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Home My WebLink About195-047195047 by Date: 3/28/2019 30 52 8 Transmittal Number: 93660 ((VC D FE.CE BPXA WELL DATA TRANSMITTAL BAR 2q 2019 Enclosed is one disc containing the information listed below. AOGCC If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendallgbn.com. SW Name API Date Com an Description 03-09 500292036200 3/27/2019 BPXA COMPOSITED GYROSCOPIC SURVEY X-09 500292045500 3/6/2019 BPXA COMPOSITED GYROSCOPIC SURVEY IX -09A 1500292045501 3/6/2019 BPXA COMPOSITED GYROSCOPIC SURVEY LX -09B 1500292045502 3/6/2019 BPXA COMPOSITED GYROSCOPIC SURVEY Please Sign an&Re—tuinone cpoy of this transmittal to Thank you, .Mer Xendaff Subsurface Information Management GANCPDCAbp365.onmicrosoft com Alaska Oil & Gas Conservation Commission Department of Natural Resources ConocoPhillips Alaska, Inc. ExxonMobil, Alaska Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. \ 'ì 6 - 0 Ll / File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: o Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, NolType OVERSIZED o Logs of various kinds o Other COMMENTS: Scanned by: Beverl incent Nathan Lowell Date: Y --I /s/ J2..ß o TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /s/ -\I ~, ~ \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well o Oil 0 Gas 0 Suspended aD Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' SNL, 372' WEL, SEC. 07, T10N, R14E, UM At top of productive interval 359' SNL, 3744' EWL, SEC. 17, T10N, R14E, UM At total depth 684' SNL, 3998' EWL, SEC. 17, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 72.81' ADL 047475 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 07/06/1995 07/12/1995 2/22/2002 N/A MSL Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 1 21. Thickness of Permafrost 12446 8976 FTI 12442 8976 FTI 0 Yes aD No N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR 23. CASING SIZE 20" X 30" 13-3/8" 9-5/8" Classification of Service Well ~loCA11ONS , , ~ . . . . ... .. .. 7. Permit Number 195-047 302-030 8. API Number 50- 029-20455-01 9. Unit or Lease Name Prudhoe Bay Unit X-09A ~ 9~ 10. Well Number 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 7" 72# 47# 29# 6.5# L-80 L-80 L-80 L-80 CASING LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 8.5 cu vds Concrete Surface 2671' 17-1/2" 3720 cu ft Permafrost Surface 11871' 12-1/4" 1689 cu ft Class 'G'. 130 cu ft PF 11377' 12008' 8-1/2" 454 cu ft Class 'G' 11338' 12442' 3-3/4" None AMOUNT PULLED WT. PER FT. GRADE 2-7/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) None SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 10060' - 11403' PACKER SET (MD) 11327' 25. MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11190' P&A with 44 Bbls Class 'G', Squeezed to 2000 psi 10010' Set EZSV, Set Whipstock on top 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL CHOKE SIZE 1 GAS-OIL RATIO OIL GRAVITY-API (CORR) PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL ?R CORE DATA f'1\ r" fn, r'" ~ , .f C r>¡s Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit corøJðhiPs.