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Home My WebLink About198-208 • if-, a Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC J U L 3 0 2 9tt 0 1':i 3800 Centerpo i nt Drive Suite 100 AOAUC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Sapp AUG 292016. Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Q Anchorage, AK 99501 ( 61 ' •{'� 81 r--1 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD# 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig •I New I API_WeilNo I PermitNumber WellName I WellNumber WeIlNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E 09~30~03 Schlumberger NO. 2981 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm At'tn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. 5-16B ~ qq -- [ ~ LDL 09/10/03 E-21A SBHP SURVEY 09116103 NK-29 I'~'i ~ ' [ ~- ~ PROD PROFILE W/DEFT 09109103 D.S. 3-29 '/~ ~ ~q PROD PROFILE W/DEFT 09/~9/03 D.S. 15-18 [ ~ ~O('~ SBHP SURVEY 09/~9/03 U-08A ~q~- ~~ SBHP SURVEY 09120103 W-24., I ~ ~~: / LDL 09~23~03 D.S. 9-06 ~ ~ I~-~ ~ PROD PROFILE W/DEFT 09~20~03 D.S. 2-089 ~ ~'~ 23375 CH EDIT MCNL 05/31/03 W-23A~~-~ (~ 23373 MD VISION RESlSTIVI~ 04~30~03 W-23A ~ ~3373 ~D VISION RESlSTIVI~ 04130103 ~'23A / 23373 MD BOREHOLE PROFILE 04~30~03 MPS-0~ ~,_/~ ~0624537 CH EDIT SCMT GR (PDC) 08~09~03 MPS-02 ~~ / '( 23435 SCMT 08~09~03 MPS-~8~ ~,~ 10559235 CH EDIT SCMT GR (PDC) 03~03~03 MPS48/~ ~ ~ 10559235 SCMT 03103103 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND R,- ~ [JRNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth STATE OF ALASKA {'~' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plug back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 198-208 302-352 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21946-04 4. Location of well at surface 9. Unit or Lease Name 2755' NSL, 799' WEL, SEC. 08, T11N, R17E, UM X - 270243, Y = 5970974 Duck Island Unit/Endicott At top of productive interval 3329' NSL, 1454' WEL, SEC. 05, T11N, R17E, UM X = 269750, Y = 5976845 At total depth 10. Well Number 3325' NSL, 1485' WEL, SEC. 05, T11N, R17E, UM X = 269719, Y = 5976842 3-17D/M-31 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Endicott Field / Endicott Pool KBE = 56' ADL 047502 I I I if °ffsh°re 116' No' °f C°mpletions 12. Date9/25/98Spudded 13. Date10/1T'D'0/98Reached 14. Date Comp.,1/1/2003Susp" or Aband. 15. Water depth, 6' - 12' MSLI Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 13010 10146 FTI 12878 10018 FTI [] Yes [] NoI Nipple 1522' MDI 1465' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, CDL/CNL/DLL/MLL/GR, GR/CCL ~, CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE ToP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 142' Driven 13-3/8" 68# NT80CYHE Surface 2498' 17-1/2" ¢185 c.f. Permafrost 9-5/8" 47# NT80S Surface 10500' 12-1/4" 575 c.f. Class 'G' 7"X 4-1/2" 12.6# L-80 10312' 10500' 6" ~18 c.f. Class 'G' 2-7/8" 6.4# L-80 10304' 13010' 3-3/4" 127 c.f. Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25' TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None N/A MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12850' P&A with 25 Bbls Class 'G' 10176' Set EZSV Plug 10176' Set KO Plug with 34 Bbls of Class 'G' /..r , 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED O~L'BBL GAS'MCF WATER-BBL O~L GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CoRE DATA Brief description of lithology, porosity,0 fractures,., apparent dips and presence of oil,-~gas or water. Subrl-~~r,,~,,,~IVE,.,r" No core samples were taken. ";~? :~~.i',~;'--. ~ '~;':~~!'~' '"' ':"' '': : , APR 2003 .-- .. ::' I AY O 5 2003 ~,.,,!:,.~~~. Alaska 0il & Gas Cons. Commission ..... Anchorage Form 10-407 Rev. 07-01-80 ORiBiNAL Submit In Duplicate 29. 30. Geologic Markers : Formation Tests Marker Name ' Measured TrUe Vertical Include intewal tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. SBA1 12865' 10006' K2B 12874' 10014' 2800SB 12889' 10029' 2700F 12892' 10032' RECEIVED Alaska Oil & Gas Cons. Commission 31. List of Attachments: Summary of Daily Drilling Reports and a Pre-Rig Summary Report. I~ 32. I hereby certify that the foregoing is trUe and correct to the best of my knowledge ' 3-17D/M-31 :: 198-208 302-352 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Walter Quay, 564-4178 INSTRUCTION8 GEgERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection; salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing fool. ITEM 27: Method of Operation: Flowing, Gas Lift, ROd Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. SCANNED M~Y 0 5 20~ Form 10-407 Rev. 07-01-80 Well: 3-17E/K-30 Accept: 02-23-03 Field: Endicott Field / Endicott Pool Spud: 03-04-03 APl: 50-029-21946-05 Release: 03-18-03 Permit: 202-247 Rig: Do¥on 15 Date PRE-RIG WORK 10/26/02 PULLED OGLV @ STA. #1 & GLV @ STA. #6. WAS UNSUCCESSFUL IN PULLING VALVE @ STA #4. SET DGLV @ STA #1. 10/27/02 PUMPED I BBL NEAT MEOH, 45 BBS DIESEL DOWN IA, FOLLOWED BY BBLS SEAWATER. PRESSURED UP TO 3000 PSI. MIT IA. PUMPED 1BBL NEAT MEOH DOWN CA, PRESSURED UP TO 1000 PSI, MIT CA. BOTH IA AND CA PASSED MIT JUST FINE. PULLED GLV FROM STA. #4. SET DGLV'S IN STA. #4 & STA. #6. PULLED C-SUB. 11/11/02 DRIFT TBG & TAG LINER TOP W/3.625 BARBELL 13'- 2" LONG @ 10,266' WLMD DRIFT LINER W/2.25 CENT & SAMPLE BAILER TO 12,839' WLMD 12/30/02 MIRU CTU # 5. STAND BY FOR WEATHER. 12/31/02 END WEATHER STAND BY. BEGIN R/U. BEGIN R/U. ATTEMPT TO BULLHEAD KILL. UNABLE TO KILL (3700 PSI @ 0.5 BPM) BLEED WHP DOWN & RIH TO CIRC / KILL. TAG TD @ 12861' (UP). FLAG CT @ 12850'. DO PULL TEST OFF BTM. CIRC KILL DOWN FL. PINCH THEN CLOSE IN RETURNS. CONTINUE PUMPING DOWN CT. 01/01/03 ~ COMPLETE CI~C KILL AT TM. PUMF~24 B~rs OF 15.8 # CLASS G CEMENT DOWN CT. LAY IN FROM 12850': PULL TO SAFETY @ ~.'BUMP PRESSURE TO 800 PSI, MONITOR, BUMP PRESSURE TO 1000 PSI. APPEARS TIGHT. REDUCE WHP TO 500 PSI. DROP BALL, CONTAMINATE W/1.5# BIO FROM 9000' TO 10290. JET SLICK WATER FROM 10290'-9000', UP/DOWN @ 50%. JET FROM 10290' UP @ 80%. MAKE REPEAT SLOW PASSES ACROSS JEWELRY AND GLM'S. FP W/METHNVTR FROM 2000'. TRAP 500 PSI WHP. 01/02/03 PRESSURE TEST COIL TUBING PXA, CEMENT PLUG. TEST PASSED. 01/07/03 PPPOT-IC PASSED TO 3000 PSI (PLASTIC PACKED). TORQUED LDS TO 450 FT-LBS. lC HANGER LDS WORKED FINE. RUN 3.625 CENT, SAMPLE BAILER TO TOP OF CEMENT @ 10279' SLM ( CORRECTION TD = 10318') ((BAILER EMPTY)) 3-17E/K-30 Page 2 01/12/03 TUBING PUNCH, STRING SHOT, CHEMICAL CUTTER. PUNCH 9 HOLES IN TUBING 10210'-10212'. FIRE STRING SHOT OVER THE INTERVAL 10224'-10236' TO CLEAN PIPE FOR CHEMICAL CUTTER SEV HEAD AND ANCHORS. CUT PIPE AT 10235' USING 3 5/8" CHEMICAL CUTTER. GOOD INDICATION OF CUT. 01/15/03 PUMP 1006 BBLS OF SEAWATER DOWN THE TUBING TAKING RETURNS UP THE INNER ANNULUS TO CIRC OUT GAS. PUMP 125 BBLS OF DIESEL TO FREEZE PROTECT TUBING AND INNER ANNULUS. 01/29/03 PT BPV AND CEMENT PLUG TO 2000 PSI. PASSED TEST. PUMPED 10 BBLS OF DIESEL DOWN IA UP TBG TO TEST BPV. 01/30/03 CHECK LOCK DOWN SCREWS. ALL LDS FUNCTIONED EXCEPT FOR ONE LDS THAT APPEARS TO BE FROZEN TO THE GLAND NUT. THE PIN DOES FUNCTION AND IS WORKING. BP Page 1 ~,1~ Operations Summary Report Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Spud Date: 2/23/2003 Event Name: REENTER+COMPLETE Start: 2/23/2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 2/2212003 13:00 - 15:30 2.50 MOB P PRE PREPARE RIG TO SKID RIG FLOOR 15:30 - 16:30 1.00 MOB P PRE SKID RIG FLOOR 16:30 - 18:00 1.50 MOB P PRE MOVE PIT MODULE AROUND WELL ROW 4 18:00 - 19:00 1.00 MOB P PRE JACK UP CANTILEVER LEGS 19:00 - 20:00 1.00 MOB P PRE MOVE SUB BASE OFF WELL 4-10 - MOVE SUB AROUND CORNER OF WELL ROW 4 20:00 - 21:00 1.00 MOB P PRE PICK UP TREE WITH CELLAR BRIDGE CRANE - SET ON STUMP ON BOP DECK - SET OPEN TOP TANK 21:00 - 00:00 3.00 MOB P PRE INSTALL AUGAR END FOR OPEN TOP TANK - WELD FRAME WORK ON HOLE IN SUB BASE WALL AND PIT MODULE WALL FOR FILL UP LINE - INSTALL COUNTER BALANCE ON TOP DRIVE - SET MATS TO MOVE ON 3-17 2~23/2003 00:00 - 02:30 2.50 MOB P PRE FINISH INSTALLING COUNTER BALANCE ON TOP DRIVE - FINISH WELDING PROJECTS IN PITS I ON RIG - FINISH INSTALLING AUGAR DUMP ON PITS 02:30 - 04:00 1.50 MOB P PRE MOVE SUB OVER WELL 3-17 / K-30 - CENTER SUB TO WELL 04:00 - 05:00 1.00 MOB P PRE MOVE AND SET PIT MODULE 05:00 - 06:30 1.50 RIGU P PRE HOOK UP ALL SERVICE LINES - PRESSURE TEST GAS LINE WITH WELL TENDER 06:30 - 07:00 0.50 RIGU P PRE LOWER BACK SUPPORT LEGS ON SUB 07:00 - 08:00 1.00 RIGU P PRE SKID RIG FLOOR OVER WELL 3-17E 08:00 - 11:00 3.00 RIGU P PRE CLOSE CELLAR DOORS - INSULATE CELLAR AROUND WELL HOUSES - FOLD IN BEAVER SLIDE - SET STEPS AROUND RIG - INSTALL GERONIMO LINE -TAKE ON 100 BBLS SEAWATER 11:00 - 12:30 1.50 RIGU P PRE HOOK UP SECONDARY VALVE ON ANNULUS VALVE 12:30 - 13:30 1.00 WHSUR P DECOMP ACCEPT RIG 12:30 HRS ON 2/23/2003 - RIG UP LUBICATOR AND PULL BPV - RIG DOWN LUBICATOR 13:30 - 15:30 2.00 RIGU P DECOMP RIG UP TP DISPLACE WITH SEAWATER - TEST ALL SURFACE LINES TO 3000 PSI 15:30 - 20:30 5.00 CLEAN P DECOMP DISPLACE FREEZE PROTECTION WITH SEAWATER- PUMP 300 BBLS - STAGE UP TO 2 BPM THEN 5 BPM 2 BPM - 500 PSI - 5 BPM 1050 PSI - WAIT 30 MINS - PUMP '300 BBLS - STAGE UP TO 2 BPM THEN 5 BPM 2 BPM - 375 PSI - 5 BPM 1025 PSI - WAIT 30 MINS - PUMP 300 BBLS - STAGE UP TO 2 BPM - THEN 5 BPM 2 BPM - 400 PSI - 5 BPM 1050 PSI - MONITOR WELL FOR 30 MINS - WELL STABLE 20:30 - 21:00 0.50 WHSUR P DECOMP SET TWC - BLOW DOWN LINES 21:00 - 21:30 0.50 WHSUR P DECOMP TEST TWC TO 1000 PSI FOR 15 MINS 21:30 - 22:00 0.50 REST P DECOMP BLOW DOWN ALL SURFACE LINES - PICK UP AND CLEAR AREA FOR NIPPLE DOWN TREE - NU BOP 22:00 - 00:00 2.00 WHSUR P DECOMP NIPPLE DOWN 4 1/16" TREE - ADAPTER FLANGE - SEPERATE ADAPTER FLANGE FROM TREE - PLUG CONTROL LINE PORTS ON HANGER - SCREW XO SUB INTO HANGER TO ENSURE THREAD INTERGRITY' OF HANGER - THREADS TDS - NOSE SEAL BAD - STRENGTH INTERGRITY IS GOOD 2~24~2003 00:00 - 09:30 9.50 BOPSUF;P DECOMP NIPPLE UP - SPACER SPOOL - RISER - BOP'S - CHANGE BOTTOM RAMS'TO 4 1/2" X 7" VARIABLES - (LOAD PIPE SHED WITH 5" DP) 09:30 - 10:30 1.00 BOPSUF,P DECOMP HOOK UP CHOKE LINE - KILL LINE Printed: 3/24/2003 9:13:41 AM BP Page 2 of 1,~' Operations Summary Report :Legal Well Name: 3-17E/K-30 :Common Well Name: 3-17E/K-30 Spud Date: 2~23~2003 Event Name: REENTER+COM PLETE Start: 2~23~2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/24/2003 .10:30 - 12:00 1.50 BOPSUR P I DECOMP HELD PJSM. M / U TEST JOINT, R / U TO TEST BOPE 12:00 - 19:00 7.00 BOPSUI; ~ DECOMP TESTED BOPE - ANNULAR 250 LOW / 3,000 HIGH - 5 MINS EA TEST - PIPE RAMS - BLIND RAMS - CHOKE MANIFOLD - CHOKE LINE MANUAL VALVE / CHOKE HYDRAULIC VALVE - KILL LINE MANUAL VALVE / KILL LINE HYDRAULIC VALVE - FLOOR SAFETY VALVES - UPPER I LOWER IBOP VALVES - 250 LOW / 4,500 HIGH - 5 MINS EA TEST 19:00 - 20:00 1.00 BOPSUF 3 DECOMP R i D BOPE TEST EQUIPMENT 20:00 - 22:30 2.50 EVAL = DECOMP PJSM - DERRICK INSPECTION 22:30 - 23:00 0.50 RIGU = DECOMP INSTALL BAILS - ELEVATORS ON TOP DRIVE 23:00 - 00:00 1.00 WHSUR 3 DECOMP SET SHOOTING FLANGE - RIG UP LUBRICATOR 212512003 00:00 - 00:30 0.50 WHSUR P DECOMP HELD PJSM. PULLED TWC WITH DSM - RIGGED DOWN LUBRICATOR - LAID DOWN SHOOTING FLANGE. 00:30 - 01:00 0.50 PULL P DECOMP PICKED UP TWO JOINTS 5" DP MADE UP XO - RIH - SCREWED INTO HANGER - 11 TURNS MADE UP TDS THREADS. 01:00 - 01:30 0.50 PULL i p DECOMP CHECKED ANNULUS, NO PRESSURE - WELL STABLE - BACKED OUT LOCK DOWN SCREWS - PULLED HANGER AND TUBING STRING UP 12'- PICK UP WEIGHT 155,000#. 01:30 - 03:30 2.00 PULL P DECOMP BROKE CIRCULATION - CHECKED SURFACE EQUIPMENT FOR LEAKS - CIRCULATED 2 x BOTTOMS - 11,000 STROKES - PUMP RATE 424 GPM, SPP 475 PSI. 03:30 - 04:00 0.50 PULL P DECOMP BROKE OUT AND BLEW DOWN TOP DRIVE. 04:00 - 05:00 1.00, PULL P DECOMP HELD PJSM. PULLED TUBING HANGER TO FLOOR, TERMINATED CONTROL LINES. BROKE OUT AND L / D HANGER. L / D 5" DP AND XO. R / U CAMCO CONTROL LINE SPOOLING EQUIPMENT. 05:00 - 05:30 0.50 PULL P DECOMP CHANGE ELEVATORS - POOH, L / D 4-112" IBT TUBING 05:30 - 06:00 0.50 PULL P DECOMP RIG SERVICE 06:00 - 08:00 2.00 PULL P DECOMP LAY DOWN 4 1/2" TUBING 35 JOINTS - RECOVERED 40 STEEL BANDS - RIG DOWN - LAY DOWN CAMCO SPOOLING SYSTEM 08:00 - 12:00 4.00 PULL P DECOMP CONTINUE LAYING DOWN 4 112" TUBING - TOTAL DOWN 164 JTS 12:00 - 12:30 0.50 PULL P DECOMP PJSM - LAYING DOWN TUBING 12:30 - 13:00 0.50 PULL P DECOMP RIG SERVICE - TOP DRIVE 13:00 - 14:30 1.50 PULL N RREP DECOMP REPAIR HYDRAULIC LEAK ON HYDRAULIC UNIT ON RIG FLOOR 14:30 - 18:00 3.50 PULL P DECOMP CONTINUE LAY DOWN 4 1/2" TUBING - TOTAL JOINTS LAID DOWN 239 JTS - CUT OFF 33.33' - 6 GLM - 1 SSSV - 2 PUPS 18:00 - 19:00 1.00 PULL P DECOMP PJSM - RIG UP SCHLUMBERGER WlRELINE TOOLS 19:00 - 22:00 3.00 PULL P DECOMP RIH WITH CCL - GR - JB - GR 8.0" - TAG UP ON TUBING CUT 10241' WLM - LOG UP FROM 10241' TO 7800' - POH - NOTHING IN JUNK BASKET 22:00 - 23:00 1.00 PULL P DECOMP CHANGE TOOLS - MAKE UP 9 5~8" EZSV PLUG TO SCHLUMBERGER TOOLS 23:00 - 00:00 1.00 PULL P DECOMP RIH WITH 9 5~8" EZSV PLUG 2/26/2003 00:00 - 01:30 1.50 PULL P DECOMP RIH WITH 9 5/8" EZSV PLUG - SET ON DEPTH @ 10180' - FIRED SETTING TOOL 3 TIMES - NO INDICATION OF RELEASING SLEEVE - LINE WEIGHT 3800 - PU TO 4500 LINE WEIGHT - NOT RELEASED - SLACK OFF TO 1900 LINE WEIGHT - PLUG SET NO MOVEMENT DOWN - PU TO Printed: 3/24/2003 9:'~3:41 AM BP Page 3 of,,1,~' Operations Summary Report Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Spud Date: 2/23/2003 Event Name: REENTER+COMPLETE Start: 2/23/2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 212612003 00:00 - 01:30 1.50 PULL P , DECOMP 7000 LINE WEIGHT 75% OF LINE PULL - NOT RELEASED TOP OF FISH 10156.6' - FISH LENGTH 23.4" - ROPE SOCKET CONNECT OD 2 1/4" / 13" LONG - XO TO ROLLER HOUSING - FISHING NECK 3 3/8" OD - FISHING LENGTH 16" - ROLLERS 5 1/2" OD - ROLLER HOUSING 4" - 3 SETS OF ROLLERS ON TOOL 01:30 - 02:30 1.00 PULL N DFAL DECOMP PJSM - RIG UP T-BAR TO BLOCKS - PULL LINE FROM ROPE SOCKET WITH BLOCKS - RIG DOWN T-BAR 02:30 - 03:00 0.50 PULL P DECOMP POH WITH WIRE LINE - DISCONNECT FROM ROPE SOCKET ON LINE 03:00 - 03:30 0.50 PULL P DECOMP RIG DOWN SCHLUMBERGER TOOLS 03:30 - 04:30 1.00 PULL P DECOMP CLEAR RIG FLOOR OF TOOLS (POWER TONGS - HANGER - 2 PUPS - ELEVATORS - SLIPS) PICK UP WEAR RING - RUNNING TOOL 04:30 - 05:00 0.50 PULL P DECOMP INSTALL WEAR RING 05:00 - 08:00 3.00 PULL P DECOMP PREPARE TO PU 5" HWDP - LOAD 6 1/4" DC'S IN PIPE SHED - STRAP / OD / ID'S - 08:00 - 09:00 1.00 PULL P DECOMP MAKE UP BAKER OVERSHOT WITH 3 3/8" GRAPPLE 09:00 - 12:00 3.00 PULL P DECOMP PICK UP BHA - RIH TO 761' 12:00 - 17:30 5.50 PULL P DECOMP RIH WITH 5" DP FROM SHED - 5" DP PACKED WITH ICE / SNOW - STEAM OUT EACH JOINT TO ENSURE OPEN - RIH TO 3900' 17:30 - 18:00 0.50 PULL P DECOMP CIRCULATE DRILL PIPE VOLUME - 90 SPM - 350 PSI - UP WT 150K - SO 150K - BLOW DOWN TOP DRIVE 18:00 - 21:00 3.00 PULL P DECOMP CONTINUE PICKING UP 5" DRILL PIPE - STEAMING OUT SNOW / ICE PACKED JOINTS - RIH TO 7100' 21:00 - 22:00 1.00 PULL P DECOMP CIRCULATE DRILL PIPE VOLUME - 90 STKS - 500 PSI - UP WT 190K - SO 170K - BLOW DOWN TOP DRIVE 22:00 - 00:00 2.00 PULL P DECOMP CONTINUE PICKING UP 5" DRILL PIPE - STEAMING SNOW / ICE PACKED JOINTS - RIH TO 9300' - TOTAL JOINTS 5" DRILL PIPE PICKED UP 269 2/27/2003 '00:00 - 00:30 0.50 PULL P DECOMP RIG SERVICE - INSPECT TOP DRIVE 00:30-01:30 1.00 PULL P DECOMP CONTINUE PICK UP 5" DRILL PIPE - FROM 9300' TO10120' - TOTAL PICKED UP 295 JOINTS 01:30 - 02:00 0.50 PULL P DECOMP BREAK CIRCULATION @ 7 BPM - PSI 400 - PU 245K - SO 200K - TEST HARD LINE FROM 3-17 TO 3-19 TO 1800 PSI - OK 02:00 - 05:30 3.50 PULL P DECOMP PJSM - PAD OPERATOR OPENED FLOW VALVE ON 3-19 - START DISPLACING SEAWATER WITH MILLING FLUID FROM 3-17- TAKING RETURNS TO 3-19 - STAGING UP RATE'S - (100 BBLS SEAWATER OUT OF PITS - 50 BBLS FRESH WATER - 670 BBLS MUD) 2 BPM 350PSI 4 BPM 450 PSI 5 BPM 700PSI 5 BPM MAX RATE PRODUCTION CAN HANDLE - CUT :DISPLACEMENT 100 BBLS SHORT - TOOK RETURNS INTO PITS FOR'FINAL 100 BBLS - TO ENSURE NO MUD INTO PRODUCTION FLOW LINE - FINAL RATE 10 BPM - 1600 PSI 05:30 - 06:00 0.50 PULL N DFAL DECOMP RIH TAG FISH @ 10156' - PUMP 23 STKS 800 PSI - Printed: 3/24/2003 9:13:41 AM (' BP Page 4 of 1~ Operations Summary Report Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Spud Date: 2/23/2003 Event Name: REENTER+COMPLETE Start: 2/23/2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: Date From- To Hours Task Code NPT Phase Description of Operations 2/27/2003 05:30 - 06:00 0.50 PULL N DFAL DECOMP INCREASE TO 950 PSI - PU 245 - SO 195 - ROT 225 - 80 RPM 10K TQ - 90 RPM - 11K TQ - 100 RPM 11K TQ - PULL 35K OVER STRING WT TO 280K - SHEAR OFF PLUG - SHEAR OUT CIRCULATING SUB @ 3200 PSI - 06:00 - 06:30 0.50 PULL P DECOMP PUMP DRY JOB - BLOW DOWN TOP DRIVE 06:30 - 13:30 7.00 PULL P DECOMP POH WITH FISH - DRAG NORMAL - RECOVERED 100% OF ALL FISH 13:30 - 14:30 1.00 PULL N DFAL DECOMP LAY DOWN FISH - FISHING TOOLS - CLEAR FLOOR 14:30 - 16:00 1.50 STMILL P WEXIT TEST CASING TO 3000 PSI FOR 30 MINS - TEST ON CHART - UNPLUG DRIP PAN UNDER RIG FLOOR 16:00 - 17:00 1.00 STMILL P WEXIT MAKE UP 9 5/8" SECTION MILLING ASSEMBLY 17:00 - 19:30 2.50 STMILL P WEXIT RIH WITH MILLING ASSEMBLY to 3130' 19:30 - 21:00 1.50 STMILL P WEXIT CUT DRLG LINE - BREAK CIRCULATION - 45 SPM 500 PSI (TOOK 6 BBLS TO FILL PIPE) 21:00 - 22:30 1.50 STMILL P WEXIT CONTINUE RIH FROM 3130' TO 4750' 22:30 - 23:00 0.50 STMILL P WEXIT BREAK CIRCULATION - 100 SPM 1500 PSI - (TOOK 8 BBLS TO FILL PIPE) 23:00 - 00:00 1.00 STMILL P WEXlT CONTINUE RIH FROM 4750' TO 7409' (TOOK WEIGHT @ 7380' 10 TO 15K IMEDIATELY DROPPED OFF - PULLED BACK THROUGH - NO DRAG SEEN - RIH - DID NOT SEE ANY THING) 2/28/2003 00:00 - 02:00 2.00 STMILL P WEXlT CONTINUE RIH FROM 7409' TO 7889' - FILL PIPE - CONTINUE RIH FROM 7889' TO 10176' TAG UP ON EZSV PLUG 02:00 - 03:00 1.00 STMILL P WEXlT PICK UP 5' - SPOT 20 BBL 18 PPG PILL ON TOP OF EZSV PLUG 03:00 - 03:30 0.50 STMILL P WEXlT POH TO 9976' MILLING DEPTH 03:30 - 00:00 20.50 STMILL P WEXlT START MILLING SECTION @ 9976' - 10004' - 28' CUT IN 20.5 HRS - AVG 1.4 FT/HR - 28' = 1316 LBS METAL - RECOVERED 1025 LBS = 77 % - WT ON CUTTING BLADES 8K TO 16K - GPM 650 - PP 3500 - RPM 85 - TQ 18K TO 21K - ROT WT 208K - PUMPED 8 SWEEPS - 1 LOW - 1 HIGH - 6 BAROLIFT '3/1/2003 00:00 - 09:30 9.50 STMILL P WEXlT MILLING 9 5/8" SECTION FROM 10004' TO 10026' - WEIGHT ON BLADES 8K TO 16K - RPM 85 / 110 - TQ ON 20K OFF 14K - GPM 600 / 650 - PP 3000 / 3500 - PU 285 - SO 195 - ROT 225 - CUT 50 FEET = 2350 # METAL - RECOVERED - 3000 # METAL / BAROLIFT/CUTTINGS = 130% - (BAROLIFT MIXED WITH MUD IS PROBABLY THE :DIFFERENCE IN WEIGHT) 09:30 - 14:00 4.50 STMILL :P WEXlT CIRCULATE CLEAN HOLE OF METAL CUTTINGS - RECIPROCATE AND ROTATE PIPE THROUGH WINDOW - WORK MILL ON TOP STUMP TO CLEAR ANY CUTTINGS NEST OFF MILL - 150 RPM - TQ 14K - GPM 670 - PP 3750 - PUMPED 5 HI-VIS SWEEPS - 2 WEIGHTED - 1 WEIGHTED HI-VIS - PULL INTO CASING - PUMP DRY JOB - BLOW DOWN TOP DRIVE 14:00 - 16:30 2.50 STMILL :~ WEXIT POH TO 5400'- NOTICED METAL BIRDS NEST IN BOPS 16:30 - 17:30 1.00 STMILL = WEXlT KNOCK BIRDS NEST APART - CIRC IT OUT - PUMPING THROUGH KILL-LINE 17:30 - 18:00 0.50 STMILL ~ WEXIT POOH TO 5000'- (ClRCUI~,TE THROUGH KILL LINE VERY LITTLE CUTTINGS BACK) 18:00 - 19:00 1.00 STMILL = WEXIT RIG SERVICE TOP DRIVE - DRAWWORKS - TROUBLE Printed: 3/24/2003 9:13:41 AM BP Page 5 of,,~,,, Operations Summa Report Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Spud Date: 2/23/2003 Event Name: REENTER+COMPLETE Start: 2/23/2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/1/2003 18:00 - 19:00 1.00 STMILL P WEXlT SHOOT CROWN-O-MATIC 19:00 - 21:00 2.00 STMILL P WEXlT POOH - SPORADIC OVERPULL FROM 1970 TO 1750' - 21:00 - 22:00 1.00 STMILL P WEXlT CIRCULATE HOLE @ 1750' - GPM 630 - PP 1450 - SLOWLY WORK PIPE UP WHILE CIRCULATING - WORK PIPE TWICE - RECOVERED 4 BUCKETS OF METAL - 22:00 - 23:00 1.00 STMILL P WEXlT CONTINUE POH FROM 1750' TO BHA - NO DRAG 23:00 - 00:00 1.00 STMILL P WEXIT LAYING DOWN 6 1/4" DC'S 3/2/2003 00:00 - 01:30 1.50 STMILL P WEXIT LAYING DOWN 6 1/4" DC'S - LAST TWO DC'S WITH CUTTER - CIRCULATE 600 GPM PULLING THE TOOL OUT TO FLUSH STACK - LAY DOWN MILL - XO 01:30 - 03:00 1.50 STMILL P WEXlT MAKE UP STACK WASHER WITH STRING MAGNET - RIH WASH STACK - 400 GPM - 100 RPM ROTATING - WASH / FLUSH STACK 4 X - LOTS OF METAL BACK ON MAGNET AND AT SHAKER'S 03:00 - 03:30 0.50 STMILL P WEXIT LAY DOWN STACK WASHER - STRING MAGNET - 2 DC'S - BLOW DOWN TOP DRIVE 03:30 - 04:00 0.50 REMCM'I'P WEXlT RIG SERVICE - ADJUST TOP DRIVE 04:00 - 09:30 5.50 REMCM'I'P WEXlT MAKE UP MULESHOE - RIH TO 9520 - BREAK CIRCULATION @ 2376' - 4750 - 7133 - 9520' 09:30 - 11:00 1.50 REMCM']'P WEXIT PICK UP SINGLES FROM PIPE SHED 21 JOINTS - CONTINUE RIH TO 9970' - WASH FROM 9970 TO 10076' 11:00 - 13:00 2.00 REMCM']'P WEXIT CIRCULATE / CONDITION MUD FOR KICK OFF PLUG - RPM 90 -TQ 12K- GPM 42~.~.