392 00 000 O0 0 1 1 1 4 GR DSI GAPI 1088392 O0 000 00 0 1 1 1 4 TENS DSI LB 1088392 O0 000 O0 0 1 1 1 4 HTENDSI LB 1088392 00 000 O0 0 1 1 1 4 FIRES DSI 0~4~1088392 00 000 00 0 1 1 1 4 MT~DSI DEGF 1088392 00 000 00 0 1 1 1 4 RTNR CNT 1088392 O0 000 O0 0 1 1 1 4 RCNT CNT CPS 1088392 00 000 00 0 1 1 1 4 RCFT CNT CPS 1088392 00 000 00 0 1 1 1 4 CNTCCNT CPS 1088392 00 000 00 0 1 1 1 4 CFTC CNT CPS 1088392 00 000 00 0 1 1 1 4 TNRA CNT 1088392 00 000 00 0 1 1 1 4 NPHI CNT PU 1088392 00 000 00 0 1 1 1 4 GR LDT GAPI 1088392 00 000 00 0 1 1 1 4 RHOBLDT G/C3 1088392 O0 000 00 0 1 1 1 4 TENS LDT LB 1088392 00 000 00 0 1 1 I 4 HTENLDT LB 1088392 00 000 00 0 1 1 i 4 ~RESLDT 0~v1~1088392 00 000 00 0 1 1 1 4 MTEMLDT DEGF 1088392 00 000 00 0 1 1 1 4 DRHOLDT G/C3 1088392 00 000 00 0 1 1 1 4 LSRHLDT G/C3 1088392 00 000 00 0 1 1 I 4 LURHLDT G/C3 1088392 O0 000 00 0 1 1 1 4 PBF LDT 1088392 00 000 00 0 1 1 1 4 QLS LDT 1088392 00 000 00 0 1 1 1 4 QSS LDT 1088392 00 000 00 0 I 1 1 4 RHOB LDT G/C3 1088392 00 000 00 0 1 1 1 4 DPHI LDT PU 1088392 00 000 00 0 1 1 1 4 S1RHLDT G/C3 1088392 O0 000 00 0 1 1 1 4 LSHVLDT V 1088392 00 000 00 0 1 1 1 4 SSHVLDT V 1088392 00 000 00 0 1 1 1 4 LL LDT CPS 1088392 00 000 00 0 1 1 1 4 LU LDT CPS 1088392 00 000 00 0 1 1 1 4 LS LDT CPS 1088392 00 000 00 0 1 1 1 4 LITHLDT CPS 1088392 00 000 00 0 1 1 1 4 SSi LDT CPS 1088392 O0 000 00 0 I 1 1 4 SS2 LDT CPS 1088392 00 000 00 0 1 1 1 4 CALI LDT IN 1088392 O0 000 00 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 15501.000 AOIO.AIT -999.250 AO20.AIT -999.250 AO30.AIT AO60.AIT -999.250 Aogo.AIT -999.250 ATiO.AIT -999.250 AT20.AIT AT30.AIT -999.250 AT60.AIT -999.250 AT90.AIT -999.250 AF10.AIT AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 AF90.AIT CIDP.DTE -999.250 IDPH.DTE -999.250 CIMP.DTE -999.250 IMPH.DTE CILD.DTE -999.250 ILD.DTE -999.250 CILM.DTB -999.250 ILM. DTE IFRE. DTE -999.250 IDQF. DTE -999.250 IMQF.DTE -999.250 IIRD.DTE IIXD.DTE -999.250 IIRM. DTE -999.250 IIX~.DTB -999.250 SFLU. DTE SP.DTE -999.250 BMIN. MLL -999.250 BFINO.MLL -999.250 DTCO.DSI -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 LIS Tape Verification Listing ~chlumberger Alaska Computing Center ( 5-NOV-1997 14:15 PAGE: DTSM. DSI -999.250 PR.DSI TENS.DSI -999.250 HTEN. DSI RTNR.CNT -999.250 RCNT. CNT CFTC. CNT -999.250 TNRA. CNT RHOB.LDT -999.250 TENS.LDT MT~.LDT -999.250 DRHO.LDT PEF. LDT -999.250 QLS.LDT DPHI.LDT -999.250 S1RH. LDT LL.LDT -999.250 LU. LDT SS1.LDT -999.250 SS2.LDT DEPT. 3627.000 AO10.AIT AO60.AIT -999.250 AO90.AIT AT30.AIT -999.250 AT60.AIT AF20.AIT -999.250 AF30.AIT CIDP.DTE -999.250 IDPH. DTE CILD. DTE -999. 