\"" L. ~ ;;.v 1"J No core samples were taken. tvr'l GII~AL -.- Form 10-407 Rev. 07-01-80 .. ft ft "I '" 1'\". " D U f"hJ U, -¡:- Alas1<a OB & GD;: U.;,·.:,..;;;·", Änchoraç8 SCANNED JUL 1 0 2002 1VfAY 3 0 2002 Submit In Duplicate /".-...,\ ~ 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Shublik 12036' 8869' Sadlerochit 12305' 8950' 31. List of Attachments: Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date C1S. ;¡3 · 0 X-09A Well Number 195-047 302-030 Permit No.1 A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage 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 SCANNED JULIO Z002 f"'\ i ~ Page 1 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 pescriptionÇ)f Operations 3/8/2002 14:00 - 00:00 10.00 MOB P PRE RIG DOWN. MOVE PUMP AND PIT MODULE. RIG DOWN. LOWER DERRICK. START MOVING RIG UNIT AT 21:30 HRS 3/9/2002 00:00 - 14:00 14.00 MOB P PRE MOVE RIG UNIT TO WELL X-09B. MOVE PUMP/ PIT MODULE AND CAMP TO X PAD. RIG UP. SPOT PITS, CAMP, MECHANIC SHOP AND CUTTINGS BOX. RIG UP. 14:00 - 1S:00 P DECOMP ACCEPT RIG AT 14:00 HRS INSTALL SECONDRY VALVE ON ANNULUS. 1S:00 - 16:00 P DECOMP PRE-SPUD AND SAFETY MEETING WITH ALL PERSONNEL. 16:00 - 19:00 3.00 BOPSU P DECOMP PULL BACK PRESSURE VALVE. RECEIVE SEA WATER. SEA WATER TRUCKS DELAYED DUE TO WORK LOAD. 19:00 - 21:30 2.S0 BOPSU P DECOMP SAFETY STAND DOWN WITH ALL RIG PERSONNEL AND PEAK DRIVERS. 21 :30 - 00:00 2.S0 BOPSU P DECOMP DISPLACE FREEZE PROTECT WITH SEA WATER WHILE OFF LOADING VAC TRUCKS. 3/10/2002 00:00 - 02:30 2.S0 BOPSU P DECOMP DISPLACE FREEZE PROTECT AND CIRCULATE WELL WITH SEA WATER AT 3 BPM. 02:30 - b3:00 O.SO BOPSU DECOMP RIG DOWN CIRCULATING LINES. 03:00 - 03:30 O.SO BOPSU DECOMP INSTALL TWO WAY CHECK VALVE AND TEST TO 1000 PSI. 03:30 - OS:OO 1.S0 BOPSU DECOMP SAFETY STAND DOWN WITH DRILLING CREW. OS:OO - 07:00 2.00 BOPSU DECOMP NIPPLE DOWN TREE AND ADAPTOR FLANGE. 07:00 - 10:00 3.00 BOPSU DECOMP NIPPLE UP BOP. 10:00 - 10:30 O.SO BOPSU DECOMP RIG UP TO TEST BOP. 10:30 - 1S:00 4.S0 BOPSU DECOMP TEST BOP AND RELATED EQUIPMENT. 2S0 PSI LOW, 3S00 PSI HIGH. NOTE: JOHN CRISP OF AOGCC WAIVED WITNESSING TEST 1S:00 - 16:00 1.00 BOPSU DECOMP RIG UP DSM LlBRICA TOR. PULL TWC. 16:00 - 17:30 1.S0 PULL DECOMP PULL TUBING HANGER. PROBLEMS BACKING OUT LOCK DOWN SCREWS. 17:30 -18:30 1.00 PULL P DECOMP UNSEAT HANGER. WORK STRING. 