~P 1100- PU 230K- SO 185K- ROT 200K // 13:00- 14:30 1.50 REMCM']'P WEXIT PJSM-BATCH MI~f~.~4/BBLS CEMENT 17 PPG- PUMP 10 BBLS WATER-4 B~.P.P~- 680 PSI- TEST LINES TO 3500 PSI - PUMP 10 BBLS WATER - PUMP 34 BBLS CEMENT - 5 BPM - 1300 PSI - PUMP 7 BBLS WATER - DISPLACE WITH RIG - 153 BBLS MUD - CUT DISPLACEMENT SHORT 5 BBLS - 10 BPM - 800 PSI 14:30 - 15:00 0.50 REMCM'I'P WEXIT POH 8 STANDS SLOWLY TO 9295' 15:00 - 16:00 1.00 REMCM']'P WEXIT PUMP 30 BBL NUT PLUG SWEEP AROUND - PUMP WIPER BALL OUT DP - 423 GPM - 1600 PSI - CLEAR PIPE 16:00 - 18:00 2.00 REMCMI'P WEXIT PERFORM HESITATION SQUEEZE 16 STKS 350 PSI - 310PSI 27 STKS 650 PSI- 625 PSI 42 STKS 1000 PSI - 925 PSI 63STKS 1350 PSI -1250 PSI 86STKS 1700 PSI -1500 PSI 100 STKS 1800 PSI - 1675 PSI 117 STKS 2000 PSI - 1800 PSI FINAL PRESSURE AFTER 1 HR PUMPED 11.78 BBLS - BACK 8 BBLS 18:00 - 18:30 0.50 REMCM' P WEXIT BREAK OUT TEST EQUIPMENT - PUMP DRY JOB - BLOW DOWN SURFACE EQUIPMENT 18:30 - 22:30 4.00 REMCM'i'P WEXIT POOH FROM 9295' TO SURFACE BREAK OFF MULESHOE 22:30 - 00:00 1.50 BOPSUF~P PROD1 DRAIN STACK - RIG UP TO PULL WEAR RING - METAL ON TOP OF WEAR RING - PICK UP STAND 5" - USE TOOL JOINT AS MAGNET - RETRIEVE METAL STRINGERS FROM TOP OF WEAR RING - SEVERAL RUNS MADE CLEANING OUT METAL' 3/3/2003 00:00 - 00:30 0.50 BOPSUF:P PROD1 RUN IN WITH RUNNING TOOL - RETRIEVE WEAR RING 00:30 - 01:30 1.00 BOPSUF:P PROD1 MAKE UP TEST ASSEMBLY - FILL STACK / MANIFOLD Printed: 3/24/2003 9:13:41 AM BP Page 6 of ~ Operations Surnma Report Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Spud Date: 2/23/2003 Event Name: REENTER+COMPLETE Start: 2/23/2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 3/3/2003 00:30 - 01:30 1.00 BOPSUR P PROD1 WITH WATER 01:30 - 04:30 3.00 BOPSUR N SFAL PROD1 TESTING LOWER PIPE RAMS - NO VISABLE LEAKS - RAMS HOLDING - NO LEAK FROM ANNULUS - GRADUAL PRESSURE LEAK FROM 4500 TO 4200 PSI IN 3 TO 4 MINS - TROUBLE SHOOTING LOSS OF PRESSURE - FOUND PROBLEM IN PRESSURE MANIFOLD - BY-PASS MANIFOLD - CONTINUE TESTING 04:30 - 09:00 4.50 BOPSUR P PROD1 TEST BOP'S - ANNLUAR 250 LOW 3000 HIGH - 5 MINS EACH TEST - RAMS UPPER / LOWER - BLIND - CHOKE MANIFOLD - HYD CHOKE VALVE - MANUAL CHOKE VALVE - KILL HYD VALVE - KILL MANUAL VALVE - UPPER ! LOWER IBOP - FLOOR SAFETY VALVES - SPACER SPOOL ANNULUS VALVES - 250 LOW 4500 HIGH - 5 MINS EACH TEST - TEST GOOD - JOHN CRISP WITH AOGCC WAIVED THE WITNESS OF THE TEST 09:00 - 09:30 0.50 BOPSUF; P PROD1 INSTALL WEAR RING - SHUT ANNULUS VALVES 09:30 - 13:30 4.00 DRILL P PROD1 PU 5" DRILL PIPE FROM SHED TO COMPLETE STRING FOR TD OF 3-17 - PU 99 JTS S-135 - 13:30 - 14:00 0.50 DRILL P PROD1 'CIRC 30 BBL WLLNUT SWEEP THROUGH DP TO CLEAN RUST / SCALE OUT OF PIPE - 600 GPM - 750 PSI 14:00 - 15:30 1.50 DRILL N RREP PROD1 WORK ON PASON EQUIPMENT ON CROWN - TRACKING UNIT FOR FOOTAGE / DEPTH AT BIT 15:30 - 17:00 1.50 DRILL P PROD1 BLOW DOWN TOP DRIVE - POH 5" DP - LID MULESHOE - CLEAR FLOOR 17:00 - 20:00 3.00 DRILL P PROD1 PU MOTOR / MWD - ORIENT SAME - PROGRAM MWD - FLEX DC'S - JARS - 5 JTS HWDP - SHALLOW TEST @ 350' 20:00 - 00:00 4.00 DRILL P PROD1 RIH - FILL PIPE @ 3190' 90 STKS 1800 PSI - 5560' 90 STKS 1800 PSI - 7946' 90 STKS 3200 PSI - JET PLUGGED - WORK PIPE - DUMP PRESSURE - UNPLUG JET - 90 STKS 1800 PSI - CIRCULATE FOR 20 MINS CLEAR PIPE - BLOW DOWN TOP DRIVE 3/4/2003 00:00 - 01:00 1.00 DRILL P PROD1 Held Pre-Job Safety Meeting And Continue To RIH w/8 1/2" Directional BHA On 5" DP From 7,946' To 9,300' 01:00 - 01:30 0.50 DRILL P PROD1 Connect Tesco Top Drive And Break Circulation - Record Pump Pressure At The Following Rates: Rate GPM Pressure 90 381 1700 PSI 100 423 2100 PSI 136 575 3500 PSI Wash From 9,300' TO 9,830' - Tag Good Hard Cement 01:30 - 02:30 1.00 DRILL P PROD1 Drilled Good Cement By Rotating From 9,830' to 9,929' WOB Rotating 20,000# - 30,000#, RPM 60, Motor RPM 145, Torque Off Bottom 18,000 ft / lbs - On Bottom 15,000 ft / lbs, Pump Rate 450 To 500 gpm, SPP Off Bottom 3,000 psi, On Bottom 3,200 psi. String Weight Up 235,000#, String Weight Down 185,000#, String Weight Rotating 215,000# 02:30 - 03:00 0.50 DRILL P PROD1 'Circulate Out Clabbered Mud While Reciprocating And Rotating Drill String 03:00 - 04:00 1.00 DRILL P PROD1 Continue To Drill Hard Cement From 9,929' To 9,979'- WOB Rotating 25,000# - RPM 60, Motor RPM 145 Printed: 3/24/2003 9:13:41 AM BP Page 7-ef~ Operations Sumrna Report Legal Well Name: 3-17E/K-30 Common Well Name: 3-17E/K-30 Spud Date: 2/23/2003 Event Name: REENTER+COMPLETE Start: 2/23/2003 End: 3/18/2003 Contractor Name: DOYON Rig Release: 3/18/2003 Rig Name: DOYON 15 Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 3/4/2003 04:00 - 08:00 4.00 DRILL P PROD1 Per Well Program Orient Motor Tool Face 'To 90 Degrees Left Of High Side For Kick Off And Directional Drill Ahead From 9,~6' (20 Feet Below Bottom Of Window) 08:00 - 09:00 1.00 DRILL P PROD1 Pull Bit Into Casing - Circulate And Condition Mud For Formation Integrity Test 09:00 - 09:30 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Preform FIT To 12.0 PPG EMW Closed Annular Element And Performed FIT. Strokes Pmp'd Pressure 4 125 psi 8 235 psi 12 375 psi 16 500 psi 20 625 psi 24 750 psi 28 875 psi 32 950 psi Held Test F1 10 minutes w/50 Psi. Pressure Loss. MW 9.7 ppg, Csg Shoe TVD 7,734' Pressure 950 psi = 12.06 PPG. EMW. Bleed Pressure To 0 Psi. - Open Annular 09:30 - 12:00 2.50 DRILL P PROD1 Blow Down Kill Line - Hold Pre-Job Safety Meeting With All Personal - Pump Hi-Vis Sweep And Displace Hole To Baroid GEM Enhanced Mud At 7 BPM And 80 RPM - Clean Mud Trough And Shaker Possom Belly - Record Slow Pump Rates - Wash Back To Bottom At 10,046' 12:00 - 13:00 1.00 DRILL P PROD1 Directional Drill Ahead Sliding From 10,046' To 10,068' 13:00 - 14:00 1.00 DRILL N RREP PROD1 : Held Pre-Job Safety Meeting - POH To Window And Repair :Cooling System On Turbine 14:00 - 00:00 10.00 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,068' to 10,360'. WOB Sliding 20,000# - 30,000#, WOB Rotating 25,000# - 28,000#, RPM 60 To 85, Motor RPM 148, Torque Off Bottom 19,000 ft / lbs To 22,000 ft / lbs. - On Bottom 18,500 ft / lbs, Pump Rate 508 gpm, SPP Off Bottom 2,400 psi, On Bottom 2,580 psi. String Weight Up 295,000#, String Weight Down 175,000#, String Weight Rotating 215,000#. ART -- 6.11 hrs, AST = 6.01 hrs. *NOTE* Excessive Torque (27K) On Connection At 10,326' While Back Reaming Stand Up - Lost Power To Top Drive Had To Reset Breakers 3/5/2003 00:00 - 07:30 7.50 DRILL ~ PROD1 Drilled 8 1/2" Directional Hole By Rotati~And Sliding From 10,360' to 10,614"~h~cord SlowPu/n~ Rates - WOB Sliding 20,000# - 30,000#, WO.B., Rotating25,000# - 28,000#, RPM 60 To 85 Motor_R. PM 148, Tbr~ue/,Off Bottom 19,000 ft /lbs To 22,000 ft / Ib~. '- On Bottom 1,;8,500 ft / lbs, Pump Rate 508 To 550 gpm, SPP Off Botto_m.~. ,6_ 8b,l~.si, On Bottom 2,950 psi. String Weight Up 295,0/00#, String YV~eight Down 175,000#, ........... String Weight Rotatin.,~215,000# -AR~= 4.06 hrs, AST = 1.05 hrs. ~e 'h2'2~0 ' 07:30 - 09:00 1.50 DRILL ~ PROD1 Circulate Hi-Vis p At 546 GPM Wit Ps~ While Rotating And P/,/eciprocating Drill String "-. ? Printed: 3/24/2003 9:13:41 AM t~ STATE OF ALASKA l' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2755' NSL, 799' WEL, SEC. 08, T11N, R17E, UM At top of productive interval 3329' NSL, 1454' WEL, SEC. 05, T11N, R17E, UM At effective depth 3329' NSL,1451' WEL, SEC. 05, T11N, R17E, UM At total depth 3325' NSL, 1485' WEL, SEC. 05, T11N, R17E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 3-17DIM-31 9. Permit Number 198-208 10. APl Number 50- 029-21946-04 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 13010 feet true vertical 10146 feet Effective depth: measured 12878 feet true vertical 10018 feet Casing Length Structural Conductor 142' Surface 2498' Intermediate 10500' Production Liner 386' 2706' Plugs (measured) Junk (measured) Size Cemented 30" Driven 13-3/8" 4185 cuft Permafrost 9-5/8" 575 cu ft Class 'G' 7"x4-1/2" 218 CU ft Class 'G' 2-7/8" 127 cu ft Class 'G' MD TVD 142' 142' 2498 2496' 10500' 8082' 10312'-10698' 7959'-8225' 10304'-13010' 7954'-10146' Perforation depth: measured 12897' - 12902' true vertical 10037' - 10041' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing to 10324' RECEIVED NOV 1 8 2002 Oil& Gas Cons. Commissio~ Packers and SSSV (type and measured depth) 9-5/8" packer at 10266'; HXO SVL SSSV Landing Nipple at l~lOIra~e 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation December 2, 2002 16. If propOsal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Walter Quay, 564-4178 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: / [] Oil [] Gas [] Suspended Service SCANNED DEC 0 $ 2002 Prepared By Name/Nurnbefi Sondra Stewman, 564-4750 17. I hereby certify that the fqrego'l~g is trj,l~ and correct to the best of my knowledge Signed Fred Johnson j -~//-/~Z//-~-,'3,1. Title Senior Drilling Engineer Date ////~,A~,O 7.. i i'. i' ':'.;.:..! ! i':.:.;.i!", :..: ,.:;;:.:!:i : .:?'.'.";".'.i'( ':?,;'i:.: i:' i ii: :i',::::'i:: :i :' .:::',i:'[ ::;:';:i;:. ~i!i~~~ ;~::i ';i 'i: .".':: :i ;: [i:'?::.';'~?i;:?'";, i!; i~; [:i~!~i~j~lli::,"~:i ~!~'~'!'i;"i.:i ?.;: ':?:ii .?:.!'i'!"' ?.!?! :?:,::!::i i:,i;; 'i':: i'?,:! :': ':,?i ';i: !:, :..'!'i :[ !!!' ':, ?!"i :.! i:.i "i:' :i"'i!'' !:;:;.[ ;.:~;': ':.!: !.: '::;';'.:.': [:::, '. ii::'? ':.i .! i;:'i ~' .!;':.:i i'I ::!'; i:' :.,.! i:I !;'.!'!, !i!!i :;..; ii, i:,. 'Conditian; af Al~Proval: Notify (~ommission ~s~ representati~/e m~y,,witn~ss ......... I _ ' ...' _ .-, ~...~"" ' · ./ ~¥ · I Approval NO Plug integrity )r,,. BOP Test ,~ Location clearance I ',._c,,c--~,-- ,...,,,.-..~ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission '"~'"~'"~'~~ ~ Commissioner Date /f/'z' ~/,',~ z. Form 10-403 Rev. 06/15/88RBDNS BFL",-/" ~ ~.-~' ~ ~ '~ I t I N~t~,'~'II'~IAi., ~!~!l/?5':;r',? Submit In Triplicate Endicott 3-17d To: From: Subject: Reference: Winton Aubert - AOGCC Date: November 14, 2002 Walter Quay Endicott 3-17d/M31 Application for Sundry Approval - Plug and Abandon for Sidetrack Operations APl # 50-029-21946-4 Approval is requested for the proposed sidetracking of 3-17d/M-31 to a new bottom hole location as a conventional producer targeting Kekiktuk zone 2A reserves. The proposed path forward is to pump cemen't to cover the perforations and fill the 2-7/8" casing to the 4-1/2" X 2-7'8;Ji'd',~hanger to abandon the old wellbore, then cut the 4-1/2" tubing above the productio,,n packer at -1,~,250'/IVID. The rig would then move on, pull the tubing above the cut, section mill the 9-5/8 casing @ -~5b' to 10,200' then sidetrack the well to the new bottom hole location, and run a 4-1/2" liner cemented back into the 9-5/8" casing. See attached schematics for details. The sidetrack is currently scheduled for Doyon 15 beginning around February 1, 2003, after the completion of the 4-10 sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved, with the target date to commence pre-rig work on December 2, 2002. SCANNED DEC 0 6 200?_ Version 1.0 18 Nov 2002 Endicott Sidetrack and Complete Procedure Summary 3-17d Pre-Riq Work: 1. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. Ri.q 1. 2. 3. COMPLETE (10/10/01): Packoff passed test to 3000 psi, Tubing hanger p~sed test to 5000 psi. All lock-down screws functioned. Some Iockscrews are hard to operate. 2. RU slickline~_drift tubing and tag PBTD. Well drifted on 11/11/02 w/2.25" OD to 12,839' and w/3.625" OD to 10,266'. Dummy off all GLM's. Test the integrity of the dummied off tubing string by applying -3000 psi on the annutb'~~'. GLMs dummied off and IA x tubing annulus tested to 3000 psi on 10/27/02 3. RIH wit~y~T.U/and perform a cement P&A using 15.8 ppg class 'G' cement. Use adequate cement vol~ fill the. -~.'casing from PBTD (12,878') and extend the cement plug ~ the 4-1/2" tubing @ -/'[0,29.0~. approximately 15' above the 2-7/8" X 4-1/2" liner hanger, plus squeeze'~ to the perforations. Cir~ to clean any residual cement above this depth as the casing cut is ple~'~d for just 40' above this depth, at -10,250'. 4. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut @ T~_~d'. 5. Test the integrity of the cement plug and 2-7/8" casing by pressure testing the tubing to-dO000 psi for 30 minutes. 6. Pull one of the lower DGLMs. Displace the well to clean seawater by circulating down the tubing via the lower GLM. Freeze protect top 1500' MD with diesel. 7. RU E-line. Cut the 4 Y2" L-80 tubing at approximately 10,250' MD using either a jet or chemical cutter. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. If necessary, level the pad. Operations: MIRU Doyon 15. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. Nipple down tree. Ali.qnment marks should be made before removinq the old tree. Nipple up and test BOPE to 250 / 5000 psi. Pull TWC. 4. Pull and lay down 4-1/2" tubing from E-line cut and above. 5. MU 9-5/8" window section milling assembly and RIH with 5" DP to top of tubing stub. Displace well to milling fluid. 6. Spot a balanced 18.0 ppg mud pill from -10,250' to 10,150'. 7. Section mill window from 10,150' to 10,200'. POOH. 8. MU cementing mule-shoe and TIH to 10,250'. Circulate and condition. 9. Mix and pump cement kickoff plug. POOH. 10. MU 8-1/2" PDC drilling assembly including MWD/GR RIH to top of cement. Clean out cement to kick-off point. 11. Kick-off and drill the 8-1/2" hole section as per directional plan to TD at +/-13,780" MD (10,332' TVD). Condition hole for running liner, spot liner running pill, and POOH. 12. Run and cement a 4 Y2", 12.6# 13 Cr80 production liner. Release from liner and set liner top packer. Test wellbore to 1000 psi to verify liner top packer is set. 13. Run 4-1/2", 12.6# 13 Cr-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" liner tie- back sleeve. 14. Drop ball/rod & set packer. Test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Freeze protect and secure the well. 17. Rig down and move off. Post-Riq Work: 1. RU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the production packer. Install gas lift valves. 2. RU e-line. Perforate ~50' of Kekituk interval with 2-7/8" guns. SCANNED DEC 0 2002 Version 1.0 2 18 Nov 2002 T, ELEV = 56'~' 3-17d / M31 MAX. DEV. = 56 Deg.@ 6100' TEE: 4-1/16" / 5000 psi / CIW/Baker Act. , WELLHEAD: 13-5/8" / 5000 / FMC SSH big i L- 80, CY1-E BTRS. HES 'HXO' SVL 1,522' ~k (3.813" MIN. ID) 2498' ,~ W/SSSV MIN I.D. 2" 4-1/2" 12.6#/ft L-80 IBM ' Tbg. 9-5/8", 47#/ft ~ CAM~ "TB" 9 CR GLI~ NT80S xo to~ ~ No IVD TVDss I NT 95HS ~ #6 3620' 3504' #5 6326' 5253 #4 7936' 6291 #3 9009' 7009' #2 10031' 7711' #1 10186' 7815' I II HES 'x' Nipple I (3.813" MIN. ID) I 10255' I 9-5/8" -- PACKER I 10266' I ~;~ ~ 4-1/2 X" NIPLE .... I 10201,I J (HES) (3.813" ID) I I/ 2-7/8""x" nipple I 10309' 4-1/2"x2'7/8" I I ~;~] ~/ ~ (2.31"1D) Baker KB Pkr 10,303' 7"ZXPBakor I 10,312', ~/ ,/~~4-1/2 XN"Nipple I 10311'I .... Liner PKR Milled out to 3.81" Btm. 9-5/8" Csg I 10,500' NOTE: Section window in 9-5/8" ' csg. from 10500'-10550' PERFORATION SUMMARY ,--] ~ Baker Tie Back Sleeve I 10698' Date Size I SPF Interval & 2-7/8" ST-L Seal 11/10/98 1-11/16 4 12,756'- 12761' 3A3 Assembly 11/10/98 1-11/16 4 12,852'- 12867' 3A2 10/20/98 1-11/16 4 12,897'- 12902' Zn 2B NOTE: Section window in 4-1/2" liner from 11177' -11193. High dog legs through this area. II 2-7/8" 6.4#/ft. ST-Liner Drift ID = 2.347" Capacity = 0.00579 bbl/ft II I rlll~ 2_7/8, Model M bridge 12878' PBTD 12940' plug (HES) 12903' 2-7/8" Float Shoe 13010' -- DATE REV. BY COMMENTS ENDICOTT WELL 3-17d/M-31 10/24/98 JDE Initial Perfs APl NO: 50-029-21946-04 11/10/98 DB Add Perfs COMPLETION DIAGRAM 11/18/98 DV Set MBP's 11/14/02 WQ Revised 9-5/8" Shoe Depth BP EXPLORATION, INC. Date Size SPF Interval 11/10/98 1-11/16 4 12,756'- 12761' 3A3 11/10/98 1-11/16 4 12,852'- 12867' 3A2 10/20/98 1-11/16 4 12,897'- 12902' Zn 2B T. ELEV = 56' ~'"" ~,.~=~.~,. ?reposed Completion 3-1~ .' MAX. DEV. = 56 Deg. @ 6100' ~ ~ ,,=-,,, ~ ~ ~ ~ TEE: 4-1/16" / 5000 psi / CIW/Baker Act. / WELLHEAD: 13-5/8" / 5000 / FMC SSH big L- 80, CYt-E BTRS. HES 'HXO' SVL 1,522' (3.813" MIN. ID) I2498. I ,~ ~, W/SSSV MIN I.D. 2" , -- 4-1/2" 12.61b/ft 13 CrS0 VAMACE TBG , -- ~ 4-1/2x1-1/2" MMG GLM 9-5/8", 47#/ft NTS0S xo to NT 95HS I I ~ ~ 9-5/8" baker s-3 PaCkEr I I i 9-5/8"x7" BAKER FLEXLOCK LINER HANGER + LTP AT 10000' ~ 8-1/2" HOLE x 4-1/2" LINER ~ ~ ~ 13CR HYDRIL 563 LINER SECTION MILL 50' WINDOW KICKOFF CMT PLUG AT 10166' ~ , , t TD 13780'MD, 10330'TVD 10t~o NOTE: Section window in 9-5/8" csg. from 10500'-10550' -- ' & 2-7/8" ST-L Seal Assemb}y i~ ~i 2-7/8" 6.4#/ft. ST-Liner I"~~ 2-7/8" Model Mbridge 12878' PBTD 12940'I ~~, plug (HES) 12903' 2-7/8" Float Shoe 13010' I~, DATE REV. BY COMMENTS ENDICOTT WELL 3-17E/K-30 8/20/2002 FJ Proposed Completion APl NO: 50-029-21946-05 11/14/02 WQ Proposed Completion COMPLETION DIAGRAM BP £XPLOR~TION, INC. ~J Z Z Well Compliance Report File on Left side of folder 198-208-0 DUCK IS UNIT SDI 3-17D/M31 50- 029-21946-04 BP EXPLORATION (ALASKA) INC Roll #1: Start: Stop Roll #2: Start Stop MD 13010 TVD 10146 Completion Date: .__1..9~2_9L9_8 Completed Status: J__-Q_[L_ Current: .................... Name Interval Sent Received T/C/D D 8741 6-15 SPERRY GR OH 11/11/98 11/12/98 L DGR-MD 6-15 10644-13010 OH 11/11/98 11/12/98 L DGR-TVD 6-15 8183-10145 OH 11/11/98 11/12/98 L DLL FINAL 11165-12985 OH 11/11/98 11/13/98 L SLIM-CN/LDT FINAL 11165-12985 OH 11/11/98 11/13/98 L SLIM-CNL FINAL 11165-12985 OH 11/11/98 11/13/98 L SSTVD FINAL 11165-12985 OH 11/11/98 11/13/98 R SRVYRPT SPERRY 11149.17-13010. OH 11/25/98 11/27/98 Daily Well Ops _____ ---- _ ...... Are Dry Ditch Samples Required? yes~ And Received? yes no Was the well cored? yes no Analysis Description Received. ye~o/ Sample Set # Comments: Wednesday, November 08, 2000 Page 1 of 1 STATE OF ALASKA Al_ASKs:} '"'L AND GAS CONSERVATION COMMISSI~,~' ',. REPORT SUNDRY WELL OPE ATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.oe, Alaska 99519-6612 4. Location of well at surface 2755' NSL, 799 WEL, SEC. 8, T11N, R17E. UM At top of productive interval 3336' NSL, 1415' WEL, SEC., 5, T11N, R17E, UM At effective depth 3328' NSL, 1451' WEL, SEC., 5, T11N, R17E, UM At total depth 3324' NSL, 1503' WEL, SEC. 5, T11N, R17E, UM 5. Type of Well: Development .. Exploratory __ Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-17DIM-31 9. Permit number/approval number 98-208 10. APl number 50- 029-21946-04 11. Field/Pool Duck Island Unit/Endicott 12. Present well condition summary Total depth: measured true vertical 13010 feet 10146 feet Plugs (measured) MBP plug set 12878' - 12903' Effective depth: measured true vertical 12878 feet Junk (measured) 10018 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 86' 30" Driven 142' 142' 2442' 13-3/8" 4185 C.F. Permafrost 2498' · 2439' 10444' 9-5/8" 575 c.f. Class 'G' 10500 8026' 188' 7" x 4-1/2" 218 C.F. Class 'G' 10312'- 10500' 7903'- 8026' 2706' 2-7/8" 127 c.f. Class 'G' 10304'- 13010' 7898'- 10090' measured 12756'- 12761'; 12852'- 12867'(OPEN); 12897- 12902'(Mechanically lsolated/Plugged) true vertical 9846'- 9851'; 9937'- 9952'( OPEN); 10130'- 10134' (Mechanically Isolated/Plugged) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10324' MD Packers and SSSV (type and measured depth) 9-5/8"packer TIW (HB-BP-T) @ I0266'; 4-1/2" x 2-7/8" Baker KB packer @ 10303'; 2-7/8"Baker Tie Back Sleeve @ 10698'; HES 'HXO' SVL wi SSSV @ 15,~,,~ ~.~.. ~[. 13. Stimulation or cement squeeze summary Add perforations (11/09/98) Intervals treated (measured) Perforate 12756'- 12761'; 12852'- 12867' (MD) Treatment description including volumes used and final pressure (see attached) 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure 117 n/a 5733 0 367 283 173 0 Tubing Pressure 452 344 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations X 16. Status of well classification as: Oil, X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed [ 'J~ CL.OL~ ~ .. Title Senior Technical Assistant IV [$62-$254) Date 12/01/98 I" Form 10-404 Rev 06/15'~8 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department Add Perforations DATE: 11/09/98 WELL N-°: 3-17d/M-31 BP EXPLORATION REP: Barba SERVICE COMPANY: SWS (Deckert) I DATE/TIME OPERATIONS SUMMARY I 0800 MIRU SWS SIWHP= 1400 lAP= OAP= 0830 Call for grease truck to service swab valve 1000 Hold safety meeting. 1015 Post signs & call for radio silence. 1030 Arm gun. 1045 Pressure test and RIH w/Gun #1 - G R/1-11/16" scallop gun (5'), CCL to TS 11.0' 1156 Log tie-in, pulling 2200 lbs of bottom. Note at 10100' up weight was 1300 lbs. 1205 Corrected -6' 1225 Parked CCL at 12745', shoot 12756-12761. Saw good indication 1230 Make Jewelry Log Pass and POOH. 1410 At surface 1500 Pressure test and RIH w/Gun #2 - 1-11/16" scallop gun (15'), CCL to TS 9.5'. 1625 Log tie-in, pulling 1900 lbs of bottom. 1630 Corrected -4'. TD tag 12903'. 1635 Parked CCL at 12842.5', shoot 12852-12867. Saw no indication. 