250 ILD. DTE IFRE.DTE -999.250 IDQF. DTE IIXD.DTE -999.250 IIRM. DTE SP.DTE -999.250 BMIN. MLL DTSM. DSI -999.250 PR.DSI TENS.DSi -999.250 HTEN. DSI RTNR.CNT 4.296 RCNT. CNT CFTC. CNT 514.525 TNRA. CNT RHOB.LDT -999.250 TENS.LDT MT~.LDT -999.250 DRHO. LDT PEF.LDT -999.250 QLS.LDT DPHI.LDT -999.250 S1RH. LDT LL.LDT -999.250 LU. LDT SS1.LDT -999.250 SS2.LDT -999.250 RSHC.DSI -999.250 I~ES.DSI -999.250 RCFT. CNT -999.250 NPHI.CNT -999.250 HTEN. LDT -999.250 LSRH. LDT -999.250 QSS.LDT -999.250 LSHV. LDT -999.250 LS.LDT -999.250 CALI.LDT -999.250 AO20.AIT -999.250 AT10.AIT -999.250 AT90.AIT -999.250 AF60.AIT -999.250 CIMP.DTE -999.250 CILM. DTE -999.250 IMQF.DTE -999.250 IIX~.DTE -999.250 RMNO.MLL -999.250 RSHC.DSI -999.250 MRES.DSI 1859.786 RCFT. CNT 3.879 NPHI.CNT -999.250 HTEN. LDT -999.250 LSRH. LDT -999.250 QSS.LDT -999.250 LSHV. LDT -999.250 LS.LDT -999.250 CALI.LDT -999.250 GR.DSI -999.250 MT~.DSI -999.250 CNTC. CNT -999.250 GR.LDT -999.250 MRES.LDT -999.250 LURH. LDT -999.250 RHOB.LDT -999.250 SSHV. LDT -999.250 LITH. LDT -999.250 -999.250 AO30.AIT -999.250 AT20.AIT - 999. 250 AFl 0. AIT -999.250 AFgO.AIT -999.250 IMPH.DTE -999.250 ILM. DTE -999.250 IIRD.DTE -999.250 SFLU.DTE -999.250 DTCO.DSI -999.250 GR.DSI -999.250 MT~.DSI 456.538 CNTC. CNT 46.092 GR.LDT -999.250 FIRES.LDT -999.250 LURH.LDT -999.250 RHOB.LDT -999.250 SSHV. LDT -999.250 LITH. LDT -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1832.119 27.781 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01AiO DATE : 97/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FiLE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A10 DATE : 97/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing S~hlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: FILE - EDIT. 002 PHILLIPS PETROLEUM CORP. NORTH COOK INLET NORTH COOK INLET UNIT "B" NO. 1 50-883-20093-00 "RUN #1 REPEAT DATA" DATA SAMPLED EVERY -.5000 FEBT DATA INCLUDED - EXTENSION TOOL USED NAME .DTE PHASOR DUAL INDUCTION SFL .LDT LITHO DENSITY TOOL .CNT COMPENSATED NEUTRON .MLL MICRO LOG ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 196 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 5 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: 8 ** SBT TYPE - CHAN ** NAME SBRV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 1088392 00 000 00 0 2 1 1 4 68 0000000000 CIDP DTB ~0 1088392 00 000 00 0 2 1 1 4 68 0000000000 IDPH DTE 0~4~1088392 00 000 O0 0 2 1 1 4 68 0000000000 CIMP DTE ~4~0 1088392 00 000 00 0 2 1 1 4 68 0000000000 IMPH DTE 0~4~ 1088392 00 000 00 0 2 1 1 4 68 0000000000 CILDDTE ~4~0 1088392 O0 000 O0 0 2 1 1 4 68 0000000000 ILD DTE 0}~4~I088392 00 000 00 0 2 1 1 4 68 0000000000 CILMDTB ~24~0 1088392 O0 000 00 0 2 1 1 4 68 0000000000 