40K OVER PULL. PULL TUBING HANGER TO FLOOR AND LAY DOWN SAME. 18:30 - 19:30 1.00 PULL P DECOMP RIG UP 4 1/2" TUBING EQUIPMENT AND CONTROL LINE SPOOLER. PJSM. 19:30 - 22:00 2.S0 PULL P DECOMP POH. LAY DOWN 41/2"12.6# BTC TUBING. NORM INSPECT TREE, TUBING HANGER AND FIRST 10 JOINTS. 22:00 - 22:30 O.SO PULL P DECOMP LAY DOWN SSSV. RIG DOWN CONTROL LINE SPOOLER. 22:30 - 00:00 1.S0 PULL P DECOMP POH LAY DOWN 41/2" TUBING. 3/11/2002 00:00 - 06:00 6.00 PULL P DECOMP POH LAY DOWN 41/2" TUBING. TOTAL OF 236 JTS AND 12.7S' CUT OFF STUB. 06:00 - 07:30 1,SO PULL P DECOMP RIG DOWN TUBING HANDLING EQUIPMENT AND CLEAN FLOOR. 07:30 - 09:30 2.00 CLEAN P DECOMP MAKE UP 8 112" MILLING BHA. 09:30 - 10:30 1.00 CLEAN P DECOMP PICK UP S" DRILL PIPE AND RIH TO 1788'. 10:30 - 11 :30 1.00 CLEAN P DECOMP MAKE UP RTTS PACKER AND RIH TO 33'. 11:30 -12:00 O.SO CLEAN P DECOMP SET RTTS PACKER AND TEST TO 1S00 PSI. 12:00 - 13:30 1.S0 BOPSU P DECOMP NIPPLE DOWN BOP. 13:30 - 23:30 10.00 BOPSU P DECOMP REMOVE TUBING SPOOL. PROBLEMS REMOVING LOCK DOWN SCREW. CHAGE OUT 13 S/8" x 9 S/8' CASING PACK OFF AN DTEST TO SOOO PSI. INSTALL TUBING SPOOL. 5CANNEDt:JUll2'f {l12n02 I~ I " R.::' . ..~. ...(.......... 1::"..,. .f. t. in !i ". 1. ,P..... I '{ 8.p~e2 ofG Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Alaslm OB & be:J <';Li¡:~, l¡(¡mmìsslO spu~~g~~~/1980 Start: 3/9/2002 End: 3/26/2002 Rig Release: 3/26/2002 Rig Number: :;[\0 ? !.- 'OJ....' l...-... NIPPLE UP BOP. NIPPLE UP BOP. TEST UPPER PIPE RAMS AND BOTTOM FLANGE TO 250 PSI LOW AND 5000 PSI HIGH. TEST LOWER PIPE RAMS, ANNULAR, LOWER KELL Y COCK AND TIW TO 250 PSI LOW AND 3500 PSI HIGH. 05:00 - 05:30 DECOMP INSTALL WEAR BUSHING. 05:30 - 08:00 DECOMP PULL RTTS PACKER AND LAY DOWN SAME. 08:00 - 15:30 DECOMP PICK UP 5" DRILL PIPE AND RIH WITH MILL BHA TO 4 1/2" TUBING STUMP AT 10070' 15:30 - 16:30 1.00 BOPSU DECOMP CIRCULATE BOTTOMS UP AT 586 GPM. 16:30 -19:00 2.50 BOPSU DECOMP POH WITH 5" DRILL PIPE TO 4134' 19:00 - 20:00 1.00 BOPSU DECOMP SLIP AND CUT DRILLING LINE. 20:00 - 20:30 0.50 BOPSU DECOMP SERVICE TOP DRIVE. 20:30 - 21 :30 1.00 BOPSU DECOMP POH TO BHA. 21:30 - 22:00 0.50 BOPSU DECOMP POH MILL BHA, 22:00 - 22:30 0.50 BOPSU DECOMP RIG UP SCHLUMBERGER E-LlNE UNIT. PJSM WITH RIG CREW, SCHLUMBERGER CREW AND HALLlBUTRON BRIDGE PLUG TECH. 22:30 - 00:00 DECOMP RIH WITH 9 5/8" EZSV BRIDGE PLUG ON E-LlNE. 3/13/2002 00:00 - 02:00 DECOMP RIH WITH 9 5/8" EZSV BRIDGE PLUG ON E-LlNE AND SET AT 10010'. GOOD INDICATION THAT BRIDGE PLUG SET BUT UNABLE TO RELEASE TOOLS. 02:00 - 02:30 DFAL DECOMP INSTALL "T" BAR TO WIRELlNE, PULL UP WITH BLOCKS AND PULL OUT OF ROPE SOCKET 02:30 - 04:00 DECOMP POH WITH WIRE LINE AND RIG DOWN SCHLUMBERGER. 04:00 - 06:00 DFAL DECOMP MAKE UP FISHING BHA WITH 3 3/8" OVER SHOT GRAPPLE AND 8 1/8" GUIDE. 06:00 - 09:00 DFAL DECOMP RIH WITH 5" DRILL PIPE TO 9994'. 