1640 POOH. 1745 At surface 1800 Confirm all shot fired. Release radio silience 1815 POP well 1830 RDMO PERFORATION SUMMARY: GUN INTERVAL (DLL) FEET ZONE I 12756-12761 5 3A3 2 12852-12867 15 3A2 All intervals were shot using 1 11/16" scallop guns at 4 spf, 0 degree phasing and random orientation. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well J~] Oil J-'] Gas J--J Suspended [--J Abandoned J--J Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-208 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21946-04 4. Location of well at surface ...... ; ~ ~ ..'~ .... .... .~., 9. Unit or Lease Name 2755' NSL, 799' WEL, SEC. 8, T11N, R17E, UM iZ'__~ ~';':,../~ :~ Duck Island Unit/Endicott Z'_~/_z.o. ~--~.i , 10. Well Number At top of productive interval ,/_, ,..'r-.~;~ i~~ 3-17D/M-31 3328'At totaINSL'depth1473' WEb, SEC. 5, T11 N, R17E, UM t-~'"-'~-~. .... 11 Field and Pool 3324' NSL, 1503' WEb, SEC. 5, T11 N, R17E, UM ................. ............. ~.~,,,r; . · Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56'I ADb 047502 12' Pate'"~"Pudded. 9/25/98. ......... 113' Date T'D' ReaChed I 14: Date C°mp" Susp" °r Aband'115'"'Water depth~i! °ffSh°re 116' N°' °f C°mpleti°nsl 0/10/98 10/20/98 .................. - 12' MSL One 17. Total Depth (MD+'I:VD) 18. Plug Back Depth (MD+TVD) 19. Direc:~i0nal Survey 120. Depth w'i~e~.e sssv set 121. Thickness of Permafrost 13010 10146 FT 12878 10018 FT [~Yes [--]NoI 1522' MDI 1465' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, CDL/CNL/DLL/MLL/GR, GR/CCL ~3' CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Driv.e..Pipe.. Surface 142' Driven 13-3/8" 68# NTDOCYHE SurfaCe 2498' 17-1/2" 4185 c.f. Permafrost" 9-5/8" 47# NTDOS Surface 10500' 12-1/4" 575 c.f. Class 'G' 7" x 4-1/2" 12.6# L-80 10312' 10500' 6" 218 c.f. Class 'G' 2-7/8" 6.4# L-80 10304; 13010' 3-3/4" 127 c.f. Class 'G' 24. Perforations open to Produc~'i~n (MD+TVD ofT°p and' 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 1-11/16" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10324' 10266' MD TVD MD TVD ............................... 10312' 12897'-12902' 10037'-10041' 26' ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' · ................ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ..... Freeze protect with 8 bbls diesel 27. PRODUCTION TEST I,l~ ~ ~'"T ,e~" Date First Production I Method of OPeration (Flow ng, gas lift, etc.) ............................ October 21, 1998 I Gas Lift /~lal~310il ~ ~18 ~$' G01fltll~,,_ _,__ Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-McF WATER-BBb ' ,CHOKE SiZE TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAvITy-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lith°i0gy, porosity, fractures, apparent dips and presence of oil, gas or water. Sub'S'it core chips. L Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests .... Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. SBA1 12865' 10006' K2B 12874' 10014' 2800SB 12889' 10029' 2700F 12892' 10032' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby '~"ertify that the foregoing is true anti correct to the best of my knowledge Signed JeffHupp .; '- :, '/..~, Title TTRD Seni.o.[,Drilling Engineer . Date // · - 3-17DAv~__~-- v 98-208 Prepared By Name/Number: Kathy Campoamor, 564-5122 .. Well Numb'er ........... Permit No. / Ap, ,p,r,o, val,,N0. , ......................... INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevatiOn (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 15 Sep 98 16 Sep 98 17 Sep 98 18 Sep 98 19 Sep 98 20 Sep 98 21 Sep 98 Progress Report End SDI Well 3-17D/M-31 Page 1 Rig (null) Date 24 November 98 08:30-11:30 11:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-13:00 13:00-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-03:00 03:00-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-00:30 00:30-01:00 01:00-01:30 01:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-12:30 12:30-13:00 13:00-14:00 14:00-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-22:30 22:30-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-10:00 Duration 3hr 6-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 6-1/2 hr 1-1/2 hr 1 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 4-1/2 hr 3 hr 1/2 hr 3 hr 1 hr 5 hr 1 hr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 1-1/2 hr 3 hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1 hr 1/2 hr 4-1/2 hr 1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 4 hr 3-1/2 hr 1/2 hr 1 hr 1/2 hr 2 hr Activity Rig moved 90.00 % Rig waited: Orders Held safety meeting Rig waited: Orders Held safety meeting Rig waited: Orders Held safety meeting Rig waited: Orders Held safety meeting Rig waited: Orders Held safety meeting Rig waited: Orders Held safety meeting Rig waited: Production facilities Rigged up Additional services Skid rig Rig moved 100.00 % Held safety meeting Rigged up Drillfloor / Derrick Retrieved Hanger plug Retrieved Xmas tree Rigged up BOP stack Tested BOP stack Held safety meeting Retrieved Hanger plug Rigged up Bell nipple Conducted slickline operations on Slickline equipment - Tool run Ran Drillpipe to 1700.0 ft (2-3/8in OD) Circulated at 1700.0 ft Ran Drillpipe to 6320.0 ft (2-3/8in OD) Held safety meeting Ran Drillpipe to 11500.0 ft (2-3/8in OD) Circulated at 11500.0 ft Pulled out of hole to 1500.0 ft Circulated at 1500.0 ft Pulled out of hole to -0.0 ft Conducted electric cable operations Held safety meeting Conducted electric cable operations Serviced Top drive Ran Drillpipe to 10311.0 ft (2-3/8in OD) Circulated at 10330.0 ft Ran Drillpipe to 11500.0 ft (2-3/8in OD) Circulated at 11500.0 ft Pulled out of hole to 7551.0 ft Held safety meeting Pulled out of hole to -0.0 ft Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Held safety meeting Serviced Block line Serviced Top drive Rig waited: Equipment Facility Date/Time 22 Sep 98 23 Sep 98 24 Sep 98 25 Sep 98 Progress Report End SDI Well 3-17D/M-31 Rig (null) Page Date 10:00-16:30 16:30-17:30 17:30-19:00 19:00-19:30 19:30-21:30 21:30-22:00 22:00-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-11:00 11:00-18:00 18:00-18:30 18:30-19:00 19:00-21:30 21:30-01:30 01:30-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-08:30 08:30-10:00 10:00-10:30 10:30-11:30 11:30-12:00 12:00-13:00 13:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-21:00 21:00-00:30 00:30-01:00 0! :00-02:30 02:30-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-21:00 21:00-01:00 01:00-01:30 01:30-05:00 05:00-06:00 06:00-06:30 Duration 6-1/2 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 1/2 hr 4 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 7 hr 1/2 hr 1/2 hr 2-1/2 hr 4 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr 4 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2 hr 1/2 hr 1 hr 2-1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 4 hr 1/2 hr 3-1/2 hr 1 hr 1/2 hr Activity Ran Drillpipe to 11195.0 ft (2-3/8in OD) Pulled out of hole to 8899.0 ft Held safety meeting Held safety meeting Pulled out of hole to -0.0 ft Made up BHA no. 1 R.I.H. to 11176.0 ft · ""-.3 Milled Casing at 11177.5 ft Pulled out of hole to 3000.0 ft Held safety meeting Pulled out of hole to 18.0 ft Pulled BHA R.I.H. to 11174.0 ft Milled Casing at 11191.0 ft Held safety meeting Milled Casing at 11193.0 ft Reamed to 11193.0 ft Pulled out of hole to 21.0 ft Pulled BHA Ran Drillpipe to 11140.0 ft (2-3/8in OD) Serviced Block line Held safety meeting Circulated at 11170.0 ft Held safety meeting Injectivity test - 3.000 bbl injected at 1500.0 psi Mixed and pumped slurry - 12.000 bbl Pumped out of hole to 10607.0 ft Circulated at 10607.0 ft Pulled out of hole to 10417.0 ft Injectivity test - 3.500 bbl injected at 1500.0 psi Pulled out of hole to 2830.0 ft Held safety meeting Held safety meeting Pumped out of hole to -0.0 ft Made up BHA no. 3 R.I.H. to 10510.0 ft Washed to 10644.0 ft Drilled cement to 10775.0 ft Circulated at 10775.0 ft Drilled cement to 10975.0 ft Held safety meeting Drilled cement to 11077.0 ft Circulated at 11077.0 ft Drilled cement to 11176.0 ft Pulled out of hole to 4845.0 ft Held safety meeting Pulled out of hole to 128.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 11150.0 ft ,, Washed to 11176.5 ft Milled Casing at 11181.5 ft Circulated at 11181.5 ft Held safety meeting 2 24 November 98 Facility Date/Time 26 Sep 98 27 Sep 98 28 Sep 98 29 Sep 98 30 Sep 98 Progress Report End SDI Well 3-17D/M-31 Page 3 Rig (null) Date 24 November 98 06:30-09:30 09:30-10:00 10:00-10:30 10:30-13:30 13:30-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-20:30 20:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-17:00 17:00-18:00 18:00-18:15 18:15-18:30 18:30-19:00 19:00-06:00 06:00-06:30 06:30-07:00 07:00-17:00 17:00-17:15 17:15-17:30 17:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-21:30 21:30-22:00 22:00-22:30 22:30-00:00 00:00-01:00 01:00-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-11:30 11:30-12:30 12:30-13:30 13:30-14:00 14:00-15:30 15:30-18:00 18:00-18:30 18:30-06:00 Duration 3hr 1/2 hr 1/2 hr 3 hr 1/2 hr 1 hr 3hr 1/2 hr 2 hr 9-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 10hr 1 hr 1/4 hr 1/4 hr 1/2 hr llhr 1/2 hr 1/2 hr 10hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 4-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3 hr 1 hr 1 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 11-1/2 hr Activity Pulled out of hole to 115.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 5 R.I.H. to 9599.0 ft Held safety meeting R.I.H. to 11181.0 ft Drilled to 11212.0 ft Held safety meeting Drilled to 11297.0 ft Held safety meeting Drilled to 11368.0 ft Held safety meeting Circulated at 11368.0 ft Drilled to 11423.0 ft Circulated at 11423.0 ft Pulled out of hole to 11.170.0 ft R.I.H. to 11423.0 ft Held safety meeting Drilled to 11525.0 ft Held safety meeting Circulated at 11525.0 ft Drilled to 11615.0 ft Pulled out of hole to 11174.0 ft R.I.H. to 11615.0 ft Drilled to 11619.0 ft Held safety meeting Drilled to 11720.0 ft Held safety meeting Drilled to 11838.0 ft Held safety meeting Drilled to 11848.0 ft Pulled out of hole to 11170.0 ft Serviced Top drive R.I.H. to 11848.0 ft Tested MWD - Via string Circulated at 11848.0 ft Circulated at 11848.0 ft Pulled out of hole to 128.0 ft Pulled BHA Held safety meeting Made up BHA no. 16 Tested MWD/LWD - Via string R.I.H. to 9568.0 ft Serviced Block line R.I.H. to 11580.0 ft Took MWD survey at 11580.0 ft Logged hole with LWD: Formation evaluation (FE) from 11700.0 ft to 11848.0 ft Drilled to 11868.0 ft Held safety meeting Drilled to 11960.0 ft Facility Date/Time 01 Oct 98 02 Oct 98 03 Oct 98 04 Oct 98 05 Oct 98 End SDI Progress Report Well 3-17D/M-31 Rig (null) Page Date Duration Activity 06:00-06:30 06:30-07:30 07:30-13:30 13:30-14:00 14:00-14:15 14:15-17:15 17:15-17:30 17:30-18:00 18:00-18:30 18:30-00:00 00:00-06:00 06:00-06:30 06:30-17:30 17:30-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-01:15 01:15-01:30 01:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-08:30 08:30-09:00 09:00-18:00 18:00-18:30 18:30-19:30 19:30-01:30 01:30-02:00 02:00-02:15 02:15-02:30 02:30-05:00 05:00-06:00 06:00-06:30 06:30-09:15 09:15-09:30 09:30-10:30 10:30-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-03:30 03:30-04:00 04:00-04:15 04:15~04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-10:00 10:00-10:30 10:30-11:00 11:00-12:00 1/2 hr 1 hr 6 hr 1/2 hr 1/4 hr 3 hr 1/4 hr 1/2 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr llhr 1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 3/4 hr 1/4 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 9 hr 1/2 hr 1 hr 6 hr 1/2 hr 1/4 hr 1/4 hr 2-1/2 hr 1 hr 1/2 hr 2-3/4 hr 1/4 hr 1 hr 7-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 6 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 1 hr Held safety meeting Drilled to 11962.0 ft Pulled out of hole to 130.0 ft Pulled BHA Retrieved Wear bushing Tested All functions Installed Wear bushing Made up BHA no. 17 Held safety meeting R.I.H. to 11962.0 ft Drilled to 11996.0 ft Held safety meeting Drilled to 12007.0 ft Pulled out of hole to 11800.0 ft Held safety meeting Pulled out of hole to 137.0 ft Pulled BHA Made up BHA no. 18 Tested M.W.D. tool - Via string R.I.H. to 11150.0 ft Held safety meeting R.I.H. to 11583.0 ft Took MWD survey at 11.583.0 ft R.I.H. to 11993.0 ft Took MWD survey at 11993.0 ft Washed to 12007.0 ft Drilled to 12066.0 ft Held safety meeting Circulated at 12066.0 ft Pulled out of hole to 137.0 ft Pulled BHA Made up BHA no. 19 Tested MWD - Via string R.I.H. to 8000.0 ft Serviced Block line Held safety meeting R.I.H. to 11585.0 ft Took MWD survey at 11585.0 ft R.I.H. to 12066.0 ft Drilled to 12114.0 ft Held safety meeting Drilled to 12125.0 ft Circulated at 12125.0 ft Pulled out of hole to 137.0 ft Pulled BHA Made up BHA no. 20 Tested MWD - Via string R.I.H. to 4800.0 ft Held safety meeting R.I.H. to 11150.0 ft Serviced Top drive R.I.H. to 11583.0 ft Took MWD survey at 11583.0 ft R.I.H. to 12125.0 ft 4 24 November 98 Facility Date/Time 06 Oct 98 07 Oct 98 08 Oct 98 09 Oct 98 10 Oct 98 11 Oct 98 End SDI Progress Report Well 3-17D/M-31 Rig (null) Page Date Duration Activity 12:00-18:00 18:00-18:30 18:30-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-13:00 13:00-14:00 14:00-14:45 14:45-15:00 15:00-17:30 17:30-18:00 18:00-18:30 18:30-21:30 21:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-03:00 03:00-03:30 03:30-03:45 03:45-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-07:45 07:45-08:00 08:00-09:00 09:00-10:00 10:00-10:30 10:30-11:00 11:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-20:00 20:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-14:30 14:30-16:00 16:00-18:00 18:00-18:30 18:30-00:30 00:30-01:30 6 hr 1/2 hr 9hr 1-1/2 hr 1 hr 1/2 hr 6-1/2 hr 1 hr 3/4 hr 1/4 hr 2-1/2 hr 1/2 hr 1/2 hr 3 hr 8-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr 1/2 hr 1/4 hr 1/4 hr 2 hr 1/2 hr 1 hr 1/4 hr 1/4 hr 1 hr 1 hr 1/2 hr 1/2 hr 5-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 10hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 5 hr 1 hr 2 hr 1-1/2 hr 2 hr 1/2 hr 6 hr 1 hr Drilled to 12193.0 ft Held safety meeting Drilled to 12228.0 ft Circulated at 12228.0 ft Pulled out of hole to 11150.0 ft Held safety meeting Pulled out of hole to 137.0 ft Pulled BHA Made up BHA no. 21 Tested MWD - Via string R.I.H. to 5700.0 ft Serviced Top drive Held safety meeting R.I.H. to 12228.0 ft Drilled to 12330.0 ft Held safety meeting Drilled to 12443.0 ft Held safety meeting Drilled to 12455.0 ft Circulated at 12455.0 ft Pulled out of hole to 137.0 ft Pulled BHA Retrieved Wear bushing Installed BOP test plug assembly Tested All functions Held safety meeting Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Repaired Draw works Made up BHA no. 22 Tested MWD - Via string Serviced Top drive R.I.H. to 11150.0 ft Serviced Block line R.I.H. to 11450.0 ft Held safety meeting R.I.H. to 11772.0 ft Took MWD survey at 11772.0 ft R.I.H. to 12455.0 ft Drilled to 12635.0 ft Held safety meeting Drilled to 12800.0 ft Held safety meeting Drilled to 12935.0 ft Held safety meeting Drilled to 13010.0 ft Circulated at 13010.0 ft Pulled out of hole to 11150.0 ft R.I.H. to 13010.0 ft Circulated at 13010.0 ft Held safety meeting Pulled out of hole to 179.0 ft Pulled BHA 5 24 November 98 Facility Date/Time 12 Oct 98 13 Oct 98 14 Oct 98 End SDI Progress Report Well 3-17D/M-31 Rig (null) Duration Activity 01:30-02:00 02:00-06:00 06:00-06:30 06:30-07:00 07:00-13:30 13:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-22:45 22:45-23:00 23:00-23:15 23:15-23:30 23:30-00:15 00:15-00:30 00:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-10:30 10:30-12:00 12:00-13:30 13:30-17:30 17:30-18:30 18:30-20:00- 20:00-20:30 20:30-01:30 01:30-02:30 02:30-03:30 03:30-06:00 06:00-06:30 06:30-13:30 13:30-14:30 14:30-16:00 16:00-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-00:30 00:30-01:30 01:30-02:00 02:00-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-12:30 12:30-13:30 13:30-14:00 14:00-15:00 15:00-17:00 17:00-19:30 19:30-20:00 1/2 hr 4 hr 1/2 hr 1/2 hr 6-1/2 hr 2 hr 1/2 hr 2hr 1/2 hr 3-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 1/4 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4 hr 1-1/2 hr 1-1/2 hr 4 hr 1 hr 1-1/2 hr 1/2 hr 5 hr 1 hr 1 hr 2-1/2 hr 1/2 hr 7 hr 1 hr 1-1/2 hr 2 hr 1/2 hr 3-1/2 hr 1/2 hr 2 hr 1 hr 1/2 hr 4 hr 1/2 hr 2-1/2 hr 1 hr 2-1/2 hr 1 hr 1/2 hr 1 hr 2 hr 2-1/2 hr 1/2 hr Rigged up Logging/braided cable equipment Conducted electric cable operations Held safety meeting Made up BHA no. 23 R.I.H. to 13010.0 ft Circulated at 13010.0 ft Flow check Pulled out of hole to 11100.0 ft Held safety meeting Pulled out of hole to 108.0 ft Pulled BHA Retrieved Wear bushing Installed BOP test plug assembly Installed BOP stack Tested Top ram Rigged up Casing handling equipment Held safety meeting Ran Liner to 2312.0 ft (2-7/8in OD) Circulated at 2312.0 ft Ran Liner on landing string to 5000.0 ft Held safety meeting Ran Liner on landing string to 11150.0 ft Circulated at 11150.0 ft Ran Liner on landing string to 13010.0 ft Circulated at 13010.0 ft Mixed and pumped slurry - 22.000 bbl Circulated at 10698.0 ft Held safety meeting Pulled Drillpipe in stands to -0.0 ft Rigged up Top ram Serviced Block line Wait on cement Held safety meeting Wait on cement Tested Liner Ran Casing to 398.0 ft (2-7/8in OD) Ran Drillpipe in stands to 3700.0 ft Held safety meeting Ran Drillpipe in stands to 10698.0 ft Tested Liner Circulated at 10698.0 ft Tested Liner Functioned Retrievable packer Laid down 7000.0 ft of 2-3/8in OD drill pipe Held safety meeting Laid down 3000.0 ft of 2-3/8in OD drill pipe Ran Drillpipe in stands to 4250.0 ft Laid down 3750.0 ft of 2-3/8in OD drill pipe Freeze protect well - 8.000 bbl of Diesel Laid down 500.0 ft of 2-3/8in OD drill pipe Installed Hanger plug Removed BOP stack Held safety meeting Held safety meeting Page Date 6 24 November 98 Facility Date/Time 15 Oct 98 End SDI Progress Report 20:00-22:00 22:00-00:30 00:30-01:30 01:30-02:00 02:00-04:00 04:00-06:00 Duration 2 hr 2-1/2 hr 1 hr 1/2 hr 2 hr 2 hr Well 3-17D/M-31 Rig (null) Activity Removed BOP stack Installed Xmas tree Retrieved Hanger plug Installed Hanger plug Rigged down Drillfloor / Derrick Skid rig Page Date 7 24 November 98 BPX Endicott Production Engineering Department Initial Perforations DATE: 10/20/98 WELL N°: 3-17d/M-31 BP EXPLORATION REP: Varble SERVICE COMPANY: SWS (Palmer) DATE/TIME OPERATIONS SUMMARY 0930 MIRU SWS SIP=900 lAP=500 OAP=0 1030 Hold safety meeting. 1040 Post signs & call for radio silence. 1045 Arm ~lun. 1100 RIH w/Gun - GR/1-11/16" enerjet (strip) gun (5') 1210 In liner. Bleed whp down to 250 psi. 1217 Log tie in pass. Tie into DLL dated 10/11/98. Take out 20'. 1223 RIH & log confirmation pass. Add 7'. 1230 Re-log. Add 1' 1245 Re-log. On depth. TD = 12903'. Will be shooting just off bottom. 1305 Log into place & hang CCL @ 12891.5' md. (5.5' from CCL to top shot) 1310 Shoot gun from 12897'-12902' md. No indication that gun fired. 1313 Log off. 1317 POOH. SUMMARY: Initial Pedorations after TTRD Sidetrack Gun Run Interval Perforated Lenqth Gun Type Density Phasing I 12,897' - 12902' 5' 1-11/16" Enerjet 4 spf 0 deg. Attempted to log static survey after perforating, but had computer problems. Rigged down SWS and logged static survey with slickline conveyed memory gauges. BPX Endicott Production Engineering Department SET MBP DATE: 11117-18198 WELL N°: 3-17diM-31 BP EXPLORATION REP' VARBLE SERVICE COMPANY: SWS (CYCA) HES (WILLIAMS) I DATE/TIME OPERATIONS SUMMARY 0900 MIRU SWS FWHP=375 IAP=1800 OAP=0 0930 Shut off G/L. 1000 Swab leaking. Call for grease truck. 1030 Swab fixed. Continue R/U. 1100 Hold safety meeting. 1115 Call for radio silence. 1125 Arm 1-11/16" multi-stage setting tool. 1150 RIH w/GR-CCL / 12' weight bar/MS setting tool & 2-7/8" model M bridge plug. OAL = 30' 1310 CCL quit @ approx. 6350'. Stop & trouble shoot. 1330 Unable to fix. POOH. 1445 OOH. Short in 1 weight bar. Take out. Test all tools. Re-arm setting tool. 1530 RIH w' same - 1 weight bar. OAL = 24' 1700 Ran thru KB pkr @ 10303' md with no problems. 1740 Log tie in pass ~ 11600' md. Tie into DLL dated 10/11/98. Take out 16' 1800 Tag TD. @ 12903' md. Log off btm. On depth. 1810 RIH to TD. Tools became stuck on btm. Unable to come up hole. Pull 2500 #'s. Work wire while pulling up to 2500-2600#'s (weak point set @ ~ 2900 #'s) 1830 Unable to work tools free. Opt to set plug instead of pulling out of cable head. 1840 Pull 1400 #'s & shoot. 1850 Still stuck. Not sure if toolstring is stuck or if plug did not set. 1900 Pull up to 3400 #'s. (max pull on line) Unable to pull out of cable head. Work wire hard while pulling up to 3400 #'s. No luck. 2000 Flow well to try & free up tools. No luck. Work wire while flowing well. No luck. 2045 Shut in well & pull 3400 #'s for 1 hr. No luck. 2145 Re-group & discuss options. ( cutter bar or pump down tbg.) 2215 Opt to pump down tbg. with dead crude. Will wait until morning. 