ILM DTE 0~1088392 O0 000 O0 0 2 1 1 4 68 0000000000 IFRE DTB HZ 1088392 00 000 O0 0 2 1 1 4 68 0000000000 IDQFDTE 1088392 O0 000 O0 0 2 1 1 4 68 0000000000 IMQF DTE 1088392 00 000 O0 0 2 1 1 4 68 0000000000 IIRDDTE F~4~O 1088392 00 000 O0 0 2 1 1 4 68 0000000000 IIXDDTE ~4~0 1088392 00 000 O0 0 2 1 1 4 68 0000000000 IIRMDTE ~4~0 1088392 00 000 00 0 2 1 1 4 68 0000000000 II3~4DTE F~4~O 1088392 00 000 00 0 2 1 1 4 68 0000000000 SFLU DTE 0~4~1088392 00 000 00 0 2 1 1 4 68 0000000000 SP DTB MV 1088392 O0 000 O0 0 2 1 1 4 68 0000000000 GR DTE GAPI 1088392 00 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 1088392 00 000 O0 0 2 1 1 4 68 0000000000 MTE~DTE DEGF 1088392 O0 000 O0 0 2 1 1 4 68 0000000000 ~RES DTE 0H~1088392 O0 000 00 0 2 1 1 4 68 0000000000 HTENDTB LB 1088392 O0 000 00 0 2 1 1 4 68 0000000000 RHOB LDT G/C3 1088392 00 000 00 0 2 1 1 4 68 0000000000 DPJ{OLDT G/C3 1088392 00 000 00 0 2 1 1 4 68 0000000000 PEF LDT 1088392 00 000 00 0 2 1 1 4 68 0000000000 QLS LDT 1088392 00 000 00 0 2 1 1 4 68 0000000000 QSS LDT 1088392 00 000 00 0 '2 1 1 4 68 0000000000 LS LDT CPS 1088392 00 000 O0 0 2 I 1 4 68 0000000000 LU LDT CPS 1088392 00 000 00 0 2 1 1 4 68 0000000000 LL LDT CPS 1088392 00 000 O0 0 2 1 1 4 68 0000000000 LITHLDT CPS 1088392 00 000 00 0 2 1 1 4 68 0000000000 SSi LDT CPS 1088392 00 000 00 0 2 1 I 4 68 0000000000 SS2 LDT CPS 1088392 00 000 00 0 2 1 1 4 68 0000000000 LSHVLDT V 1088392 00 000 00 0 2 1 1 4 68 0000000000 SSHVLDT V 1088392 O0 000 00 0 2 1 1 4 68 0000000000 S1RHLDT G/C3 1088392 00 000 00 0 2 1 1 4 68 0000000000 LSRHLDT G/C3 1088392 O0 000 O0 0 2 1 1 4 68 0000000000 LURHLDT G/C3 1088392 00 000 O0 0 2 1 1 4 68 0000000000 CALI LDT IN 1088392 O0 000 00 0 2 1 1 4 68 0000000000 NPHI CNT PU 1088392 00 000 O0 0 2 1 I 4 68 0000000000 RTNR CNT 1088392 00 000 00 0 2 1 1 4 68 0000000000 TNRA CNT 1088392 00 000 O0 0 2 1 1 4 68 0000000000 RCNTCNT CPS 1088392 00 000 O0 0 2 1 1 4 68 0000000000 RCFT CNT CPS 1088392 00 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 1088392 00 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 1088392 00 000 O0 0 2 1 1 4 68 0~00000000 BMINMLL 0HF~41088392 O0 000 00 0 2 1 1 4 68 0000000000 BI, NO MLL 0~1088392 00 000 00 0 2 1 1 4 68 0000000000 .. LIS Tape Verification Listing S'chlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: ** DATA ** DEPT. 9743.500 CIDP.DTB 83.938 IDPH. DTE 11.906 CIMP.DTE IMPH.DTE 4 . 906 CILD.DTE 86.188 ILD.DTE 11 . 594 CILM. DTE ILM. DTE 4 . 855 IFRE.DTE 20. 000 IDQF. DTE 3 . 000 IMQF. DTE IIRD.DTE 77. 063 IIXD.DTE 13 . 453 IIRM. DTE 193 . 500 IIX~.DTE SFLU. DTB 10. 422 SP.DTE 245.250 GR.DTE 69. 875 TENS.DTE MT~.DTE 151. 475 FIRES.DTE O. 793 HTEN. DTE 2818. 