2300 Secure well & leave 2 men on unit to watch well & equipment. 11/18 0930 MIRU HB&R. PIT hardline. Stand by for crude. SIP- 1500 lAP = 1700 lAP- 0. 1015 Start pumping dead crude down tbg. @ 4 bpm, 1700 psi. 1035 45 bbls away, work wire. 1045 74 bbls away, tools came free. Shut down pump & POOH. (may still have plug) 1200 Stop @ 3000' & stand by for HES Rep. to arrive. 1215 HES rep. on location. Call for radio silence. 1220 Hold safety meeting. 1225 POOH. 1255 OOH. 1305 Plug is gone. Setting tool fully stroked. No visible s~gns of why tools were stuck. 1330 Decide to run another plug. Re-head with lower weak point. & set up plug # 2. 15OO 1505 1525 1720 1745 1752 1800 1915 1930 Hold safety meeting. Arm setting tool. RIH w/GR-CCL / 6' weight bar / M S setting too & 2-7/8" model M bridge plug. OAL = 30' SHIWHP = 1100 psi. Log tie m pass ~ 11600' md. Tie into DLL dated 10/11/98. Add 18'. Stop @ 12875' elm. Pull up to 12873' elm. (17' from CCL to plug element) Should put plug @ 12890' md. Fire setting tool. No weight change. POOH & log off. (Tie in depth after logging off puts plug @ 12878' md.) OOH. Plug set. POP to FOC & request well test ASAP. SUMMARY: Plug became stuck on btm.(TD, 12903' md.) while attempting to tie in. Choose to set plug instead of pulling out of cable head. Still stuck after setting plug. Unable to pull out of cable head (due to sever doglegs?) Attempted to free tools by flowing well. Unsuccessful. Pumped 75 bbls crude down tbg @ 4 bpm. Tools came free. No visible indications on tools as to why we were stuck. Ran plug # 2 and set @ ~ 12878' md. Did not log off btm. to tie in due to problems encountered on first attempt. No difficulties setting plug # 2. Endicott Alaska State Plane Zone 3 Endicott SD! 3-17D/M-31 Job No. AKMW80251, Surveyed: 10 October, 1998 S UR VEY REPORT ORIGINAL 20 November, 1998 Your Ref: API-500292194603 KBE- 54.95' Surface Coordinates: 5970973.83 N, 270243.36 E (70° 19'20.3471" N, 147° 51'46.9665" Vt/) DRILLING SERVICE=. Survey Reft svy546 Endicott Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for 3-17D/M-31 Your Ref: API-500292194603 Job No. AKMWS0251, Surveyed: 10 October, 1998 11149.17 22.220 290.160 8566.18 8621.13 11174.00 21.710 285.630 8589.21 8644.16 11193.80 26.250 282.380 8607.30 8662.25 11223.55 30.160 278.450 8633.51 8688.46 11254.60 30.560 275.200 8660.30 8715.25 11288.15 31.830 272.380 8689.01 8743.96 11319.44 36.140 270.220 87t4.95 8769.90 11351.53 42.310 268.350 8739.79 8794.74 11381.03 45.940 267.650 8760.97 8815.92 11413.97 47.970 268.480 8783.45 8838.40 11446.12 46.780 267.980 8805.22 8860.17 11476.58 45.870 267.100 8826.25 8881.20 11506.08 46.740 263.710 8846.64 8901.59 11538.98 46.760 263.750 8869.18 8924.13 11571.51 48.950 260.210 8891.01 8945.96 11601.73 48.260 259.820 8910.99 8965.94 11633.50 47.650 258.700 8932.27 8987.22 11664.89 49.190 264.280 8953.11 9008.06 11694.44 49.150 268.000 8972.43 9027.38 11728.72 48.590 267.180 8994.98 9049.93 11759.37 48.120 265.740 9015.35 9070.30 11788.59 46.240 265.530 9035.21 9090.16 11822.80 44.630 266.830 9059.22 9114.17 11854.91 43.910 268.850 9082.21 9137.16 11884.42 41.980 271.300 9103.81 9158.76 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5842.83 N 281.57 E 5976805.30 N 270703.67 E 5845.69 N 272.74 E 5976808.43 N 270694.93 E 5847.61N 264.93 E 5976810.59 N 270687.19 E 5850.12 N 251.11E 5976813.52 N 270673.44 E 5851.98 N 235.53 E 5976815.86 N 270657.93 E 5853.12 N 218.19 E 5976817.53 N 270640.64 E 5853.50 N 200.71E 5976818.44 N 270623.18 E 5853.23 N 180.43 E 5976818.79 N 270602.90 E 5852.51N 159.91E 5976818.70 N 270582.37 E 5851.70 N 135.86 E 5976818.63 N 270558.29 E 5850.97 N 112.21 E 5976818.62 N 270534.64 E 5850.02 N 90.20 E 5976818.35 N 270512.61 E 5848.31 N 68.95 E 5976817.29 N 270491.31 E 5845.69 N 45.13 E 5976815.40 N 270467.42 E 5842.32 N 21.25 E 5976812.76 N 270443.46 E 5838.39 N 1.07W 5976809.51N 270421.02 E 5833.99 N 24.25W 5976805.83 N 270397.72 E 5830.53 N 47.46W 5976803.08 N 270374.42 E 5829.03 N 69.76W 5976802.26 N 270352.08 E 5827.94 N 95.56W 5976801.97 N 270326.26 E 5826.53 N 118.42W 5976801.25 N 270303.37 E 5824.90 N 139.78W 5976800.28 N 270281.96 E 5823.27 N 164.10W 5976799.40 N 270257.61 E 5822.42 N 186.50W 5976799.23 N 270235.20 E 5822.44 N 206.60W 5976799.87 N 270215.11E Alaska State Plane Zone 3 Endicott SDI Dogleg Rate (°/100ft) 7.125 23.872 14.544 5.444 5.768 14.303 19.575 12.415 6.432 3.874 3.646 8.816 0.107 10.507 2.480 3.247 14.170 9.525 2.432 3.831 6.456 5.429 4.930 8.646 Vertical Section (ft) Comment -29.50 -20.56 -12.68 1.25 16.89 34.26 51.74 71.99 92.46 116.46 140.05 162.00 183.16 206.84 230.55 252.68 275.65 298.69 32O.90 346.63 369.41 390.69 414.91 437.25 457.33 Tie-on Survey Window Point Continued... 20 November, 1998 - 15:17 - 2 - Dr#/Quest Endicott Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for 3-17D/M-31 Your Ref: API-500292194603 Job No. AKMW80251, Surveyed: 10 October, ~998 11917.64 40.300 272.180 9128.83 9183.78 11949.25 37.900 271.810 9153.36 9208.31 11987.07 35.970 273.440 9183.59 9238.54 12019.26 35,360 276.270 9209.74 9264.69 12049.74 37.120 282.730 9234.33 9289.28 12079.10 40.030 283.490 9257.28 9312.23 12112.86 42.810 285.180 9282.60 9337.55 12144.92 42,930 285.760 9306.10 9361,05 12174.67 42,390 286.160 9327.97 9382.92 12208,85 41.580 287.810 9353.38 9408.33 12240.84 38.560 285.040 9377.86 9432.81 12270.59 35.420 279.770 9401.63 9456.58 12301.39 33.040 276.300 9427.09 9482.04 12333.73 28.810 275.720 9454.83 9509.78 12364.86 24.770 277.510 9482.61 9537.56 12397.20 22.710 278.450 9512.21 9567.16 12439.82 22.410 277.250 9551.57 9606.52 12471.09 21.730 271.720 9580.55 9635.50 12500.35 20,840 269.700 9607.82 9662.77 12534.48 19,940 266,980 9639.81 9694.76 12564.56 20.300 261.030 9668.06 9723.01 12594.07 20.880 259.410 9695.68 9750.63 12627.51 21.710 258.320 9726.84 9781.79 12660.74 21.990 256.350 9757.68 9812.63 12687.33 21.020 256.560 9782.42 9837.37 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5823.10 N 228.44W 5976801.20 N 270193.29 E 5823.80 N 248.36W 5976802.50 N 270173.40 E 5824.83 N 271.06W 5976804.23 N 270150.74 E 5826.42 N 289.76W 5976806.39 N 270132.10 E 5829.41N 307.51W 5976809.92 N 270114.46 E 5833.56 N 325.33W 5976814.62 N 270096.77 E 5839.10 N 346.97W 5976820.82 N 270075.31E 5844.92 N 367.99W 5976827.28 N 270054.48 E 5850.46 N 387.37W 5976833.41N 270035.28 E 5857.14 N 409.24W 5976840.75 N 270013.62 E 5862.97 N 428.98W 5976847.19 N 269994.07 E 5866.85 N 446.44W 5976851.59 N 269976.74 E 5869.28 N 463.58W 5976854.55 N 269959.68 E 5871.03 N 480.11W 5976856.80 N 269943.21 E 5872.63 N 494.04W 5976858.83 N 269929.33 E 5874.43 N 506.94W 5976861.03 N 269916.50 E 5876.66 N 523.13W 5976863.76 N 269900.38 E 5877.59 N 534.83W 5976865.04 N 269888.71 E 5877.73 N 545.45W 5976865.50 N 269878.10 E 5877.39 N 557.34W 5976865.52 N 269866.22 E 5876.30 N 567.61W 5976864.76 N 269855.91 E 5874.54 N 577.84W 5976863.31N 269845.63 E 5872.19 N 589.75W 5976861.32 N 269833.65 E 5869.48 N 601.82W 5976858.98 N 269821.51E 5867.20 N 611.29W 5976856.99 N 269811.97 E Alaska State Plane Zone 3 Endicott SDI Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 5.349 479.18 7.628 499.12 5.722 521.84 5.465 540.59 13.789 558.45 10.042 576.44 8.875 598.29 1.286 619.54 2.031 639.14 4.005 661.28 10.961 681.25 14.992 698.86 9.991 716.10 13.112 732.68 13.233 746.67 6.476 759.63 1.289 775.91 6.989 787.64 3.941 798.25 3.829 810.11 6.906 820.33 2.755 830.47 2.750 842.27 2.362 854.21 3.659 863.58 Continued... 20 November, 1998 - 15:17 - 3 - Dr#/Quest Sperry-Sun Drilling Services Survey Report for 3-17D/M-31 Your Ref: API-500292194603 Job No. AKMWS0251, Surveyed: 10 October, 1998 Endicott Measured Sub.Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 12723.67 20.740 256.350 9816,37 9871.32 12754.74 19.330 254.870 9845.56 9900.51 12783.29 18.420 256.250 9872,58 9927.53 12816.08 17.460 257.250 9903.77 9958.72 12847.38 16.090 260.290 9933.74 9988.69 12877.57 15.200 262.090 9962.81 10017.76 12910,37 15.170 262.600 9994.47 10049,42 12943.84 14.960 263,720 10026.79 10081.74 12965.56 15.090 262.320 10047.76 10102.71 13010.00 15.090 262.320 10090.67 10145.62 5864.16 N 623.89W 5976854,34 N 269799.29 E 5861.52 N 634.20W 5976852.02 N 269788.90 E 5859,22 N 643.14W 5976849.99 N 269779.90 E 5856.90 N 652.97W 5976847,97 N 269770.00 E 5855.13 N 661.83W 5976846.48 N 269761.09 E 5853.88 N 669.87W 5976845.47 N 269753.01 E 5852,74 N 678.38W 5976844.59 N 269744.47 E 5851.70 N 687.02W 5976843.82 N 269735.80 E 5851.02 N 692.61W 5976843.31N 269730.20 E 5849.47 N 704.07W 5976842.11 N 269718.69 E All data is in feet unless otherwise stated. Directions and coordinates are relative to Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 28.393° (20-Sep-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 272.470° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 13010.00ft., The Bottom Hole Displacement is 5891.69ft., in the Direction of 353.137° (True). True North. Alaska State Plane Zone 3 Endicott SDI Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.798 4.822 3.550 3.075 5.196 3.358 0.417 1.072 1.775 0.000 876.03 886.22 895.05 904.77 913.54 921.53 929.98 938.57 944.12 955.51 Projected Survey Continued... 20 November, 1998.15:17 - 4 - Dri/IQuest Endicott Sperry-Sun Drilling Services Survey Report for 3-17D/M-31 Your Ref: API-500292194603 Job No, AKMW80251, Surveyed: 10 October, 1998 Alaska State Plane Zone 3 Endicott SDI Commen ts Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11149.17 8621.13 5842.83 N 281.57 E 11174.00 8644.16 5845.69 N 272.74 E 13010.00 10145.82 5849.47 N 704.07 W Comment Tie-on Survey Window Point Projected Survey 20 November, 1998 - 15:17 -5- DrillQuest spe u-sun D rill Q u e s [ DFIILI-ING S E I::! V I (~ EE S · ~(, tsl~,,, cd- c~s(! ~L, C,4 ~ij[~, Endicott Eastings Alaska State Plane Zone 3 Scale: lcm = 500ft Endicott SDI -50o 0 _ . I 3-17D/M-31 ~_,7~.,,-3, 0 Projected Survey ~ ~ 5500 Window/~Point Tie-r,n Survey 900 -- -- 5000 i 1800 -- -- 4500 2700 I -- ' 4000 I 3600 -- '--- 3500 , roe) ~ 4500 _i ' 3000 r- ~ 5400 _t -- 2500 ,-- }-- 6300 -- -- 2000 , 7200 --~ -- 1500 I Tie-/n Survey 8100 -- -- 1000 ~ 9000- ',, Window Point -- 500 , II '-- 9900- ?. " 0 ~ ~ ~----Projected Survey 0 900 Scale: 1cra ~ 900ft Section Azimuth: 272.470° (True ~0rth) Vertical Section .Prepared: JOhecked: jApproved: 11/11/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12047 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Endicott (Open Hole) Well Job # Log Description Date BL Sepia LIS Tape 3-17D/M-31 -'~.-~toz~ 98535 SLIM CNT,SDN,DLL (PDC) 98535 1 3-17D/M-31 ' 98535 SLIM DLL 98535 1 I 3-17D/M-31 98535 SLIM CNL 98535 1 1 3-17D/M-31 98535 SLIM CNL/LDT 98535 1 1 3-17D/M-31 98535 SSTVD 98535 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Bird Anchorage, AK 99503 WELL LOG TRANSMITTAL To: State of Alaska .alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine St. .anchorage, Alaska 99501 MWD Formation Evaluation Logs 3-17D / M-31, November 11. 1998 "" .AK-MM-80251 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3-17D / M-31: 2" x 5" MD Gamma Rav Logs: 50-029-21946-04 2" x 5" TVD Gamma Ray Logs: 50-029-21946-04 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 November 11. 1998 MWD Formation Evaluation Logs - 3- t 7D / M-31, AK-MW-80251 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of". .~di Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG fbrmatted Disc with verification listing. API#: 50-029-21946-04 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLE$, GOVERNOR ALASKA OIL ~D GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 16, 1998 Dave Cocking Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island 3-17D/M-31 BP Exploration (Alaska) Inc. Permit No: 98-208 Sur Loc: 2755'NSL, 799'WEL, Sec. 8, T1 IN, R17E, UM Btmhole Loc. 3343'NSL, 1510'WEL, Sec. 5, T1 IN, R17E, UM Dear Mr. Cocking: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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 detenuinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chaim~an ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. K/~" STATE OF ALASKA i" ALAS ,.,IL AND GAS CONSERVATION CON,~vIISSION PERMIT TO DRILL 20 AAC 25.005 REVISED 10101198 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] DevelOpment Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator '5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL047502 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2755' NSL, 799' WEL, SEC. 8, T11N, R17E, UM Duck Island~ At top of productive interval 8. Well Number ~-~ I ~.~4~"''- Number 2S100302630-277 3352' NSL, 1462' WEL, SEC. 5, T11N, R17E, UM ~-~?~ ;3-t-7-~/M-31 At total depth 9. Approximate spud date Amount $200,000.00 3343' NSL, 1510' WEL, SEC. 5, T11 N, R17E, UM 09/18/98 12".' Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) .... ADL 047503,1510'I No Close Approach 2560 12899 MD / 9950' 'FVDSS 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 11200' MD Maximum HoleAn,qle 53° Maximum surface 3941 psig, At total depth (TVD) 9590'/4900 psig 18. Casing Program Setting Depth Size Specifications Top . Bottom Quantity of Cement "iLl'(~le Casing weight Grade Coupling Length MD TVD, ~ ~ 'iinclude stage data) " 3-3/4" 2-7/8" 6.4# L-80 STL 2199' 10700' 8206' { -In?nn, ~ 1-02 SX class 'G' ' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~i~ r. ~ [,,. i ¥ i. ~ Present well condition summary Total depth: measured 13138 feet Plugs (measured) 0C'E ~5 true vertical 10079 feet Effective depth: measured 12111 feet Junk (measured) true vertical 9492 feet ~lL0i~&G~lSC011$.~0tll~l'l~S~0~ Casing Length Size Cemented AIIStl0~D- TVD Structural Conductor 142' 30" Driven 142' 142' Surface 2498' 13-3/8" 4185 c.f. Permafrost 2498' 2496' Intermediate 10520' 9-5/8" 575 c.f. Class 'G' 10520' 8095' Production Liner 2844' 4-1/2" 218 c.f. Class 'G' 10338'-13182' 7976'-10079' Perforation depth: measured N/A ~),jt '~ f t~,~'''~'' .... ..... "~,, il ~--x !~f.~;X. i!/~.~"~ L true vertical N/A 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Chris West, 564-5089/~j Prepared By Name/Number: Carol Withey, 564-4114 Contact Engineer Name/Number: 21. I hereby certify that the for,ege~is t~ and correct to the best of my knowledge ,/ Signed'/',(~i~-~ 0//~/~ ' Dave Cocking Title Drilling Superintendent Date/. Commission Use Only ...... Permit Number I APl Number ~. ,Ai~proval Date I See cover letter 98-; ~- ~ ~ 50- O 2, ~ -- ,~, ~ c( ~ (~ - (~ J .-~,//~ ~ for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required []Yes Hydrogen Sulfide Measures [~Yes [] No Directional Survey Required [~Yesr"lNo Required Working Pressure for BOPE []2K; 1--13K; 1--14K; 1~SK; []10K; 1--115K Other: ~,~,"~!~na, l Signed By by order of Approved By RR',/id W, Johnston Commissioner the commission Date//~)--'/~' ---~ Form 10-401 Rev. 12-01-85 Submit In Triplicate 'FLEE: 4-~1/16'' / 5000 psi/CIW/Baker Acs, ..... ~ors 13-5/8" / 5000 psi / FMC S~ Jig Bore RT ELEV= 56' BF ELEV= 17.2 MAX. DEV. = 71 DEG. 13-3/8", 68#/ft, L-80 CYHE BU-I-I' CSG 4 1/2" L-80 IBM TBG. 12.6 #/FT 9-5/8", 47#/ft NT80S XO to NT95HS NOTE' SECTION WINDOW IN 9 5/8 CASING FROM 10500' -10550' 0312' I 7" ZXP BAKER LINER PKR 0338' 7" X 4.5" XO (3.875" ID) Proposed Top Whipstock 11176' Window f/11177-191' MD Propsed Whipstock packer @ 11 Cement Retainer @ 12111' Previous window @ 1219~MD PERFORATING SUMMARY Ref. Log CNL/GR 7/9/97 CO I' SW~ SW..c SWS AWS I SIZE I SPF I ; 2-7/81 6 2-7/8 I 6 2-7/8I 6 2-7/8 I 6 tINTERVAL 1281 ~2~- 12822' SQZ'D 2916-12931' SQZ'D 30861-13098' SQZ'D 3116-13136' SQZ'D 4..5 HYRIL 511 CASING 12.6 #/FT (3.958" ID) PBTD I 13164' TD i 13183' Date 7/10/97 7/28/97 DAV RAC Comments Initial Perfs & Completion ADD-PERFS SSSV LANDING NIPPLE HES "HXO" (3.813" ID) 522 4.5 X 1.5 CAMCO "'i'B" 9CR GLM'S. RA LATCHES CAMCO "TB" 9 CR t,~n 'l~ll~ 6 3620' 3504' 5 6326' 5253' 4 7936' 6291' 3 9009' 7009' 2 10031' 7711' I 10186' 7815' 4-1/2 .... X|1 NIPPLE 7 TIW HB-BP-T PACKER (3.935 ID) ~,-1/2 .... X" NIPPLE (HES) (3.813" ID) 4-1/2 .... XN" NIPPLE (HES) (3.725 ID) 4-1/2" WLEG 10255' 10266' 10291' 10311' [ 10324' ELMD 110326' I Proposed TD of ST C @ 12899' MD 9950' TVDss Sidetrack A Drld to 12870' md Sidetrack B Drld to 12738' md ENDICOTT WELL: 3-17b/M-31 APl NO: 50-029-21946-02 COMPLETION DIAGRAM CID I~VDI ADA?IAIkl fAI AC~VA~ il~l/''q IWell Name: 13-17c/M-31 Well Plan Summary IType of Well (Producer or injector): Well Design (Conventional, slimhole, etc.)' Producer q-FRD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 2755 798 8 11N 17E Tie in survey Location: 3313 516 5 11N 17E Target I Location' 3352 1462 5 11N 17E Bottom Hole Location: 3343 1510 5 11N 17E I AFE Number: 1 727026 ISeptember 18, 1998 IEstimated Start Date: I Rig: I DOYON 15 IOperating days to drill and complete: Formation Markers Well Bore: 12+3 Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =3941 psi TOP WEST SAK TOP SEABEE/AYLYAK KOP 11200' MD / 8612' TVDSS TOP SHALE WALL/TUFFS 11,578 8900 TOP HRZ 12,462 9540 BASE HRZ 12717 9779 PUT RIVER 12717 9779 LCU 12,727 9789 KEKIKTUK- Top Flow 1 12,705 9789 9.14 4900 psi @ 9590 TVDSS Top Flow 3A3C 12782 9840 Target K2B 12865 9918 8.82 TD 12899 9950 Logging Program: I Logs: 3.75" Hole Curve and Tangent Open Hole E-line Cased Hole: MWD-GR G R-Laterlog-Density E-line Perforating (after rig moves) Casing/Tubinc. Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVDSS 3.75 2.875" 6.4 L-80 S'I'L 2199 10700'/8206' 12899/9950 TBG* 4.5" 12.6 L-80 IBM 10286 38 10324/7960 Note: The existing tubing will be left in ~lace and re-used. 3-17c/M-31 Redrill Drilling Program- FINAL Directional Plan Cf WP10 TTRD 10/02/98 Page Cf3 Cementing Program g lo String job): Hole Section Liner Size Depth Volume Cement Production 2.875" Liner from Cement from _+ 17 BBL Class 'G' 10310' to 12899' 10700' 102 SX 0.45% Halad-344 with 2,875" x 4.5" to12899' Final vol. 0.2% CFR-3 tie back sleeve in Based on 0,25#/sk Super CBL 4.5" tubing actual TD HR-5 as required Mud Program: Production Mud Properties: 13.75" hole section' Inhibitive Clay Seal Depth Density Plastic Yield Tau 0 pH Fluid Flow Rate (PPG) Viscosity Point Loss Reservoir 10.5 <10 16 - 25 3 - 6 9.0-9.5 <4 85-95 Hazards/Concerns Pore pressure (__.9.14 - 9.76 ppg EMW) based on offset max SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. High circulating pressures of up to 4500 psig. Close annular clearance causing swab and surge pressures. Excessive Torque to be combated with lubricant additions after testing. Maintain YP of 12-14 #/100 sq ft to minimize ECD. WELLHEAD EQUIPMENT Casing Head: Casing Hanger: ITubinghead: X-mas Tree: McEvoy 13 3/8" X 13 5/8", 5M Flange SSH McEvoy Mandrel Hanger McEvoy 13 5/8",5M X 13 5/8", 5M Cameron 4-1/8",5M DIRECTIONAL STATS FOR 9 5/8" CASING ON 3-17c/M-31 iAverage Angle: Maximum Angle Maximum Dogleg Top of Cement 50 53° 37" @ 9570' 4.38°/100@4057' 3.41 °/100' @4157' 10607 {Calc. assumin~l 30% washout) Contacts Office Home Pager Drilling Superintendent Dave Cocking 564-4896 522-3279 TTRD Team Leader Jeff Hupp 564-5606 345-4501 Operations Drilling Engineer: Chris West 564-5089 345-4699 Geologist: Evvy Goebel 564-5367 276-1045 Geophysicist: Steve Roberts 564-5911 348-0358 Sperry Sun Directional Gordon Hecht 563-3256 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Dave Higbie 248-3511 345-0398 275-4356 275-9869 275-7530 275-1337 3-17c/M-31 Redrill Drilling Program- FINAL Directional Plan Cf WP10 TTRD 10/02/98 Page Cf4 SDI 3-17C/M-31 SUMMARY PROCEDURE COMMENTS , The 9-5/8" x 4-1/2" production packer is a Baker permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. , . The ex~isting perforations were plugged with cement and the previous sidetrack window is plugged with a /,I cement retainer. ~ This well will be sidetracked at app. 11,200 feet. PRE-RIG OPERATIONS . . , , . Pressure test IA (tubing and annulus) to 3,500psi. Circulate kill weight fluid (estimated BHP at 9850'SS is 5000psi - 9.76 ppg EMW). RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. Drift 4-1/2" tubing and liner for 3.80" whipstock assy. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV and test. If rig move is delayed more than 2 days freeze protect to 500 feet Remove flowlines, level pad. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. If not, attempt bleed off pressure. If unable to bleed off pressure, Pull BPV, RU slickline and pull btm glv. Circ well w/brine or milling fluid until dead. Rerun glv. 3. If well is dead, pull BPV. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. 4. Rig up on E-Line. Run and set DW-1 Packer with orientating sub. Verify lug orientation for eccentric weight bars to determine anchor and whipstock alignment. 5. Run whipstock and anchor on drill pipe. Set Whipstock face _+ 30 o right of high side. 6. Pick up 2-3/8" Drillpipe and Milling BHA. 7. Cut TTRD window through 4.5" liner and 20 feet of new hole. If problems are encountered get out of the window, the annulus will be squeezed. 8. Pick up Sperry directional BHA to turn and build @ 12°/100 feet to 50° at app× 11445' MD. Hold 50° to 12085' md, drop to 20° at 12456' md and hold 20° to TD at +/- 12900' MD. 9. If there are hole problems, run a 3.75" Baker fixed blade HO over whole interval and spot lubricant in OH section. POOH. 10. Run a 2.875" solid liner from 10,311 to 12898' MD, cement as per plan. POOH. 11. RIH with inner string to displace to KWB. (2 days). 12. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. 13. Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. 14. Turn the well over to Production. 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan # WP10 TTRD 10/02/98 Page #5 Drilling Discussion General The proposed sidetrack of shut-in well 3-17B/M-31 to the 3-17C/M-31 location will access up- dip 3^ reserves considered unrecoverable based on the current depletion strategy. The original well 3-17B/M-31 (drilled June 1997) encountered less developed 3^ sands than were originally anticipated. In addition to poor sand development, it appears that the well crossed a significant fault which caused a majority of the 3A sand to be faulted out. The objective of the 3-17C/M-31 sidetrack is to reposition the wellbore 500' northwest of the original well where reservoir quality improves and the risk of encountering a fault is diminished. The key risks associated with this location are the uncertainty around the current fluid contacts and the structural uncertainty (+/- 50') at the target location. ^ second attempt to recover the reserves associated with this target was previously considered too risky utilizing conventional sidetracking methods. This 3-17C/M-31 sidetrack represents the 3rd implementation of 'I-I'RD technology at Endicott as a cost effective alternative to conventional sidetracking. The 3-17c/M-31 well on SDI at Endicott will target the Kekiktuk in the 3^ in accordance with the 1998 development plan. The 3-17b/M-31 well was plugged and abandoned pumping cement down coil-tubing. A previous TTRD sidetrack was attempted from this well bore to the same BHL. This 'I-I'RD sidetrack will be attempted by setting a through tubing whipstock and kick off through the 4.5" casing in the Seabee Formation to the M-31 BHL utilizing the 2.875" liner design. We will not pull the existing production packer or tubing in this well. The 2.875" liner length will be _+ 2200 feet, with the top of the tie back at 10700' inside the 4-1/2" liner. A Retrievable tieback may be run if the 4-1/2" x 9-5/8" liner top packer fails the 3000 psi test. The existing 6 valve (ultra) slimhole (4.5" x 1.5" for 9.625" casing) GLM design for the completion on a 4.5" L-80 tubing design with a X/XN nipple profile. Directional Plan: The directional plan for the 3-17c/M-31 well consists of kicking off with a whipstock and conventional 3-3/4" BHA's for the Kekiktuk Flow sands. Current plans call for up to 12°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, build up to 50° and drill the tangent at 50° degrees into the Tuffs, the angle will be dropped to 20° prior to reaching the HRZ. The 20° hole angle will be to TD at _+12898' MD (9,950 TVDSS). Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD tool configuration, and bit hydraulics will be discussed at the daily wellsite meeting. Directional Survey Program The survey program for 3-17c/M-31 calls for use of Sperry's SOLAR MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan # WP10 TTRD 10/02/98 Page #6 attention to JORPS is required;w¢ith the use of checkshots and survey'data validation. Bit Program We will kick off in the Seabee interval with a TTRD directional BHA and 3-3/4" x 4-1/4" Bi- center bit PDC bit. The bi-center bit is planned to drill a slightly larger hole to allow more annular clearance when drilling the coal intervals. The directional build will take place in the Seabee interval. The angle drop (50° to 20°) will take place in the Tuffs prior to penetrating the HRZ shale. The hole angle will be held at 20° through the HRZ and the Kekiktuk to TD. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication of bit failure such as torque spikes, the bit should be pulled at the descretion of the rigsite team. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Window Mills 90 - 120 gpm 3.75" kickoff DPI Bicenter 4-1/4" x 3-3/4" 90- 120 gpm 0.371 < 1 3.75" Kickoff HTC 335 (if needed) 90 - 120 gpm 0.371 < 1 3.75" Tangent DPI Bicenter 4-1/4" x 3-3/4" 90 - 120 gpm 0.371 < 1 3.75" Tanc~ent HTC 325 (if needed) 90 - 120 ~lpm 0.371 < I NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. Mud Program: The well is presently loaded with 10.5 ppg brine. This fluid will be used to mill the window. The rig will displace to a 10.5 ppg inhibitive Clay seal system after milling the window. Immediately after displacing, add 0.5 ppb of Barascav D. Tourly sulfite checks should be made to ensure that residual sulfites of 150mg/L are maintained with Barascav D. Make sure DITCH MAGNETS are used both in the possum belly and suction pits for maximum metal removal benefit throughout milling and drilling operations of this well. Make sure DITCH MAGNETS are used both in the possum belly and suction pits for maximum metal removal benefit throughout milling and drilling operations of this well. See Bariod mud recommendation for exact mud parameters. While milling the window, run the solids control equipment (shakers and rig centrifuge) to remove the cement and metal from the brine. The Bariod solids control van should be operational prior to drilling any new formation with the inhibitive Clay Seal mud. This will help keep the PV down, which is the main driver of circulating pressure. Since the mud weight is maintained with NaBr, the centrifuges can be run continuously without reducing the mud weight. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mudlube. Maintain a ~ ppb buffer of Bicarb/Soda ash if EP Mudlube is added. A Iow vis, weighted brine sweep prior to the cement slurry may be needed to clean the hole. This will facilitate a better cement job. Tripping Practices / Stuck Pipe / Hole Cleaning / Reaming Tripping should be undertaken with caution due to swabbing possibilities with high viscosity fluids and the tight annular clearance. The 10.0 ppg brine trip fluid was not needed on the last well due to the reduced viscosity. The same mud parameters will be used on this well. The bottom hole pressure could be as high as 4700 psi (+/- 9.3 ppg ). The mud weight is recommended to be maintained in the 10.5 ppg range to control the HRZ shale. This mud weight is based on the original well and the Niakuk HRZ study. If swabbing becomes a problem, the well will be displaced to a trip fluid (10.5 ppg brine) to minimize swab pressures. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan Cf WP 10 'I-rRD 10/02/98 Page Cf7 on hand. Baroid recommends-~tilization of Iow viscosity sweeps tO--assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. After getting back to bottom after a trip, bring pump on very slowly to minimize surge pressures. Pipe should be pulled and run very slowly (4-5 minutes/stand) in the open hole to reduce pressure fluctuations. Hole Cleaning Based on the PWD (Pressure while Drilling) review from the original SDI 3-17C well, hole packoff due to elevated ECD through the HRZ shale was the primary cause of hole instability. The ECD data from the 2nd well (1-33AJN-24) showed the lower viscosity mud reduced the ECD by 1.0 ppg without a reduction in hole cleaning. The 3-17C redrill will be kicked off above the HRZ in the Seabee formation to ensure the directional work is completed prior to encountering the HRZ or P-3 Coal HRZ. The 20° hole angle through the HRZ and coal should help minimize the hole instability. The Bariod reservoir studies have shown that this fluid causes little formation damage. The ECD data also showed that numerous short trips and circulating is needed to clean the hole. If any coal is encountered, drill only 1-2 ft prior to circulating the hole clean. Coal also caused packoff problems in the 3-17C well. The coals will probably not be identified until the cuttings reach the shaker. During the expected coal interval, we should control drill no more than 1-3 feet at a time, and circulate bottoms up before continuing. The warning signs for coal packoff are pressure or torque fluctuations, coal cutting across the shaker, hole fill after connections, return flow fluctuations, and increase of drag. To identify and minimize problems, this information must to recorded on the driller handover sheet to track trends. Reaming Reaming in 'I-I'RD wells require much closer attention while reaming than conventional wells due to the affect of ECD and pipe movement in very close annular clearance. If reaming is needed, reduce the pump rate and ream very slowly. This is important both while drilling the reservoir, and any time there are unstable formations such as coals or the HRZ exposed. Mud properties must be maintained within the specified parameters at all times. If mud properties are not within range, drilling operations should cease, and the mud conditioned before continuing. Every attempt to rotate rather than slide will assist hole cleaning, and minimize reaming. If we do have to ream, it should be at reduced ( < 50% of drilling circulation rate) circulation rate and only up-ream. The combined affects of ECD and down-reaming put excessive pressure on the formation and will cause hole collapse. Equivalent Circulating Density The PWD (recorded data) sub will be not run in this well unless a real time tool is available or it is needed later in the well. This data has been very useful in evaluating the problems encountered in the previous wells. The reduced Iow rheology of the proposed mud will minimize the ECD. Any hole problems should be immediately reported so a revised drilling plan can be formulated. After milling out, treat out all cement contamination with bicarb or Soda ash. Establish filtrate control with N-vis and run Aldacide (3 to control bacterial growth. Low vis sweeps are recommended on an as needed basis. Barofiber, weighted, and high vis sweeps could elevate the pump pressure to unacceptable levels. Sweeps should be kept as small as 5 bbl to cover 600' of gauge open hole annulus. The mud must be kept as clean as possible. This will help keep the PV down which is the main driver of circulating pressure. The Bariod or MI centrifuge should run continuously will drilling and circulating. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mublube. Maintain a 1/2 ppb buffer of Bicarb/Soda ash if EP Mudlube is added. The mud should be conditioned and thinned prior to cementing the 2.875" liner. Also, a Iow vis, weighted brine sweep prior may be needed to clean the hole. This will facilitate a better cement job. A dirt magnet sweep, mixed in seawater or brine followed by a high vis sweep should precede the completion brine. Should losses occur after perforating, the standard Endicott sized salt pill should 3-17c/M-31 Redrill Drilling Program - FINAL 10/02/98 Directional Plan # WP10 TTRD Page #8 be used to plug the losses. No potential hazardous levels of H2S are anticipated in the 3-17c/M-31 well. There have been H2S reading on offset SDI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. Logging Program: The MWD-GR log will be the only MWD log. Wireline conveyed GR/Res will be run for WOC determination. Schlumberger will provide the logging tools and e-line unit.. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This TTRD sidetrack will require a 2.875" 6.4# L-80 liner with STL connections to be run across the entire interval. The top of the 2-7/8" liner will in the 4.5" tubing at 10310+/- MD. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to log, spot lubricant across the open hole section in the event a conditioning run is not made prior to running liner. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole opener trip after logging and prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require 1 turbolator (2-7/8" x 3-5/8") centralizers on every other joint to the window. Integral centralizers (STL connections) will be run in place of the latch-on turbolators to eliminate turbolators moving on the liner. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull the liner and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. This liner will be run with a PBR only. There is an option to run a packer after cementing operations. The cementing program is designed to place cement back the 2-7/8" liner top. The approximate volume will be 100 sacks (21 bbls) of Class 'G' with additives as specified in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. Wireline Perforating This sidetrack well can be perforated with wireline conveyed perforating guns from LWD GR and open hole resistivity logs after the rig is released. Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS After the sidetrack of the original 3-17c/M-31 well-bore, there are not any wells which are a close approach. The closet is the original well 3-17b/M-31 which quickly diverges from the sidetrack. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. See the TC plot for details. PORE PRESSURE / LOST CIRCULATION Production Interval (3.75"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset estimate of pore pressure range from __ 6.6 to 9.8 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential stickinq. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. 3-17c/M-31 Redrill Drilling Program- FINAL 10/02/98 Directional Plan Cf WP10 TTRD Page Cf9 Review the Pad Data She~ for trouble highlights throughout SDI histo'ry~. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential sudace pressures. Special XOS for drillpipe are available for this well. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Disposal Cuttings Handling: Fluid Handling: CC2A Annular injection is not available at Endicott for this well. 3-17c/M-31 Redrill Drilling Program- FINAL Directional Plan # WP 10 'I-rRD 10/02/98 Page #10 TTRD Special ConSiderations Although the Endicott SDI 3-17c/M-31 well will be Shared Services Drilling (SSD) and BP Alaska's eighth Through Tubing Rotary Drilling (TTRD) application, it qualifies as "non-routine" since it will be the first done entirely through 4-1/2" tubing and into 4-1/2" production liner. The potential hazards, contingencies and special operational considerations are addressed on the next few pages. Well Control Due to the special circumstances involved in drilling such small (3-3/4") diameter hole, many areas of concern should be revisited and/or addressed. Barriers Per SSD drilling policy, all drilling operations must conform with the principle of redundant isolation inside the production string and in the annulus. Redundant isolation insures that there are two, independent barriers to potential flow. Two barriers will be required at any time while installing and/or removing the tree or BOP stack. Examples of acceptable barriers include: · Cement across perfs (must be tested); · Bridge plug above perfs (must be tested); · Tubing plug above perfs (must be tested); · Closed and tested SSSV; · Static fluid of sufficient MW to hold highest BHP; · Check valve installed and tested in the tubing hanger; · Production packer (must be tested); · Tubing hanger packoff (must be tested); · Dummy sleeve across safety valve landing nipple; Any variation from this policy will require dispensation from the Drilling Superintendent. Well Control Equipment All well control equipment and systems are to be carefully inspected by the Company Representative at rig up and must be in excellent working order. Daily function tests of the primary BOP components and tourly function tests of PVT equipment shall be required and must be documented in the morning drilling report's progress log. Well control drills shall be carried out by all crews (both tours) at the beginning of each hole section, prior to drilling into any suspected hydrocarbon zone and as deemed necessary by the Company Representative to maintain the highest levels of awareness. Per SSD policy, minimum required kick detection equipment shall consist of: · Pit volume totalizers (PVT); · Flow indicator on flowline; · ROP recorder; · MW in and out monitoring (minimum measurement every 1& hour); · Trip tank with digital readout or mechanical indicator visible from driller's console; In addition, accurate pressure gauges should be in place on both the standpipe and choke manifolds. The gauges should be new or recently calibrated, must be rated for the same pressure as the equipment on which it is installed and should be suitable for accurately reading Iow drillpipe and casing pressures. All kick detection equipment must be in good working order and should be function tested tourly. Drills should be held to "re-familiarize" rig crews with proper function and operation of all kick detection equipment. Kick Tolerance, Kick Detection, Kick Drills Kick tolerances are to be defined as a volume and are to be calculated as defined in the latest BPX Casing Design Manual. The kick tolerance of the weakest known point of the hole section being 3-17c/M-31 Redrill Drilling Program - FINAL 10/02/98 1 Directional Plan # WP10 TTRD Page #11 1 Shared Services Drilling Well: End/co tt 3-17C/M-31 Wp 10 .DrillOuext k"¢ 'l lir;:d' O~ ~ :.':'[ ' VVc'I b,'c.,rlh ftt!/'Oll.~"4;U : ]'lllll VD. rite. a! ,q~.c'.i:)n A2imull, ' 272.4L:,11° :'c Hit:al Set:~'i..':~ D.:2s(:fiptio. I:IAIW. I "o'['rllzal ~:-clic.~l Oriilin: 0.00 N,O.[×} E Depth Depth Vertical Oo{ileg Section Rate 1121:O. 00 21.31 g 280.905 8658.4.'I 11240.0t:/ 2-1.511 274.7DJ $705.27 11446.25 ~9.0¢~ Z69.6~ 1 8~69. t9 ~20~5.9J ~9.094 269.~1 12456.87 20.~1 2g0.9 JO 12781.87 20.~ 280.9 lO 12~98.93 20.0~ 2~.010 I~.~ 5,~47.78 N 262136 g -1 I.&~ 5949.84 N 24 K4-4 E 3.69 lO,000 5852.91 N IL5.95 g 1Z6.20 t2.OlX! 58q9.81~ N 35'7.53 W 609.07 0.0C~ 5851,26 N 501.61 W 8t6.g8 g.&~ 5i~2.30 N fi~3.76 W ~6.43 0.~ 5g89, g8 N 713.~ W ~6.03 0.~ RKI~ [1ov~liaq: ~l.~SltRip (E~) ........... , ~4501t Welt ICB~} 55.75 hR~- ~dSL ~eck~ By: ...... ~ PROPOSAL TARGET SUMMARY Target t,,~an~e: TVD~ T~DFIRB: W~lh-~od Offs¢{s: 3-17C, q.1-$1 9e4O.CO 9~96.O3 5B52.30 N. b'-/3.7615 G'oL',al Coordic, at~s ' 5D7~q~lT&O3 re, 253750.00 F 62.00 6000 5800 Il ',r, 5600 -.fo -.I,O -fi,. - 6200 'gOOO - SBO0 - 5600 · (3.) ('_I D Ii-,MI Ill '.'. }~,P, ................................... Shared Services Drillit;.q Well - Endicott 3-fTCAI4-3! WplO Verhc.~fl O?;9in - Well lto~ Uonlal Origin: Well f.l(:;Jsur(~rflerl~' UH:IS: Oogleg se'~ed~: Deqrec~ [~r 1~1 Ve~ical Se~gn ~irnulh: 27~.468" Ve~i~ Scion Descript~n.~l Vestal ~'on Origin: 0.~ N.O.~ E M~sur~ fncl. A~m, Ve~ca[ Proposal Data for 3-17C/IVT-31 WpTO TTRD EasUngs Vortical Dogleg S~c~on Rale 5847.78 N 263.86 E 58,49.84 N ~4S. 4.t E 5952.9T ~; 125.95 E 5~49.8§ h' 357_50 ~V 5.e6t.7X, N $6~.61 W 5882.]0 N 61336 %V 58A'9,88 N '113.0~ W -! 1.9.') 3.69 10.000 126,20 12.00~ 6O9.07 816.48 8.0{)3 97.6.43 0.0'30 S66.03 [u -1 I .... Endicott ~easursff Depth Incl. Azim. Sub-Sea Depth Vertical Deplh 11200.00 21.318 280.905 8612.43 8669.43 11240.00 24.511 274.701 8649.27 8705.27 11300.00 31.639 272.521 8702. I8 8758.18 11400.00 43.5067 270.344 8781.27 8837.27 11446.25 49.094 269.641 8813.19 8~69.19 11500.00 49.094 269.641 8848.39 8904.39 11578.82 49.094 269.64I 8900.00 8956.00 11600.00 49.0§4 269.641 8913.87 8989.87 f T 700.00 49.094 269,641 8979.35 9035.3.5 11800.00 49.094 269.641 g044.83 9100.83 1 ~900.00 49.094 269.641 9110,32 9166.32 12000.00 49,094 269,541 9175.80 9231.80 12085.93 49.094 269,641 92.32.07 9288.07 12100.09 47.978 269.846 9241.38 9297.38 12200.00 40.6-66 271.547 9313,24 9369.24 12300.00 32.188 273,921 9393.95 9449.95 100,00 24.379 277.624 9481.95 9537.95 ,/456.87 20.¢_r00 280.910 9534.60 9590.60 12462.62 20.000 280.910 9540.O0 9596.00 12500,00 20.000 280.910 9575.13 9631.13 12600.00 20.090 280.910 9669, 09 9725.09 12700.00 20.000 280.910 9762.06 9819.05 12716,96 20.000 280,910 9779.00 9835.00 12727.60 20.000 280.930 9789.00 9845.00 1278Z.87 20.600 280.910 9849,00 9896.00 12792.52 20,009 280.910 9850.00 9906.00 12796.77 20.000 280.910 9854.00 9910.00 12800.00 20.000 280.910 9857.03 9913.03 12819,12 20.000 280.910 9875.00 9931,00 12840.40 20.000 280.910 9895.00 995~.00 Sperry-Sun Drilling Services Proposal Report for 3-17C/M-31 Wp 10 TTRD Lo ca ! Coordinates Northings Eastings (ft) (~) 5847.78 N 263.86 E 5849.84 N 248.44 E 5851.55 N 220.28 E 5852.92 N 159.39 E 5852.91N 125.95 E 5852.