000 RHOB. LDT DRHO.LDT 0.004 PEF. LDT 5.984 QLS.LDT -0.037 QSS.LDT LS. LDT 740 . 500 LU. LDT 696. 500 LL. LDT 392 . 250 LITH. LDT SS1.LDT 250.500 SS2.LDT 390.250 LSHV. LDT 1481.000 SSHV. LDT S1R]~. LDT 1 . 917 LSPJ~. LDT 1 . 933 LURH. LDT 1 . 937 CALI. LDT NPHI. Chh 30 . 667 RTNR. CNT 3 . 304 TNRA. CNT 3 . 064 RCNT. Chh RCFT. Chh 850 . 932 CNTC. Chh 2894 . 436 CFTC. Chh 954 . 176 BMIN. MLL BF~NO.MLL 0. 974 DEPT. 9253 . 500 CIDP.DTE 204. 000 IDPH. DTE 4. 898 CIMP.DTE IMPH.DTE 4 . 367 CILD.DTE 204 . 250 ILD.DTE 4 . 891 CILM. DTE IL~.DTE 4 . 375 IFRE.DTE 20 . 000 IDQF. DTE 0 . 000 I~IQF. DTE IIRD.DTE 175. 375 IIXD.DTE 18.141 IIRM. DTE 214. 375 IIX~I. DTE SFLU. DTE 5.395 SP. DTE 249.375 GR.DTE 52.219 TENS.DTE MT~.DTE 151 . 025 I~I~ES.DTE 0. 765 HTEN. DTE 2564 . 000 RHOB.LDT DRHO.LDT 0. 069 PEF. LDT 4. 906 QLS.LDT -0. 028 QSS.LDT LS.LDT 323. 000 LU. LDT 305. 250 LL. LDT 170 . 375 LITH. LDT SSi .LDT 246.125 SS2.LDT 337. 750 LSHV. LDT 1481. 000 SSHV. LDT S1RH. LDT 2 . 229 LSRH. LDT 2 . 383 LUP. H . LDT 2.387 CALI. LDT NPHI. Chh '31.982 RTNR.Chh 3.375 TNRA.Chh 3.149 RCNT. CNT RCFT. Chh 680. 212 CNTC. CNT 2562. 656 CFTC. CNT 810. 032 BMIN. MLL B~NO . MLL 2. 848 203.625 205.875 2.000 5.172 6625.000 1.942 0.004 i86.000 1435.000 14.516 2857.529 0.887 228. 750 228.375 0.000 9. 203 6010. 000 2. 463 O. 028 71. 250 1435. 000 14.406 2546. 081 2. 043 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A10 DATE : 97/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing ~chlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: 10 **** FILE HEADBR FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001A10 DATE MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ****************************************************************************** FILE - EDIT. 003 PHILLIPS PETROLEUM CORP. NORTH COOK INLET NORTH COOK INLET UNIT "B" NO. 1 50-883-20093-00 "RUN #2 REPEAT DATA" DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - EXTENSION TOOL USED NAME .AIT ARRAY INDUCTION .LDT LITHO DENSITY TOOL * .CNT COMPENSATED NBUTRON * .DSI DIPOLE SONIC IMAGER ****************************************************************************** ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 220 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: 11 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API APi FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) DEPT FT 1088392 O0 000 O0 0 3 1 1 4 68 0000000000 TENS AIT LB 1088392 00 000 O0 0 3 1 1 4 68 0000000000 HTENAIT LB 1088392 00 000 00 0 3 1 1 4 68 0000000000 FI~ES AIT 0~1088392 00 000 00 0 3 1 1 4 68 0000000000 MTE~IAIT DEGF 1088392 O0 000 00 0 3 1 1 4 68 0000000000 GR DSI GAPI 1088392 00 