~5 N 85.33 E 5852.28 N 25.76 E 5852.18 N 9.75E 5B51.70 N 65.82W 5851.23 N 141.40W 5850,76 N 216.98W 5850.28 N 292.55W 5949.88 N 357.50W 5849,83 N 368.04W 5850.60 N 437.47 W 5853.20 N 496.3IW 5857.66 N 543,41W 5~61.26 N 564.61W 5861.63 N 566.54W 5864.05 N 579.09W 5870.53N 612.88W 5877.00 N 646.26W 5878.10 N 65T.95W 5878.79 N 655.53W 5852.30 N 673.75W 5882.99 N 677.33W 5883.27 N 678,76W 5585.47 N 679.84W 5~54.71 N 686.26 W 5886.09 N 693.41W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (It) (°/10Ott) (It) 5976810.80 M 270686.12 E -11.80 5976813.32 N 270670.77E 10.000 3.69 5976815.90 N 270642.67 E 12.000 ~1.90 5976819.~3 N 27058~.86 E 12,000 92.79 5976820.14 N 270548.43 E 12.000 126.20 5976821.13 N 270507.82 E 0.O00 166.77 5976822.58 N 270448.27 E 0,000 226.27 5976822.97 N 270432.27 E 0.000 242,26 5976824,81 N 270356.71 E 0.000 317.74 5976826.65 N 270281.16 E 0.000 393~3 5976828.49 N 270205.60 E 0.0O0 468.72 5976830,33N 270130.04 E 0.0gO 544.20 5976831,91 N 270065.12 E 0.000 609.07 5976822.19 N 270054.58 E 8.000 619,80 5976835.08 N 269985.21 E 8.000 689,00 5976839.58 N 269926.48 E 8.000 747.90 5978845.58 N 269879.53E 8.000 795.16 5976849.63 N 269858.45 E 8.000 816,48 5976850.06 N 269856.53 E 0,000 818,42 5976852.86 N 269P_A4.06 E 0.000 631.07 5976860.36 N 269810.69 E 0,000 864.9~ 5976867.86 N 269777.32 E 0,0OO 898.72 5976869.13 H 2~9771.66 E 0.000 904.47 5976869.93 N 269788.11 E 0.000 908.07 5976874.00 N 269750.00 E 0,000 926.43 5975874.80 N 269746.45 E 0.000 930.03 5976875.12 N 269745,03 E 0.000 931.47 5976975.36 N 269743.95 E 0.00O 932.56 5976876.79 N 269737.57 E 0101~ 939.03 5976878.39 N 2~9730.47 E O.000 946.23 Alaska State Plane Zone 3 Endicott SDI Comment KOP: Slart Dir @ 10.0000/10{1ff · 11200.00fl PAD, 86C-8.43ft 't-VD Dk Rale Increase @ 12.0[)0"/100ft ' 11240.00ft MD, 8705.2711 TVD End Dir, Sa/I @ 49.094'- 11446.25ft MD, 8869.19fl TVD Top Tuffs Siart Dir @ 8.000°/100ft · 12085,93ti MD, 9288.07tt TVD End Dir, Sail @ 20.000°: 12456.87tt MD, 9590.60R TVD Top HRZ Base HRZ/Top Put River Base Put River (LCU) _T_~p 3A3C Coal r§et: 3-17C/M-31 Wp10, 50.00 Radius., Geological Top3A3S Sand Esl. Cu~entGOC Top 3A2C Coal Top 3A2_S Sand/Shale I- Sperry-Sun Drilling Services Proposal Report for 3-17C/M-31 Wp 10 7-l-RD Endicott Measured Sub-Sea Verlicai Local Coordinales Depth Incl. Azim. Depth Depth Northings Eastings (t~) fit) (~t) (it) (fl) Global Coordinates Dogleg Vertical Northin§s Eastings Rate Section (it) (it) (°/~00a) 12845.72 20.000 2110.910 9900.00 9956.00 5886.43 N 695.20 W 12~54.24 20.000 280.910 9908.00 9964.00 5886.99 N 6.98.05 W 128:64.68 20.000 280.910 99,18.00 9974.00 $887.67 N 701.63 W 12896.80 20.00,0 260.9'1'0 9948.00 1'0004.00 58B9.74 N 712.35 W 12898.93 20.000 280.910 9950.00 10~.ff6.00 5889.88 N 713.07 W 5976878.79 N 269728.69 E 0.00O 948.03 5976879.43 N 269725.85 E 0.000 950.91 5976880.22 N 269722.30 E 0.000 954.51 59768['I2.62 1'4 269711.65 IE 0.000 965.31 5976882.78 N 269710.94- E 0.01:X) 966.03 ~,11 data is in feet unless otherwise stated. Directions and coordinates are retative to True North. tertical depths are relalive to Well. North[ngs and Eastings are relative to Well. he Dogleg Severity is in Degrees per 100ft. ert/cal Section is from Weir and calculated along an Azimuth of 272.468° {True). ~.sed upon Minimum Curvature type calculations, at a Measured Depth of 12898.93ft., Bottom Hole Displacement is 5932.89ft., in the Direction of 353.097° (True). Comment Esl. OWC Top 3A1 Shale Top Upper 21:3 Top Lower 2B Tot~tl Depth - 12898.93ft MD, 10006.00fi TVD 2 7/8" Lirter Alaska State Plane Zone 3 Endicott SDI ' T_~ I Sidetrack 4 I/"Z" L'~3 1SM TBG. 12.6 #/'F~ NO~ SEC'R, ON wlt;CcO.,v I~ 9 5,'3 ~ 7' ZXP BAK=R UNER PKR 7' X 4.5' XO (3.875' ID) ~ARY Re:. Log ~ INTE~,VAL 12812'.12822' OPEN 12916'.12931' OPEN 13085'.; 3-S'98' lSD 13116'. 1313.,5. ISO SD! WELL 3-17B/M.31 RT ELEV= 56' 4.5 X 1.5 CAMCO "T'B" ,gCR 4-1/'Z" ';C" NIPPLE ~ S/~ x 7 T1W H6-SP.T 4-1/Z' 'X' NII~PLE (HES) (3.813' ID) 4--1/'2' '~XN' NIPPLE (HES) (3.7'25 ID) 4-I,'2' Wt..EG EU/O ,, · /zzoa,m0 TOP ot MBP= 13047.6' ~ t:,kD PES "CFR' ReL Mech. 'HW' Equalizing ,S.u~ EqualLze mecr~nlca~...y (1' p~cr.g) o,, ~.yOrau:~ca~;,., (4 ste~ pi..~ x 575 ~.5 HYRIL 511 CASING L~3,90 ,..s) 12.6 ,~ ~.TF'T (3.958' 5' S.~OE ~ Datle .-..~, ,,,_, ~ELL: 3-17b~4-31 ?/~8.~7 ;=LAC AO{:>.p~ ' -' APl NO: 50-029-21946-02 MARKER PROJECT ENDICOTT ' HAW - XPI 'PLOT SS/MD NEXT PAG .. ,--,,', ;~ · WELL NAME LOG/DATE 3-17B/M-31 CNL 7/9/97 ZONE 3A2 3A.3 F1 2B TOP M.D. BDT M.D, H TOP TVD BDT T'VD SPINNER 8111197 12812 12822 10 9896 9899 0.CO 12916 12931 15 9933 9939 0.4,5 1,3086 13098 12 9993 9997 0.52 13116 13136 20 1C002 10CC9 0.C0 Last Revised: 0-.' ;WELLHEAD:' 13-5/8" / 5000 psi / FMC S~_~.~ig Bore RT ELEV= 56' BF ELEV= 17.2 MAX. DEV. = 71 DEG. sidetrack 4 1/2" L-80 IBM TBG. 12.6 #/FT 9-5/8", 47#/ft NT80S XO to NT95HS NOTE: SECTION WINDOW IN 9 5/8 CASING FROM 10500' -10550' 10312' i 7" ZXP BAKER LINER PKR J 10338' j 7'x4.5"xO (3.875" ~D) Proposed Top Whipstock 11176' Window f/11177-191' MD Propsed Whipstock packer @ 11 Cement Retainer @ 12111 Previous window @ 12191 pERFORATING SUMMARY Ref. Log CNL/GR 7/9/97 SW,'~ 2-7/8I 11 swq 2-7/81 6 tINTERVAL 12812'-12822' SQZ'D 2916'-12931' SQZ'D 3086'-13098' SQZ'D 3116'-13136' SQZ'D 7/28/97 ADD-PERFS Date Comments 7/10/97 DAV Initial Perfs & Completion RAC SSSV LANDING NIPPLE HES "HXO" (3.813" ID) 522 4.5 X 1.5 CAMCO "'I'B" 9CR GLM'S. RA LATCHES CAMCO "'i'B" 9 CR , I~11'~ '~11"t 6 3620' 3504' 5 6326' 5253' 4 7936' 6291' 3 9OO9' 7009' 2 10031' 7711' I 10186' 7815' 4-1/2' 'X' NIPPLE (HES) (3.e13' ID) 9 5/8 X 7 TIW HB-BP-T PACKER (3.935 ID) /2" 'X' NIPPLE (HES) (3.813' ID) 4-1/2" 'XN" NIPPLE (HES) (3.725 ID) 4-1/2" WLEG 10255' 10311' 0324' ELMD ~10326' Proposed TD of ST C @ 12899' MD 9950' TVDss SidetraCk A Drld to 12870' md Sidetrack B Drld to 12738' md ENDICOTT WELL: 3-17b/M-31 APl NO: 50-029-21946-02 COMPLETION DIAGRAM r3D e~VDI /'IDATI(II~I /'Al AC~VA~ I1~1/'~ I Well Name: 13-17c/M-31 Weft Plan Summary Type of Well (Producer or injector): I Producer Well Design (Conventional, slimhole, etc.)' ' I TTRD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 2755 798 8 11N 17E Tie in survey Location: 3313 516 5 11N 17E Target 1 Location: 3352 1462 5 11N 17E Bottom Hole Location: 3343 1510 5 11N 17E I AFE Number: 1727026 I I Rig: I DOYON 15 I IEstimated Start Date: ISeptember 18, 1998 Operating days to drill and complete: 12+3 Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =3941 psi TOP WEST SAK TOP SEABEE/AYLYAK KOP 11200' MD / 8612' 'I-VDSS TOP SHALE WALL/TUFFS 11,578 8900 TOP HRZ 12,462 9540 BASE HRZ 12717 9779 PUT RIVER 12717 9779 LCU 12,727 9789 KEKIKTUK - Top Flow 1 12,705 9789 9.14 4900 psi @ 9590 TVDSS Top Flow 3A3C 12782 9840 Target K2B 12865 9918 8.82 TD 12899 9950 Logging Program: 3.75" Hole Curve and Tangent Open Hole E-line Cased Hole: MWD-GR G R-Laterlog-Density E-line Perforating (after rig moves) Casing/Tubing Proc.:ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVDSS 3.75 2.875" 6.4 L-80 STL 2199 10700'/8206' 12899/9950 TBG* 4.5" 12.6 L-80 IBM 10286 38 10324/7960 ~l~&~. 'l'L. .... ;--.I.; J- l_ ~ ,~ , , ~. · Note' The existing tubing will be left in alace and re-used. 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan # WP 10 'I-I'RD 10/02/98 Page ~ Cementing Program (No String'iob): Hole Section Liner Size Depth Volume Cement Production 2.875" Liner from Cement from _+ 17 BBL Class 'G' 10310' to 12899' 10700' 102 SX 0.45% Halad-344 with 2.875" x 4.5" to12899' Final vol. 0.2% CFR-3 tie back Sleeve in Based on 0.25#/sk Super CBL 4.5" tubing actual TD HR-5 as required Mud Program: Production Mud Properties: 13.75" hole section: Inhibitive Clay Seal Depth Density Plastic Yield Tau 0 pH Fluid Flow Rate (PPG) Viscosity Point Loss Reservoir 10.5 <10 16 - 25 3 - 6 9,0-9.5 <4 85-95 Hazards/Concerns Pore pressure (±9,14 - 9.76 ppg EMW) based on offset max SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. High circulating pressures of up to 4500 psig. Close annular clearance causing swab and surge pressures. Excessive Torque to be combated with lubricant additions after testing. Maintain YP of 12-14 #/100 sq ft to minimize ECD. %A/KI I UE A I'~ Im'~"~l IlRillme&l'qm WELLHEAD EQUIPMENT Casing Head: Casing Hanger: Tubinghead: X-mas Tree: IMcEvo¥ 13 3/8" X 13 5/8", 5M Flange SSH McEvo¥ Mandrel Hanger McEvoy 13 5/8",5M X 13 5/8", 5M Cameron 4-1/8",5M DIRECTIONAL STATS FOR 9 5/8" CASING ON 3-17c/M-31 Average Angle: Maximum Angle 50° 53° 37" @ 9570' Maximum Dogleg 4.38°/100@4057' Top of Cement 3.41 °/100'@4157' 10607 (Calc. assumin~l 30% washout) Contacts Office Home PaRer Drilling Superintendent Dave Cocking 564-4896 522-3279 TTRD Team Leader Jeff Hupp 564-5606 345-4501 Operations Drilling Engineer: Chris West 564-5089 345-4699 Geologist: Evvy Goebel 564-5367 276-1045 Geophysicist: Steve Roberts 564-5911 348-0358 Sperry Sun Directional Gordon Hecht 563-3256 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Dave Higbie 248-3511 345-0398 275-4356 275-9869 275-7530 275-1337 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan # WP 10 TTRD 10/02/98 Page #4 4 SDI 3-17C/M-31' 'SUMMARY PROCFI3URF COMMENTS . The 9-5/8" x 4-1/2" production packer is a Baker permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. The existing perforations were plugged with cement and the previous sidetrack window is plugged with a cement retainer. 3. This well will be sidetracked at app. 11,200 feet. PRE-RIG OPERATIONS 1. Pressure test IA (tubing and annulus) to 3,500psi. Circulate kill weight fluid (estimated BHP at 9850'SS is 5000psi - 9.76 ppg EMW). o RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. Drift 4-1/2" tubing and liner for 3.80" whipstock assy. o Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV and test. If rig move is delayed more than 2 days freeze protect to 500 feet 5. Remove flowlines, level pad. RIG OPERATIONS (SUMMARY) , . . Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. If not, attempt bleed off pressure. If unable to bleed off pressure, Pull BPV, RU slickline and pull btm glv. Circ well w/brine or milling fluid until dead. Rerun glv. If well is dead, pull BPV. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. Rig up on E-Line. Run and set DW-1 Packer with orientating sub. Verify lug orientation for eccentric weight bars to determine anchor and whipstock alignment. Run whipstock and anchor on drill pipe. Set Whipstock face + 30 ° right of high side. Pick up 2-3/8" Drillpipe and Milling BHA. Cut TTRD window through 4.5" liner and 20 feet of new hole. If problems are encountered get out of the window, the annulus will be squeezed. Pick up Sperry directional BHA to turn and build @ 12°/100 feet to 50° at appx 11445' MD. Hold 50° to 12085' md, drop to 20° at 12456' md and hold 20° to TD at +/- 12900' MD. If there are hole problems, run a 3.75" Baker fixed blade HO over whole interval and spot lubricant in OH section. POOH. 10. 11. 12. 13. Run a 2.875" solid liner from 10,311 to 12898' MD, cement as per plan. POOH. RIH with inner string to displace to KWB. (2 days). Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. 14. Turn the well over to Production. 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan # WP10 TTRD 10/02/98 Page #5 Drilling, Discussion General The proposed sidetrack of shut-in well 3-17B/M-31 to the 3-17C/M-31 location will access up- dip 3A reserves considered unrecoverable based on the current depletion strategy. The original well 3-17B/M-31 (dri.lled June 1997) encountered less developed 3A sands than were originally anticipated. In addition to poor sand development, it appears that the well crossed a significant fault which caused a majority of the 3A sand to be faulted out. The objective of the 3-17C/M-31 sidetrack is to reposition the wellbore 500' northwest of the original well where reservoir quality improves and the risk of encountering a fault is diminished. The key risks associated with this location are the uncertainty around the current fluid contacts and the structural uncertainty (+/- 50') at the target location. A second attempt to recover the reserves associated with this target was previously considered too risky utilizing conventional sidetracking methods. This 3-17C/M-31 sidetrack represents the 3rd implementation of TTRD technology at Endicott as a cost effective alternative to conventional sidetracking. The 3-17c/M-31 well on SDI at Endicott will target the Kekiktuk in the 3A in accordance with the 1998 development plan. The 3-17b/M-31 well was plugged and abandoned pumping cement down coil-tubing. A previous TTRD sidetrack was attempted from this well bore to the same BHL. This TTRD sidetrack will be attempted by setting a through tubing whipstock and kick off through the 4.5" casing in the Seabee Formation to the M-31 BHL utilizing the 2.875" liner design. We will not pull the existing production packer or tubing in this well. The 2.875" liner length will be _ 2200 feet, with the top of the tie back at 10700' inside the 4-1/2" liner. A Retrievable tieback may be run if the 4-1/2" x 9-5/8" liner top packer fails the 3000 psi test. The existing 6 valve (ultra) slimhole (4.5" x 1.5" for 9.625" casing) GLM design for the completion on a 4.5" L-80 tubing design with a X/XN nipple profile. Directional Plan: The directional plan for the 3-17c/M-31 well consists of kicking off with a whipstock and conventional 3-3/4" BHA's for the Kekiktuk Flow sands. Current plans call for up to 12"/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, build up to 50° and drill the tangent at 50° degrees into the Tuffs, the angle will be dropped to 20° prior to reaching the HRZ. The 20° hole angle will be to TD at _+12898' MD (9,950 TVDSS). Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD tool configuration, and bit hydraulics will be discussed at the daily wellsite meeting. Directional Survey Program The survey program for 3-17c/M-31 calls for use of Sperry's SOLAR MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan # WP10 TTRD 10/02/98 Page #6 attention to JORPS is required, with the use of.checkshots and survey data validation. Bit Program We will kick off in the Seabee interval with a TTRD directional BHA and 3-3/4" x 4-1/4" Bi- center bit PDC bit. The bi-center bit is planned to drill a slightly larger hole to allow more annular clearance when drilling the coal intervals. The directional build will take place in the Seabee interval. The angle'drop (50° to 20~.) will take place in the Tuffs prior to penetrating the HRZ shale. The hole angle will be held at 20° through the HRZ and the Kekiktuk to TD. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication of bit failure such as torque spikes, the bit should be pulled at the descretion of the rigsite team. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Window Mills 90 - 120 gpm 3.75" kickoff DPI Bicenter 4-1/4" x 3-3/4" 90 - 120 gpm 0.371 < 1 3.75" Kickoff HTC 335 (if needed) 90 - 120 gpm 0.371 < 1 3.75" Tangent DPI Bicenter 4-1/4" x 3-3/4" 90 - 120 gpm 0.371 < 1 3.75" Tan~lent HTC 325 (if needed) 90 - 120 gpm 0.371 < I NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. Mud Program: The well is presently loaded with 10.5 ppg brine. This fluid will be used to mill the window. The rig will displace to a 10.5 ppg inhibitive Clay seal system after milling the window. Immediately after displacing, add 0.5 ppb of Barascav D. Tourly sulfite checks should be made to ensure that residual sulfites of 150mg/L are maintained with Barascav D. Make sure DITCH MAGNETS are used both in the possum belly and suction pits for maximum metal removal benefit throughout milling and drilling operations of this well. Make sure DITCH MAGNETS are used both in the possum belly and suction pits for maximum metal removal benefit throughout milling and drilling operations of this well. See Bariod mud recommendation for exact mud parameters. While milling the window, run the solids control equipment (shakers and rig centrifuge) to remove the cement and metal from the brine. The Bariod solids control van should be operational prior to drilling any new formation with the inhibitive Clay Seal mud. This will help keep the PV down, which is the main driver of circulating pressure. Since the mud weight is maintained with NaBr, the centrifuges can be run continuously without reducing the mud weight. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mudlube. Maintain a 1/2 ppb buffer of Bicarb/Soda ash if EP Mudlube is added. A Iow vis, weighted brine sweep prior to the cement slurry may be needed to clean the hole. This will facilitate a better cement job. Tripping Practices / Stuck Pipe / Hole Cleaning / Reaming Tripping should be undertaken with caution due to swabbinq possibilities with high viscosity fluids and the tight annular clearance. The 10.0 ppg brine trip'fluid was not needed on the last well ;due to the reduced viscosity. The same mud parameters will be used on this well. The bottom hole pressure could be as high as 4700 psi (+/- 9.3 ppg ). The mud weight is recommended to be maintained in the 10.5 ppg range to control the HRZ shale. This mud weight is based on the original well and the Niakuk HRZ study. If swabbing becomes a problem, the well will be displaced to a trip fluid (10.5 ppg brine) to minimize swab pressures. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan # WP10 TTRD 10/02/98 Page #7 on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings bed's on the Iow side of the hole. After getting back to bottom after a trip,-bring pump on very slowly to minimize surge pressures. Pipe should be pulled and run very slowly (4-5 minutes/stand) in the open hole to reduce pressure fluctuations. Hole Cleaning Based on the PWD (Pressure while Drilling) review from the original SDI 3-17C well, hole packoff due to elevated ECD through the HRZ shale was the primary cause of hole instability. The ECD data from the 2n~ well (1-33A/N-24) showed the lower viscosity mud reduced the ECD by 1.0 ppg without a reduction in hole cleaning. The 3-17C redrill will be kicked off above the HRZ in the Seabee formation to ensure the directional work is completed prior to encountering the HRZ or P-3 Coal HRZ. The 20° hole angle through the HRZ and coal should help minimize the hole instability. The Bariod reservoir studies have shown that this fluid causes little formation damage. The ECD data also showed that numerous short trips and circulating is needed to clean the hole. If any coal is encountered, drill only 1-2 ft prior to circulating the hole clean. Coal also caused packoff problems in the 3-17C well. The coals will probably not be identified until the cuttings reach the shaker. During the expected coal interval, we should control drill no more than 1-3 feet at a time, and circulate bottoms up before continuing. The warning signs for coal packoff are pressure or torque fluctuations, coal cutting across the shaker, hole fill after connections, return flow fluctuations, and increase of drag. To identify and minimize problems, this information must to recorded on the driller handover sheet to track trends. Reaming Reaming in TTRD wells require much closer attention while reaming than conventional wells due to the affect of ECD and pipe movement in very close annular clearance. If reaming is needed, reduce the pump rate and ream very slowly. This is important both while drilling the reservoir, and any time there are unstable formations such as coals or the HRZ exposed. Mud properties must be maintained within the specified parameters at all times. If mud properties are not within range, drilling operations should cease, and the mud conditioned before continuing. Every attempt to rotate rather than slide will assist hole cleaning, and minimize reaming. If we do have to ream, it should be at reduced ( < 50% of drilling circulation rate) circulation rate and only up-ream. The combined affects of ECD and down-reaming put excessive pressure on the formation and will cause hole collapse. Equivalent Circulating Density The PWD (recorded data) sub will be not run in this well unless a real time tool is available or it is needed later in the well. This data has been very useful in evaluating the problems encountered in the previous wells. The reduced Iow rheology of the proposed mud will minimize the ECD. Any hole problems should be immediately reported so a revised drilling plan can be formulated. After milling out, treat out all cement contamination with bicarb or Soda ash. Establish filtrate control with N-vis and run Aldacide G to control bacterial growth. Low vis sweeps are recommended on an as needed basis. Barofiber, weighted, and high vis sweeps could elevate the pump pressure to unacceptable levels. Sweeps should be kept as small as 5 bbl to cover 600' of gauge open hole annulus. The mud must be kept as clean as possible. This will help keep the PV down which is the main driver of circulating pressure. The Bariod or MI centrifuge should run continuously will drilling and circulating. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mublube. Maintain a ~,,~ ppb buffer of Bicarb/Soda ash if EP Mudlube is added. The mud should be conditioned and thinned prior to cementing the 2.875" liner. Also, a Iow vis, weighted brine sweep prior may be needed to clean the hole. This will facilitate a better cement job. A dirt magnet sweep, mixed in seawater or brine followed by a high vis sweep should precede the completion brine. Should losses occur after perforating, the standard Endicott sized salt pill should 3-17c/M-31 Redrill Drilling Program - FINAL 10/02/98 Directional Plan Cf WP10 TTRD Page Cf8 be used to plug the losses. No potential hazardous levels of H2S are anticipated in the 3-17c/M-31 well. There have been H2S reading on offset SDI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. Logging Program: The MWD-GR Icg will be the only MWD Icg. Wireline conveyed GR/Res will be run for WOC determination. Schlumberger will provide the logging tools and e-line unit.. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This 'I-f'RD sidetrack will require a 2.875" 6.4# L-80 liner with STL connections to be run across the entire interval. The top of the 2-7/8" liner will in the 4.5" tubing at 10310+/- MD. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to Icg, spot lubricant across the open hole section in the event a conditioning run is not made prior to running liner. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Aisc, consideration must be given to a hole opener trip after logging and prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require 1 turbolator (2-7/8" x 3-5/8") centralizers on every other joint to the window. Integral centralizers (STL connections) will be run in place of the latch-on turbolators to eliminate turbolators moving on the liner. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull the liner and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. This liner will be run with a PBR only. There is an option to run a packer after cementing operations. The cementing program is designed to place cement back the 2-7/8" liner top. The approximate volume will be 100 sacks (21 bbls) of Class 'G' with additives as specified in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. Wireline Perforating This sidetrack well can be perforated with wireline conveyed perforating guns from LWD GR and open hole resistivity logs after the rig is released. Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS After the sidetrack of the original 3-17c/M-31 well-bore, there are not any wells which are a close approach. The closet is the original well 3-17b/M-31 which quickly diverges from the sidetrack. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. See the TC plot for details. PORE PRESSURE / LOST CIRCULATION Production Interval (3.75"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset estimate of pore pressure range from _. 6.6 to 9.8 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. 3-17c/M-31 Redrill Drilling Program - FINAL 10/02/98 Directional Plan Cf WP10 TTRD Page Cf9 Review the Pad Data Sheet for trouble highlights throughout SDI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Special XOS for drillpipe are available for this well. Diverter, BOPE, and drilling fluid.system schematics on file with AOGCC. Disposal Cuttings Handling: Fluid Handling' CC2A Annular injection is not available at Endicott for this well. 3-17c/M-31 Redrill Drilling Program - FINAL Directional Plan Cf WP10 TTRD 1 O/O2/98 Page #10 TTRD Special Considerations Although the Endicott SDI 3-17c/M-31 well'will be Shared Services Drilling (SSD) and BP Alaska's eighth Through Tubing Rotary Drilling (TTRD) application, it qualifies as "non-routine" since it will be the first done entirely through 4-1/2" tubing and into 4-1/2" production liner. The potential hazards, contingencies and special operational considerations are addressed on the next few pages. Well Control Due to the special circumstances involved in drilling such small (3-3/4") diameter hole, many areas of concern should be revisited and/or addressed. Barriers Per SSD drilling policy, all drilling operations must conform with the principle of redundant isolation inside the production string and in the annulus. Redundant isolation insures that there are two, independent barriers to potential flow. Two barriers will be required at any time while installing and/or removing the tree or BOP stack. Examples of acceptable barriers include: · Cement across perfs (must be tested); · Bridge plug above perfs (must be tested); · Tubing plug above perfs (must be tested); . Closed and tested SSSV; · Static fluid of sufficient MW to hold highest BHP; · Check valve installed and tested in the tubing hanger; · Production packer (must be tested); · Tubing hanger packoff (must be tested); · Dummy sleeve across safety valve landing nipple; Any variation from this policy will require dispensation from the Drilling Superintendent. Well Control Equipment All well control equipment and systems are to be carefully inspected by the Company Representative at rig up and must be in excellent working order. Daily function tests of the primary BOP components and tourly function tests of PVT equipment shall be required and must be documented in the morning drilling report's progress log. Well control drills shall be carried out by all crews (both tours) at the beginning of each hole section, prior to drilling into any suspected hydrocarbon zone and as deemed necessary by the Company Representative to maintain the highest levels of awareness. Per SSD policy, minimum required kick detection equipment shall consist of: · Pit volume totalizers (PVT); · Flow indicator on flowline; · ROP recorder; · MW in and out monitoring (minimum measurement every ~,~ hour); · Trip tank with digital readout or mechanical indicator visible from driller's console; In addition, accurate pressure gauges should be in place on both the standpipe and choke manifolds. The gauges should be new or recently calibrated, must be rated for the same pressure as the equipment on which it is installed and should be suitable for accurately reading Iow drillpipe and casing pressures. All kick detection equipment must be in good working order and should be function tested tourly. Drills should be held to "re-familiarize" rig crews with proper function and operation of all kick detection equipment. Kick Tolerance, Kick Detection, Kick Drills Kick tolerances are to be defined as a volume and are to be calculated as defined in the latest BPX Casing Design Manual. The kick tolerance of the weakest known point of the hole section being 3-17c/M-31 Redrill Drilling Program - FINAL 10/02/98 1 Directional Plan # WP10 'II'RD Page #11 1 St;are(t $crvicc$ Drilling Well - Et ;dJco tt 3- I7C/M-31 Wp 10 f~C,lgUCed loc(. Azim. Vcrtic_al Norltlinos Eostio§',: Vertical Ooglerj Seclion la/ate 5K47.75 N 263.~6 E -! 1.80 5852.91 N 125.95 E i l~O C2.~0 5849.86 N 3~.5~ W ~9,07 0.~ 5851.26 N 5~.6l W gL&ag g.~ 5~ ~Z.30 N ~73.76 W ~6.43 5ggg.~S N 713.~ W %6.03 0.~ .. "'sURFACE LOCATION ....... IpLor Ifi/ltEIot,~,li:xq: 41,25fiRiD(ESI} [ ~.fz;/ '-"---'-- . ~'- - -- 14~01! t. VeillCge} J : 5.5.7,5 .'1 RKB. A/dSL [ C~e_--k~.vl ~,, · Cootc*.natt.' Sy~Ie',: Zoao.. 4. US Fool J ........ PROPOSAL TARGET SUMMARY Target k~ame: 'I-VI)E-,S I'I/DRKII:Vd~llv~od Ofls~:e..~: G'o~l Coo~lic, at,~$ ' 3,-17C, q.t-31 9e~0.CO 9~q6.o3 5852.,q0 f,/. 6'75.76 E 597~.O~t:,2~-OT-q3.00FJ __ 6200 6000 0 5800 c~ II ~_. 5600 U .,, -- 6200 - 6000 - 5600 '/2 (3) (1~ -r'j Z CD Shard d Services Lhrilli, l. 1 Well ' Endicolt 3~ 1 7C/4~-31 Wp 10 V¢:l:,;', (.)'.;9,1; I (o, ttonlnl Ofi.qin,: Dmtl(."(I s(:'~eri,'y ' Dl:gr~cs p?r I00:1 Vel"li£'.,~l Se. Ctbl~/~.ifnulh ' 272.468" Ve~t"--,~l Section Origin: 0.00 N.O.O0 E Ocpm ! 12t~.O0 21.319 280.905 $6,~$.43 5g-~7.'28 N ,".63.g6 112~0.00 24.51 ] 274.?01 ~705.27 5g:lg.g4 iN' ?,lg. d4 [-'. 114-~6.15 49.094 269.MI ,~9.19 5F~2.91 IX' 12~.95 E 12ofi5.93 49,094 269.641 92~g,07 51~9.8g N 357,.~0 W 1245~.g? 2.0.000 2S0.910 9590.60 5.961.7,(~ N 563.61 W 12731.g'/ 20.01):) 280.910 9996.00 5592.30 N 673.76 ~V J,~,~g&.93 20.0tX9 280.910 lO',ll~.OO 5g,~I'9~18 N 713.0-/W i ~,c,'-~'~ .~ '~ 12 o'J9 ';I ,") .'r T: I I:L:~ ,'t 60~ r.~o. 87cG.2'~ '~%,T) t: 949o 9750 ~oo5o Vertic~l DogfccJ Section Rmle -'T~*.-, 3.69 tO. oOo 12&20 i 2.0eX') 609.07 0.00~ ~¢14.45 92.6.4.1 0.000 %6.03 0.D00 .... Z 0 Endicotl D opt h 112 O0.(K} 11240.00 11300.00 11400.00 11446.25 11500.00 11578.82 ! ~ 600.00 f 1700.00 11800.00 1 ~900.00 12000.00 12085.93 12100.O0 12200.00 12300.00 ,-'456.87 12462.62 12500.00 f2600.00 12700.00 '2718.96 2727.60 2787.87 Incl. 21.318 24.5 ~ f 31.639 43.567 49.094 49.094 49,094 49.094 49.094 49.094 49.094 49.094 49.094 47.978 40. DB 6 32.188 24.379 20.000 20.000 20.000 20.000 20.000 20.000 20.000 20.(;00 Azim. Sub-Sea Depth Vertical Depth Sperry-Sun Drilling Services Proposal Report fo/' 3-17C/M-31 Wp 10 7-rRD Locat Coordinates Northings Eastings (fO (f~) 280.905 8612.43 8658.43 5847.78 N 263.86 E 274.701 8649.27 8705.27 5849.84 N 248.44 E 272.521 fl702.I 6 8758.18 5851.55 N 220.26 E 270.344 8781.27 8837.27 5552.92 N 159.39 E 269.641 8813.19 8869.19 5~52.91 N ~25.95 E 269.641 8848.39 8904.39 5,852.65 N 85.33 E 269.641 8900.00 8956.00 5852.28 N 25.76 E 289.641 8913.87 8959.87 5852,18 N 9.75 E 269,641 8979.35 9035.3.5 5851'.70 N 65.82 W 269.64~ 9044.83 9100.83 5,851.23 N 141.40 W 269.841 9110,32 9166.32 5850.76 N 2~6.98 W 289.6-41 9175.80 9231.80 5850.28 N 292.55 W 269,641 9232.07 9288.07 5849,88 N ;357.50 W 269.846 9241.38 9297.38 5849,83 N 368.04 W 271.547 9313.24 9359.24 5850.60 N 437.47 W 273,921 9393.95 9449.95 5653.30 N 496.3~ W 277,624 94-61.95 9537.95 5557.86 N 543.41 W 280.910 9534.60 9590.60 5861.26 N 564.61 W 280,910 9540_00 9596.00 586 f.63 N 566.54 W 280,910 9575,13 9631.13 5864.05 N 579,09 W 280.910 9669.09 9725,09 5870.5q3 N 612,88 W 280.91'0 9763.06 9819.05 5877.00 N 646.26 W 280.910 9779.00 9~35.00 5878.10 N 651.95 W 280.910 9789.00 9845.00 5878.79 N 655.53 W 280.910 9840,00 9896.00 5832.30 N 673.76 W ,~792.52 20.009 280.910 9850.00 9906.00 5,852.99 N 677.33 W !796.77 20.000 280.9~0 9854,00 9910.00 5883.27 N 678.76 W 800.00 20.000 280.910 9857.03 9913.03 5S83.47 N 679.84 W $19.12 20.000 280.910 9875.00 9931.00 58S4.71 N 1386.26 W ~40.40 20.000 280.910 9895.00 995~.00 5886.09 N 693.4~ W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (fl) ("110oft) (It) 5976810.80 N 27068.6.12 E -11.80 5976813.32 N 270670.77 E 10.000 3.69 5976815.90 N 270642.67 E 12.000 31.9'0 5976819.1'3 N 27058f.86 E 12.000 92.79 5976820.14 N 270548.43 E 12.000 126.20 5,976821.13 N 270507.82 E 0.000 166.77 5976822.58 N 270448.27 E 0,000 226.27 5976822.97 N 270432.27 E 0.0OD 242,26 5976824,81 N 270356.71 E 0.000 31'7.74 5978826.65 N 270281.16 E 0.000 39323 5976828.49 N 270205_60 E 0.0DO 468.72 5976830,33 N 270130.04 E 0.000 544.20 597683 ~.91 N 270065.12 E O.000 609.07 5976832,19 N 270054.58 E 8.000 619.60 5976835.08 N 269985.2 ~ E 8.000 689.00 5976839,58 N 269926.48 E 8.000 747.90 5976845.58 N 269879.53 E 8,000 795.16 5976849.63 N 269858.45 E 8.000 $16,48 5976850,06 N 269856,53 E 0.000 818.42 5976852.86 N 269844,06 E 0.000 831.07 5976860.36 N 269810.69 E 0,000 864.90 5976867.86 N 269777.32 E 0,O00 898.73 5976869.13 N 269771.66 E 0.000 904.47 5976869.93 N 269768.11 E O.000 908.07 5976874.00 hi 269750.00 E 0.000 926.43 5976874.80 N 269746.45 E O.000 930.03 5976875.12 N 269745,03 E 0.O00 931,47 5976875.36 N 269743.95 E 0.000 932.5~ 5976876.79 N 269737.57 E O.O'DD 939.03 5976878.39 N 269730.47 E 0.000 946?3 Alaska State Plane Zone 3 Endicott SDI Comment KOP: S(art Dir @ 10.000°/lOOfl- 11200.00fl MD, 6668.43f! TVO Rate Increase @ 12.000°/100ft ' 11240,001t MD, 8705.27tt 7-VD End Dir, Sail ~ 49.094°: 11446.25fl MD, 8869.19fl TVD Top Tuffs Start Dir @ 8.0O0'V100ft ' 12085,93fl MD, 9288.07tt TVD End DiG Sail @ 20.000°: 12456.87fl MD, 9590.60~t 7-VD Top HRZ Base HRZ/Top Put River Base Put River (LCU) OaP 3A3C Coal r~et: 3-17C/M-31 Wp10, 50.00 RadCus., Geologrcal Top 3A35 Sand Est. Currant GCC Top 3A2C Coal ~m ':PA ')~' ~-~'"~" · ' [~-1 x Sperry-Sun Drilling Services Proposal Repofl for 3-17C/M-31 Wp 10 TTRD Endicott Measured Sub-Sea Vertical Local Coordinates Deplh Incl. Azim. Depth Depth Northings Eastings Global Coordinates Dogleg Vertical Norlhings Easfin§s Rate Secti'on (fi) (~t) ("/~00~) (~t) 12~45.72 20.000 2130.910 9900.00 9950.00 5886.43 N 695.20 W 12554.24 20.000 280.910 9908,00 99G4.00 5886.99 N 698.05 W 12864.88 20.000 280.910 9'918.00 9974.00 5887.67 N 70'J.63 W 12896.80 20.0C,0 260.910 9948.00 10004.00 58B9.74 N 712.35 W 12898.93 20.000 21']0.910 9950.00 IOi:NSG.O0 5889.$8 N 713.07 W 5976878,79 N 269728.69 E 0.OOO 948.03 5976879.43 N 269725.85 iE 0.000 9,50.91 5976880.22 N 269722.30 E O.000 954.51 59768B2.62 N 26971%65 E 0.000 965.31 5976882.78 N 269710_94- E 0,0O0 966.03 data is in feet unless otherwise stated. Directions and coordinates are relative :to True North. 'tic. al depths are relalive to Well. Nodhings and Eastings are relative to Well. ~ Dogleg Severity is in Degrees per 100ft. tical Section is from Well and calculated along an Azimuth of 272.468" (True). upon Minimum Curvature type calculations, at a Measured Depth of 12898.93fl., BoUom Hole Displacement is 5932.89ft., in the Direction of 353.097° (True). Comment Esl. OWC Top 3A1 Shale Top Upper 2 B Top Lower Total Oepth - 12898.g3ft MD, 10006.00fl TVD 2 7/8" Liner Alaska State Plane Zone 3 Endicott SDI (',.~ c:) H143065 VEN~R /~E~Si4~,ST 14- OO INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT ~ DATE ./9~'198 HANDL CIX, 09~l 9~B NO- INST: S/W CAROL WITHEY X4i14 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. i 00. O0 loo. oo I' '~--' V~ELL PERMIT CHECKLIST COMPANY ~) ~/v~ WELL NAME .j~ ~'~ 3 -[~,~/~---Z, ( PROGRAM: exp [] dev ~1. redrll~serv [] wellbore seg II ann. disposal para req I. FIELD & POOL INIT CLASS ~ I~- ~/ (- ~ L_- GEOL AREA ~ ~ '~ UNIT# ( [~ ~/ ~'-Q ON/OFF SHORE ADMINISTRATION A~_~ DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well Iocaled in a defined pool .................. 5. Well Iocaled proper dislance front drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued wilhout administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conduclor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMr vol adequate to tie-in long string to surf csg ........ 18. CM r 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 abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~ C,~L-.> .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (~N (~ N N ~N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures..~. Y N 31. Data presented on potential overpres~ ..... Y N 32. Seismic analysis ofshallow~ ..... ' ........ Y N 33. Seabed con~~-shore) ............. Y N 34~ress reports .. ...... Y ' N exploratory omyj ' ,.. '~ ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to,surface; (C) will ~t'impair.~!echanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y 'N pool; .and (E) wi!! not circumv~_nt ~0 AA.C 25.2,52 or 20 AAC 25,4.1,2: ..... , Y N GEoL,~Gy: ENGINEERING: UIC/Annular COMMISSION: RPC_..~'~ BEW WM JDH DWJ ~ RNC co (z>,~,l~. M:cheklisl rev 05129198 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 improve 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. * ALASKA COMPUTING CENTER * ****************************** . ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : 3-17D/M-31 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292194604 REFERENCE NO : 98535 RECE v/EO NOV 15 1998 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:33 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC REEL NAME : 98535 CONTINUATION # : PREVIOUS REEL : COMFzF~VT : BP EXPLORATION, 3-17D/M-31, ENDICOTT, API #50-029-21946-04 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC TAPE NAME : 98535 CONTINUATION # : 1 PREVIOUS TAPE : COFI~IENT : BP EXPLORATION, 3-17D/M-31, ENDICOTT, API #50-029-21946-04 TAPE HEADER ENDICOTT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR '. GROUND LEVEL: RUN 1 98535 MORRISON ZARNDT WELL CASING RECORD 1ST STRING 2ND STRING 3-17D/M-31 500292194603 BP EXPLORATION (ALASKA), INC. SCHLUMBERGER WELL SERVICES 22 - OCT- 98 RUN 2 RUN 3 8 lin 17E 2755 799 54.95 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3 375 4.500 12181.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:33 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED OPEN HOLE SLIM ACCESS DLL, SDN, AND CNT DATA AQUIRED ON BP EXPLORATION'S 3-17D/M-31 WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE SDN DLL CNT BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 12946.0 11165.0 12982.0 11195.0 12932.0 11165.0 BASELINE DEPTH 88888 11133 11128 11120 11111 11105 100 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN DLL CNT 88886.5 11131.5 11127.0 11120.5 11110.0 11105.0 100.0 RUN NO. PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE EDITED OPEN HOLE DATA. THE LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:33 PAGE: DEPTH SHIFTS SHOWN ABOVE REFLECT TIE-IN CORRELATIONS TO THE MWD GR RUN BY SPERRY-SUN ON 29-JUN-1997 DOWN TO CASING POINT AT 11165 ' . $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT I1 66 15 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 ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 1 1 1 4 68 0000000000 SP SDN MV O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 LLD DLL OI4~M O0 000 O0 0 1 1 1 4 68 0000000000 LLS DLL OIt~l O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 I 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 3-NOV-l~98 10:33 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG 2'TPE CI.~SS MODNr..~B S.,~IP ELI~VJ CODE (HEX) DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13000.000 GR.SDN -999.250 SP. SDN -999.250 CALI.SDN TENS.SDN 6122.000 LLD.DLL -999.250 LLS.DLL -999.250 CNTC. CNT CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 NPHI.CNT -999.250 PEF. SDN -999.250 RHOB.SDN DRHO. SDN -999.250 DEPT. 11165.000 GR.SDN 87.068 SP. SDN 1027.563 CALI.SDN TENS.SDN 5238.000 LLD.DLL -999.250 LLS.DLL -999.250 CNTC. CNT CFTC. CNT 393.413 FCNT. CNT 406.250 NCNT. CNT 1875.000 CRAT. CNT NRAT. CNT 4.615 NPHI.CNT 32.866 PEF. SDN 5.726 RHOB.SDN DRHO.SDN 0.311 -999.250 -999.250 -999.250 -999.250 4.677 2069.633 4.822 2.210 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 10:33 PAGE: FILE SUMPIARY LDWG TOOL CODE SDN CNT $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 11165.0 11108.0 11165.0 11108.0 BASELINE DEPTH .............. 88888 0 11133 0 11128 0 11120 5 11111 0 11105 0 100 0 $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN CNT .............. 88886.5 11131.5 11127.0 11120.5 11110.0 11105.0 100.0 THIS FILE CONTAINS THE EDITED CASED HOLE DATA. THE DEPTH SHIFTS SHOWN ABOVE REFLECT TIE-IN CORRELATIONS BETWEEN THE GR AND THE MWD GR, CARRYING ALL CURVES WITH THE GR SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 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 3-NOV-1998 10:33 PAGE: ** 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 ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 2 1 1 4 68 0000000000 GRCH SDN GAPI O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11165.000 TENS.SDN 5238.000 GRCH. SDN 87.068 CNTC. CNT CFTC. CNT 393.413 FCNT. CNT 406.250 NCNT. CNT 1875.000 CRAT. CNT NRAT. CNT 4.615 NPHI.CNT 32.866 DEPT. 11108.000 TENS.SDN 5227.398 GRCH. SDN 73.882 CNTC. CNT CFTC. CNT 312.500 FCNT. CNT 322.688 NCNT. CNT 1663.625 CRAT. CNT NRAT. CNT 5.163 NPHI.CNT 37.488 2069.633 4.822 1799.594 5.352 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOVtz~98 10:33 PAGE: 7 FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUM~ER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~3~Y VENDOR TOOL CODE START DEPTH ........................... SLDT 13026.5 MDLT 13026.5 CNT 13026.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 11165.0 11165.0 11165.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMPIA RAY CNT COMPENSATED NEUTRON SLDT SLIM LATERLOG MDLT SLIM DENSITY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OI4I~1M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1I -0CT-98 8Cl -205 1830 10-0CT~98 315 11-0CT-98 13010.0 13000.0 11108.0 13000.0 TOOL NUMBER ........... STGCH-A CNT-S SLDT-A MDLT-A 3. 375 12181.0 11165.0 CLA YS EAL / STAR CH 10.50 45.0 9.5 2.6 0.053 70.0 0.077 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-l~98 10:33 PAGE: MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : O. 053 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: Primary Depth Log. Strech added 25 ft. Pulled tight 12730 to 12690 F on pass 2. Caliper closed through tight spot. Pass 1 better through the bad spots. Onlt two passes made due to well conditions. Mud chlorides are 172000 mg/1 RIG: Doyon 15 THIS FILE CONTAINS THE RAW OPEN HOLE DATA. $ LIS FORMAT DATA 70.