000 00 0 3 1 1 4 68 0000000000 PR DSI 1088392 00 000 00 0 3 1 1 4 68 0000000000 RSHC DSI 1088392 00 000 00 0 3 1 1 4 68 0000000000 DTSM DSI US/F 1088392 O0 000 00 0 3 1 1 4 68 0000000000 DTCO DSI US~F1088392 00 000 00 0 3 1 1 4 68 0000000000 AO10 AIT 014F~I1088392 O0 000 00 0 3 1 1 4 68 0000000000 A020 AIT 0~4~1088392 O0 000 00 0 3 1 1 4 68 0000000000 A030 AIT 0~4~1088392 O0 000 00 0 3 1 1 4 68 0000000000 A060 AIT 0~4~1088392 O0 000 O0 0 3 1 1 4 68 0000000000 A090 AIT 0~v~1088392 O0 000 00 ~ 0 3 1 1 4 68 0000000000 ATiO AIT 01~4~1088392 O0 000 O0 0 3 1 1 4 68 0000000000 AT20 AIT 0H~1088392 00 000 00 0 3 1 1 4 68 0000000000 AT30 AIT 014F1~1088392 00 000 00 0 3 1 1 4 68 0000000000 AT60 AIT 0H~41088392 00 000 00 0 3 1 1 4 68 0000000000 AT90 AIT 0~4~1088392 O0 000 O0 0 3 1 1 4 68 0000000000 AFiO AIT 0~4~1088392 O0 000 00 0 3 1 1 4 68 0000000000 AF20 AIT 0H~I088392 O0 000 00 0 3 I I 4 68 0000000000 AF30 AIT 0~4~1088392 O0 000 O0 0 3 i 1 4 68 0000000000 AF60 AIT 01~4~1088392 00 000 00 0 3 1 1 4 68 0000000000 AF90 AIT 0I-1~4~1088392 O0 000 O0 0 3 1 1 4 68 0000000000 TENS LDT LB 1088392 00 000 00 0 3 1 1 4 68 0000000000 HTENLDT LB 1088392 O0 000 00 0 3 1 1 4 68 0000000000 FI~ESLDT OH~f1088392 00 000 00 0 3 1 1 4 68 0000000000 MT~LDT DEGF 1088392 O0 000 00 0 3 1 1 4 68 0000000000 GR LDT GAPI 1088392 00 000 00 0 3 1 1 4 68 0000000000 DRHOLDT G/C3 1088392 00 000 00 0 3 1 1 4 68 0000000000 LSRHLDT G/C3 1088392 00 000 00 0 3 1 1 4 68 0000000000 LURHLDT G/C3 1088392 00 000 O0 0 3 1 1 4 68 0000000000 PEF LDT 1088392 00 000 00 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing ~chlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: 12 NAHE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) QLS LDT 1088392 O0 000 O0 0 3 1 1 4 68 0000000000 QSS LDT 1088392 O0 000 O0 0 3 1 1 4 68 0000000000 RHOBLDT G/C3 1088392 00 000 00 0 3 1 1 4 68 0000000000 DPHILDT PU 1088392 00 000 00 0 3 1 1 4 68 0000000000 S1RHLDT G/C3 1088392 00 000 00 0 3 1 1 4 68 0000000000 LS~IVLDT V 1088392 O0 000 00 0 3 1 1 4 68 0000000000 SSHVLDT V 1088392 O0 000 O0 0 3 1 1 4 68 0000000000 LL LDT CPS 1088392 O0 000 O0 0 3 1 1 4 68 0000000000 LU LDT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 LS LDT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 LITHLDT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 SSi LDT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 SS2 LDT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 CALI LDT IN 1088392 O0 000 00 0 3 1 1 4 68 0000000000 RTNR C_NT 1088392 O0 000 O0 0 3 I 1 4 68 0000000000 RCNTCNT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 RCFT CNT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 CNTC CNT CPS 1088392 O0 000 00 0 3 1 1 4 68 0000000000 TNRA CNT 1088392 00 000 00 0 3 1 1 4 68 0000000000 CFTC CNT CPS 1088392 00 000 00 0 3 1 1 4 68 0000000000 NPHI CNT PU 1088392 00 000 00 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 15252.000 TENS.AIT 7525.000 HTEN. AIT 1385.444 FIRES.AIT MTEM. AIT 193.881 GR.DSI 52.941 PR.DSI 0.292 RSHC.DSI DTSM. DSI 140. 713 DTCO.DSI 76.227 AO10.AIT 8. 406 AO20.AIT AO30.AIT 5. 830 AO60.AIT 5. 766 AO90.AIT 5. 965 ATIO.AIT AT20.AIT 5. 695 AT30 .AIT 5. 974 AT60.AIT 5. 644 ATgO.AIT AFiO.AIT 8.403 AF20.AIT 5.695 AF30.AIT 6.143 AF60.AIT AF90.AIT 6.410 TENS.LDT -999.250 HTEN. LDT -999.250 MRES.LDT MT~.LDT -999.250 GR.LDT -999.250 DRttO.LDT -999.250 LSRH.LDT LURH.~T -999.250 PEF. LDT -999.250 QLS.LDT -999.250 QSS.LDT RtfOB.LDT -999.250 DPHI.LDT -999.250 S1Rtt. LDT -999.250 LSHV. LDT SSHV. LDT -999.250 LL.LDT -999.250 LU. LDT -999.250 LS.LDT LITH. LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 CALI.LDT RTITR.CNT -999.250 RCNT. CNT -999.250 RCFT. CNT -999.250 CNTC. CNT TNRA. CNT -999.250 CFTC. CNT -999.250 NPHI. CNT -999.250 DEPT. 14892.000 TENS.AIT 7215.000 HTEN. AIT MT~.AIT 192.705 GR.DSI 56.925 PR.DSI DTSM. DSI 123.057 DTCO.DSI 71.312 AOIO.AIT AO30.AIT 7.498 AO60.AIT 7.225 Aogo.AIT AT20.AIT 7.431 AT30.AIT 8.018 AT60.AIT AF10.AIT 7.642 AF20.AIT 7.795 AF30.AIT AF90.AIT 8.438 TENS.LDT -999.250 HTEN. LDT MT~.LDT -999.250 GR.LDT -999.250 DRttO.LDT LURH. LDT -999.250 PEF. LDT -999.250 QLS. LDT RHOB.LDT -999.250 DPHI.LDT -999.250 S1RH. LDT 1362.901 MRES.AIT 0.254 RSHC. DSI 7.320 AO20.AIT 7.723 ATIO.AIT 7.078 ATgO.AIT 8.567 AF60.AIT -999.250 I4RES.LDT -999.250 LSP. H. LDT -999.250 QSS. LDT -999.250 LSHV. LDT 32.918 1.846 5.695 8.403 6.525 5.789 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 31.855 1.741 7.516 7.158 8.129 7.715 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing ~chlumberger Alaska Computing Center 5-NOV-1997 14:15 PAGE: 13 SSHV. LDT -999 . 250 LL. LDT LITH. LDT -999 . 250 SSI . LDT RTNR. CNT -999. 250 RCNT. CNT TNRA. CNT -999. 250 CFTC. CNT -999.250 LU. LDT -999.250 SS2.LDT -999.250 RCFT. CNT -999.250 NPHI.CNT -999.250 -999.250 -999.250 -999.250 LS. LDT CALI . LDT CNTC. CNT - 999. 250 - 999. 250 - 999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01A10 DATE : 97/11/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/11/ 5 ORIGIN : FLIC TAPE NAME : 97437 CONTINUATION # : 1 PREVIOUS TAPE : CO~2~NT : PHILLIPS PETROLEUM, NORTH COOK INLET UNIT B NO. 1, 50-883-20093-0 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/11/ 5 ORIGIN : FLIC REEL NAME : 97437 CONTINUATION # : PREVIOUS REEL : COF~4ENT : PHILLIPS PETROLEUM, NORTH COOK INLET UNIT B NO. 1, 50-883-20093-0