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 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 3_NOV!~i~8 10:33 PAGE: ** 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 ELD CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 TENS SLDT LB O0 000 O0 0 3 1 1 4 68 0000000000 LLD MDLT OHIO4 O0 000 O0 0 3 1 1 4 68 0000000000 LLS i~IDLT 0H~94 O0 000 O0 0 3 1 1 4 68 0000000000 CALI SLDT IN O0 000 O0 0 3 1 1 4 68 0000000000 GR SLDT GAPI O0 000 O0 0 3 1 1 4 68 0000000000 SP SLDT MV O0 000 O0 0 3 1 1 4 68 0000000000 DRHO SLDT G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEF SLDT BN/E O0 000 O0 0 3 1 1 4 68 0000000000 RHOB SLDT G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR CNT O0 000 O0 0 3 1 1 4 68 0000000000 RCNT CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 RCFT CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CNT O0 000 O0 0 3 1 1 4 68 0000000000 DPHI CNT PU O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13026.500 TENS.SLDT 2468.000 LLD.FIDLT 66.157 LLS.~IDLT CALI.SLDT 2.560 GR.SLDT 18.632 SP.SLDT 1244.250 DRHO.SLDT PEF. SLDT 2.669 RHOB.SLDT 2.118 RTNR.CNT 2.909 RCNT. CNT RCFT. CNT 2750.000 CNTC. CNT 8713.859 TNRA.CNT 3.029 DPHI.CNT NPHI.CNT 18.815 CFTC. CNT 2663.100 DEPT. 11165.000 TENS.SLDT 5204.000 LLD.i~iDLT 75.903 LLS.~iDLT CALI.SLDT 4.525 GR.SLDT 72.345 SP.SLDT 1027.563 DRHO.SLDT PEF. SLDT 5.055 RHOB.SLDT 1.987 RTNR.CNT 5.769 RCNT. CNT RCFT. CNT 357.542 CNTC. CNT 2061.885 TNRA.CNT 5.151 DPHI.CNT NPHI.CNT 35.711 CFTC. CNT 346.244 74.116 0.238 8000.000 32.270 1.639 0.124 2062.500 40.187 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-~98 10:33 PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILENUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUFmlARY VENDOR TOOL CODE START DEPTH SLDT 13040.0 ~IDLT 13040.0 CNT 13040.0 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 12662.0 12662.0 12662.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~kr~A RAY CNT COMPENSATED NEUTRON SLDT SLIM LATERLOG ~DLT SLIM DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS 1I-0CT-98 8Cl-205 1830 10-0CT-98 315 11-0CT-98 13010.0 13000.0 11108.0 13000.0 TOOL NUMBER ........... STGCH-A CNT-S SLDT-A FiDLT-A 3. 375 12181.0 11165.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-l~98 10:33 PAGE: 11 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OHMS) AT T~4PERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): CLA YS EAL /STAR CH 10.50 45.0 9.5 2.6 0. 053 70.0 0.077 70.0 0.053 70.0 THERMAL SANDSTONE 2.65 REMARKS: Primary Depth Log. Strech added 25 ft. Pulled tight 12730 to 12690 F on pass 2. Caliper closed through tight spot. Pass 1 better through the bad spots. Onlt two passes made due to well conditions. Mud chlorides are 172000 mg/1 RIG: Doyon 15 THIS FILE CONTAINS THE RAW REPEAT DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 11 66 14 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-xm98 10:33 PAGE: 12 TYPE REPR CODE VALUE 13 66 0 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 ELEM CODE (HEX) ....................................................................................... O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT TENS SLDT LB O0 000 O0 0 4 1 1 4 68 0000000000 LLD FIDLT OHF~I O0 000 O0 0 4 1 1 4 68 0000000000 LLS FIDLT OI{MI~I O0 000 O0 0 4 1 1 4 68 0000000000 CALI SLDT IN O0 000 O0 0 4 1 1 4 68 0000000000 GR SLDT GAPI O0 000 O0 0 4 1 1 4 68 0000000000 SP SLDT MV O0 000 O0 0 4 1 1 4 68 0000000000 DRHO SLDT G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEF SLDT BN/E O0 000 O0 0 4 1 1 4 68 0000000000 RHOB SLDT G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR CNT O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNT O0 000 O0 0 4 1 1 4 68 0000000000 DPHI CNT PU O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 4 1 1 4 .68 0000000000 ** DATA ** DEPT. 13040.000 CALI.SLDT 2.483 PEF. SLDT 1.905 RCFT. CNT 2750.000 NPHI.CNT 18.815 DEPT. 12662.000 CALI.SLDT 4.066 PEF. SLDT 3.575 RCFT. CNT 650.339 NPHI.CNT 32.750 TENS.SLDT 2052. 000 LLD.MDLT 40. 633 LLS.MDLT GR.SLDT 27.948 SP. SLDT 1328.250 DRHO.SLDT RHOB. SLDT 2.200 RTNR. CNT 2. 909 RCNT. CNT CNTC . CNT 8713. 859 TNRA . CNT 3. 029 D PHI . CNT CFTC. CNT 2663. 100 TENS.SLDT 6178.000 LLD.AIDLT 18031.285 LLS.MDLT GR.SLDT 228.673 SP. SLDT 1283.063 DRHO.SLDT RHOB.SLDT 2.448 RTNR.CNT 4.517 RCNT. CNT CNTC. CNT 3133.371 TNRA.CNT 4.809 DPHI.CNT CFTC. CNT 629.788 40. 404 0.108 8000. 000 27.243 46.634 0.111 2937.500 12.266 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-xm98 10:33 PAGE: 13 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AU3MBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH SLDT 11165.0 11100.5 ~DLT 11165.0 11100.5 CNT 11165.0 11100.5 $ LOG HEADER DATA DATE LOGGED: 11-0CT-98 SOFTWARE VERSION: 8C1-205 TIME CIRCULATION ENDED: 1830 10-0CT-98 TIME LOGGER ON BOTTOM: 315 11-0CT-98 TD DRILLER (FT) : 13010.0 TD LOGGER (FT) : 13000.0 TOP LOG INTERVAL {FT) : 11108.0 BOTTOM LOG INTERVAL (FT) : 13000.0 LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAiV~_A RAY CNT COMPENSATED NEUTRON SLDT SLIM LATERLOG ~DLT SLIM DENSITY TOOL NUMBER STGCH-A CNT-S SLDT-A FiDLT-A LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-x~98 10:33 PAGE: 14 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 3.375 12181.0 11165.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~IM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): CLAYSEAL/STARCH 10.50 45.0 9.5 2.6 O. 053 70.0 0.077 70.0 0.053 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: Primary Depth Log. Strech added 25 ft. Pulled tight 12730 to 12690 F on pass 2. Caliper closed through tight spot. Pass 1 better through the bad spots. Onlt two passes made due to well conditions. Mud chlorides are 172000 mg/1 RIG: Do¥on 15 THIS FILE CONTAINS THE RAW MAIN PASS DATA IN CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-x~98 10:33 PAGE: 15 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 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 ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 TENS SLDT LB O0 000 O0 0 5 1 1 4 68 0000000000 LLD MI)LT OI-k4~ O0 000 O0 0 5 1 1 4 68 0000000000 LLS ~IDLT 0I-I~I~ O0 000 O0 0 5 1 1 4 68 0000000000 CALI SLDT IN O0 000 O0 0 5 1 1 4 68 0000000000 GR SLDT GAPI O0 000 O0 0 5 1 1 4 68 0000000000 SP SLDT MV O0 000 O0 0 5 1 1 4 68 0000000000 DRHO SLDT G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 PEF SLDT BN/E O0 000 O0 0 5 1 1 4 68 0000000000 RHOB SLDT G/C3 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR CNT O0 000 O0 0 5 1 1 4 68 0000000000 RCNT CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCFT CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 TNRA CNT O0 000 O0 0 5 1 1 4 68 0000000000 DPHI CNT PU O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11165.000 TENS. SLDT 5204.000 LLD.MDLT 75.903 LLS.MDLT CALI.SLDT 4.525 GR.SLDT 72.345 SP. SLDT 1027.563 DRHO.SLDT PEF. SLDT 5.055 RHOB.SLDT 1.987 RTNR.CNT 5.769 RCNT. CNT RCFT. CNT 357.542 CNTC. CNT 2061.885 TNRA.CNT 5.151 DPHI.CNT NPHI.CNT 35.711 CFTC. CNT 346.244 1. 639 0.124 20 62. 500 40.187 LIS Tape Verification Listing Schlumberger Alaska Computing Center -NOV- ii, ~ 10:33 PAGE: 16 DEPT. 11100.500 TENS.SLDT 5058.000 LLD.~IDLT CALI.SLDT 3.965 GR.SLDT 74.651 SP.SLDT PEF. SLDT 25.000 RHOB.SLDT 1.712 RTNR.CNT RCFT. CNT 386.364 CNTC. CNT 1956.661 TNRA.CNT NPHI.CNT 33.767 CFTC. CNT 374.155 87.117 LLS.FIDLT 1 O13.563 DP. HO. SLDT 4. 706 RCNT. CNT 4. 927 DPHI. CNT 0.413 -0.677 1818.182 56.840 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC TAPE NAME : 98535 CONTINUATION # : 1 PREVIOUS TAPE : COM~ENT : BP EXPLORATION, 3-lTD~M-31, ENDICOTT, API #50-029-21946-04 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC REEL NAME : 98535 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, 3-lTD~M-31, ENDICOTT, API #50~029-21946-04 Sperry-Sun Drillin9 Services LIS Scan Utility Fri Nov 06 13:02:00 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writin~ Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/11/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writin~ Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER DUCK ISLAND UNIT SDI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MW-80251 E. CRIBBS E. VAUGHN RECEIVED NOV 12 1998 Alaska Oil & Gas Oo~m, Oommis$iort 3 - 17D / M- 31 A~chora~e 500292194604 BP EXPLO~TION (ALAS~), INC. SPERRY-S~ DRILLING SERVICES 06-NOV-98 MWD RUN 7 AK-MW-80251 E. CRIBBS E. VAUGHN MWD RUN 8 AK-MW-80251 E. CRIBBS J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 9 AK-MW-80251 E. CRIBBS J. CARLILE MWD RUN 10 AK-MW-80251 E. CRIBBS J. CARLILE MWD RUN 11 AK-MW-80251 E. CRIBBS J. CARLILE JOB NUMBER: LOGGING ENGINEER: MWD RUN 12 AK-MW-80251 E. CRIBBS MWD RUN 13 AK-MW-80251 E. CRIBBS MWD RUN 14 AK-MW-80251 K. ALLEN OPER3kTOR WITNESS: J. CARLILE J. CARLILE J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 15 AK-MW-80251 K. ALLEN J. CARLILE 8 liN 17E 2755 799 .00 55.00 15.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 4.500 11186.0 PRODUCTION STRING 3.750 13010.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-5 ARE FOR WELL 3-17C/M-31 AND NOT PRESENTED. 3. MWD RUNS 6-15 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), SOLAR PROBE, UTILIZING GEIGER-MUELLER TUBE TYPE DETECTORS. 4. REALTIME GAMMA DATA IS PRESENTED FROM 11146'-11665'MD. GAMMA DATA FROM 116651-11813'MD IS WIPED DATA. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13010'MD, 10145'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED (SOLAR) $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR ROP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 11100.0 12953.0 11100.0 13005.5 11090 11153 11162 11190 11315 11323 11325 11336 11365 11432 11598 11601 11603 11612 11636 11641 11704 11711 11723 11740 11763 11771 11777 11782 11788 11796 11800 11804 11808 11810 11820 11827 11833 11847 11899 11904 11927 11938 11945 11958 11967 11973 11983 BASELINE DEPTH GR 0 11100 5 11163 5 11173 0 11194 0 11328 5 11333 5 11338 5 11353 5 11388 0 11454 0 11609 0 11612 .5 11617 0 11627 5 11650 5 11658 0 11712 5 11723 0 11738 .0 11750 .0 11774 .5 11780 .0 11786 5 11793 5 11799 5 11805 5 11809 0 11814 5 11819 5 11822 0 11831 5 11838 0 11844 5 11857 0 11908 0 11914 0 11939 0 11950 5 11957 5 11974 5 11982 5 11988 0 11998 0 5 0 5 5 5 5 0 5 5 0 5 0 0 5 0 0 5 5 5 .0 5 5 0 0 0 5 0 0 0 5 5 5 5 5 0 0 0 0 0 0 0 5 EQUIVALENT UNSHIFTED DEPTH 12011 5 12035 5 12039 5 12077 0 12116 0 12144 5 12167 5 12211.5 12227.5 12248.0 12254.0 12293.0 12316.5 12332 5 12353 0 12366 0 12375 0 12380 5 12387 5 12389 0 12402 0 12409 0 12419 5 12428 0 12433.5 12494.5 12525.0 12538.5 12571.0 12584.0 12615 5 12632 5 12682 5 12692 5 12696 0 12709 5 12716 5 12730 5 12732.0 12740.0 12747.0 12749.0 12756.0 12766.5 12780 5 12793 0 12802 0 12808 0 12813 0 12821 0 12832 0 12834 5 12841 5 12843 5 12851 5 12865 5 12873 5 12026. 12049. 12054. 12092. 12131. 12158. 12183 12226 12243 12262 12270 12312 12332 12347 12370 12381 12390 12396 12402 12408 12417 12426 12436 12445 12450 12509 12539 12552 12582 12597 12625 12643 12693 12701 12706 12719 12726 12735 12742 12749 12756 12758 12766 12776 12791 12802 12810 12817 12823 12831 12841 12843 12850 12853 12862 12876 12882 5 0 5 0 0 5 5 0 0 0 0 5 5 0 0 0 0 5 5 0 5 5 0 5 0 0 0 0 5 5 5 5 0 5 0 5 0 5 0 0 0 0 5 5 0 0 5 0 0 0 5 5 5 5 0 0 0 12880.0 12884.0 12889.0 12900.0 12904.5 13001.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: 12889 5 12893 0 12899 5 12908 5 12913 5 13010 0 BIT RUN NO MERGE 6 10644 7 11178 8 11182 9 11848 10 11962 11 12008 12 12067 13 12125 14 12229 15 12455 MERGED MAIN PASS. $ TOP MERGE BASE .0 11178.0 .0 11182.0 .0 11848.0 0 11962.0 0 12008.0 0 12067.0 0 12125.0 0 12229.0 0 12455.0 0 13010.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11100 13005.5 12052.8 3812 11100 ROP 0.01 1862.41 18.0104 3812 11100 GR 7.49 452.79 155.535 3707 11100 Last Reading 13005.5 13005.5 12953 First Reading For Entire File .......... 11100 Last Reading For Entire File ........... 13005.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11100.0 11143.0 ROP 11100.0 11178.0 $ LOG HEADER DATA DATE LOGGED: 24-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA P~AY SOLAR GM 78893 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 3.8 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 11178.0 10644.0 11178.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 BRINE 10.50 31.0 10.7 17800 .0 .00 .00 .00 .00 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 68 4 2 GR MWD 6 API 4 1 68 8 3 65.6 First Name Min Max Mean Nsam Reading DEPT 11100 11178 11139 157 11100 ROP 0.01 112.84 61.1087 157 11100 GR 61.62 79.01 71.0316 87 11100 Last Reading 11178 11178 11143 First Reading For Entire File .......... 11100 Last Reading For Entire File ........... 11178 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11143.5 11147.5 ROP 11178.5 11181.5 $ LOG HEADER DATA DATE LOGGED: 25-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL ~(FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 78893 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.800 DRILLER' S CASING DEPTH (FT) : 3 . 8 BOREHOLE CONDITIONS INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 11182.0 11178.0 11182.0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER3~TURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 BRINE 10.50 29.0 10.9 17500 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 71.0 First Name Min Max Mean Nsam Reading DEPT 11143.5 11181.5 11162.5 77 11143.5 GR 72.94 77.47 75.1467 9 11143.5 ROP 2.28 14.84 6.49143 7 11178.5 Last Reading 11181.5 11147.5 11181.5 First Reading For Entire File .......... 11143.5 Last Reading For Entire File ........... 11181.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11148.0 11813.0 ROP 11182.0 11848.0 $ LOG HEADER DATA DATE LOGGED: 29-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 21.7 MAXIMUM ANGLE: 49.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 74165 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 3.8 BOREHOLE CONDITIONS MUD TYPE: INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 11848.0 11182.0 11848.0 STARCH/BRINE MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type ~ 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10.50 42.0 9.0 2.0 .000 .000 .000 .000 .3 'Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 70.5 First Name Min Max Mean Nsam Reading DEPT 11148 11848 11498 1401 11148 GR 60.41 323.82 121.137 1331 11148 ROP 0.72 154.72 11.4272 1333 11182 Last Reading 11848 11813 11848 First Reading For Entire File .......... 11148 Last Reading For Entire File ........... 11848 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11813.5 11926.5 ROP 11848.5 11962.0 $ LOG HEADER DATA DATE LOGGED: 01-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 40.4 MAXIMUM ANGLE: 44.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 78893 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 3.8 BOREHOLE CONDITIONS MUD TYPE: STARCH/BRINE MUD DENSITY (LB/G): 10.50 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 11962.0 11848.0 11962.0 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 41.0 9.0 2.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 API 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 71.7 First Name Min Max Mean Nsam Reading DEPT 11813.5 11962 11887.8 298 11813.5 GR 72.38 234.75 185.946 227 11813.5 ROP 2.03 38.48 10.6484 228 11848.5 First Reading For Entire File .......... 11813.5 Last Reading For Entire File ........... 11962 Last Reading 11962 11926.5 11962 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11927.0 11962.5 ROP 11962.5 12007.0 $ LOG HEADER DATA DATE LOGGED: 02-OCT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 37.9 MAXIMUM ANGLE: 37.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 72829 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER' S CASING DEPTH (FT) : 3 . 8 BOREHOLE CONDITIONS MUD TYPE: STARCH/BRINE MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S) : 41.0 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 12008.0 11962.0 12008.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.9 2.1 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 API 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 73.9 First Name Min Max Mean Nsam Reading DEPT 11927 12007 11967 161 11927 GR 158.93 261.02 212.821 72 11927 ROP 0.25 89.6 7.86711 90 11962.5 First Reading For Entire File .......... 11927 Last Reading For Entire File ........... 12007 Last Reading 12007 11962.5 12007 File,Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11963.0 ROP 12007.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: STOP DEPTH 12016.5 12067.0 03-0CT-98 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 12067.0 12008.0 12067.0 35.4 36.0 TOOL NUMBER SOLAR GM 78893 3.750 3.8 STARCH/BRINE 10.50 40.0 9.4 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3tTURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 API 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 71.7 First Name Min Max Mean Nsam Reading DEPT 11963 12067 12015 209 11963 GR 159.99 272.19 204.433 108 11963 ROP 1.21 1862.41 28.8866 120 12007.5 Last Reading 12067 12016.5 12067 First Reading For Entire File .......... 11963 Last Reading For Entire File ........... 12067 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12017.0 ROP 12067.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/O): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : STOP DEPTH 12074.5 12124.5 04-0CT-98 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 12125.0 12067.0 12125.0 37.1 40.0 TOOL NUMBER SOLAR GM 72829 3.750 3.8 STARCH/BRINE 10.50 42.0 8.7 FLUID LOSS (C3) : RESISTIVITY (OH/MM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.1 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 API 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 73.9 First Name Min Max Mean Nsam Reading DEPT 12017 12124.5 12070.8 216 12017 GR 142.33 245.1 206.281 116 12017 ROP 1.79 21.83 7.63122 115 12067.5 Last Reading 12124.5 12074.5 12124.5 First Reading For Entire File .......... 12017 Last Reading For Entire File ........... 12124.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12075.0 ROP 12126.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : STOP DEPTH 12179.0 12229.0 06-0CT-98 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 12229.0 12125.0 12229.0 42.4 42.9 TOOL NUMBER SOLAR GM 72829 3.750 3.8 STARCH/BRINE 10.50 43.0 8.9 2.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 API 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 76.7 First Name Min Max Mean Nsam Reading DEPT 12075 12229 12152 309 12075 GR 178.05 255.03 217.993 209 12075 ROP 0.29 32.08 12.5144 207 12126 Last Reading 12229 12179 12229 First Reading For Entire File .......... 12075 Last Reading For Entire File ........... 12229 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12179.5 ROP 12229.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12405.0 12455.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 07-0CT-98 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 12455.0 12229.0 12455.0 22.7 41.6 TOOL NUMBER SOLAR GM 78893 3.750 3.8 STARCH/BRINE 10.50 42.0 8.9 2.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 API 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 78.3 First Name Min Max Mean Nsam Reading DEPT 12179.5 12455 12317.2 552 12179.5 GR 105.47 232.92 155.23 452 12179.5 ROP 0.71 76.04 16.9244 452 12229.5 Last Reading 12455 12405 12455 First Reading For Entire File .......... 12179.5 Last Reading For Entire File ........... 12455 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12405.5 12960.0 ROP 12455.5 13010.0 $ LOG HEADER DATA DATE LOGGED: 10-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 15.0 MAXIMUM ANGLE: 22.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 78653 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 3.8 BOREHOLE CONDITIONS MI/D TYPE: STARCH/BRINE MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S): 45.0 MUD PH: 9.2 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 INSITE VER 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 13010.0 12455.0 13010.0 MUD AT M3LX CIRCULATING TERMPER3~TURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units .... ~ .................. Datum Specification Block sub-type...0 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 15 API 4 1 68 4 2 ROP MWD 15 FT/H 4 1 68 8 3 74.5 First Name Min Max Mean Nsam Reading DEPT 12405.5 13010 12707.8 1210 12405.5 GR 7.49 452.79 169.602 1110 12405.5 R0P 0.6 200.38 24.2328 1110 12455.5 Last Reading 13010 12960 13010 First Reading For Entire File .......... 12405.5 Last Reading For Entire File ........... 13010 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/11/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File