09:00 - 10:00 DFAL DECOMP ENGAGE FISH. PULL E-LlNE TOOLS FREE FROM BRIDGE PLUG. 10:00 - 11 :00 1.00 BOPSU DECOMP TEST 9 5/8" CASING TO 3500 PSI FOR 30 MINUTES. 11 :00 - 14:00 3.00 BOPSU DFAL DECOMP POH WITH OVERSHOT AND E-LlNE TOOLS. 14:00 - 15:00 1.00 BOPSU DFAL DECOMP POH WITH FISHING BHA. 15:00 - 16:30 1.50 BOPSU N DFAL DECOMP LAY DOWN FISH. CLEAR RIG FLOOR. 16:30 - 19:30 3.00 STWHIP P WEXIT MAKE UP 8 1/2" MILLING ASSEMBLY, MWD AND WHIPSTOCK. PJSM. 19:30 - 20:00 0.50 STWHIP P WEXIT SURFACE TEST MWD. 20:00 - 00:00 4.00 STWHIP P WEXIT RIH WHIPSTOCK AND MILLING BHA ON 5" DRILL PIPE TO 7992'. 3/14/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT RIH WHIPSTOCK AND MILLING BHA ON 5" DRILL PIPE TO 9960', 01 :30 - 02:30 1.00 STWHIP P WEXIT ORIENT WHIPSTOCK 85 DEG RIGHT OF HIGH SIDE. TAG UP ON EZSV AT 10013'. SET WHIPSTOCK BOTTOM ANCHOR WITH 25,000 LBS. SHEAR PIN ON WHIPSTOCK WITH 45,000 LBS. 02:30 - 04:00 1.50 STWHIP P WEXIT CIRCULATE AND DISPLACE SEA WATER WITH LSND 10.8 PPG MUD. 04:00 - 18:30 14.50 STWHIP P WEXIT MILL 81/2" WINDOW FROM 9991' TO 10024' 18:30 - 19:30 1.00 STWHIP P WEXIT CIRCULATE AND PUMP LOW VIS SWEEP AROUND. WORK MILLS ACROSS WINDOW. 19:30 - 20:30 1.00 STWHIP P WEXIT PERFORM FIT TO 12.0 PPG EMWWITH 472 PSI. 20:30 - 23:00 2.50 STWHIP P WEXIT SLIP AND CUT DRILLING LINE. 5CANNEÕìntjÙt12f2d 1îbOör ~, ---... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-09 X-09B REENTER+COMPLETE NABORS NABORS 2ES Page 3 of6 Start: 3/9/2002 Rig Release: 3/26/2002 Rig Number: Spud Date: 6/1/1980 End: 3/26/2002 3/15/2002 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 11 :00 11:00 -13:00 13:00 - 15:30 15:30 -16:30 1.50 S1WHIP P 1.50 S1WHIP P 1,00 S1WHIP P 0.50 S1WHIP P WEXIT WEXIT WEXIT WEXIT 0.50 DRILL P 1.50 DRILL P INT1 INT1 0.50 DRILL P INT1 1.50 DRILL P INT1 1.00 DRILL P 1.00 DRILL P 0.50 DRILL P 2.00 DRILL P 2,50 DRILL P 1.00 DRILL P INT1 INT1 INT1 INT1 INT1 INT1 3/16/2002 00:00 - 09:00 09:00 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 00:00 3/17/2002 00:00 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 08' 08:00 9:00 o . 0 - 11 :30 P INT1 9.00 DRILL P INT1 1.50 DRILL P 1.00 DRILL P INT1 INT1 0.50 DRILL P 12.00 DRILL P INT1 INT1 2.50 DRILL P INT1 1.00 DRILL P 1,50 DRILL INT1 , 0 DRILL P 1.00 DRILL P 1,00 DRILL P 1.00 DRILL P 2.50 DRILL P INT1 INT1 INT1 INT1 INT1 1.50 DRILL P INT1 POH TO MILLING BHA. LAY DOWN MILLING BHA. UPPER MILL FULL GAGE. CLEAN FLOOR. PULL WEAR BUSHING. WASH WELL HEAD AND BOP WITH JETTING TOOL. RUN TEST PLUG AND TEST JOINT. TEST BOP AND ASSOCIATED EQUIPMENT 250 PSI LOW, 3500 PSI HIGH FOR 5 MINUTES. CHOKE MANIFOLD TESTED WHILE POH. NOTE: TEST WITNESS WAIVED BY JEFF JONS OF AOGCC. PULL TEST PLUG AND TEST JOINT. INSTALL WEAR BUSHING. MAKE UP 81/2" DRILLING BHA WITH MUD MOTOR AND MWD. UP LOAD MWD. MAKEUPBHA. SHALLOW TEST MWD. OK. PICK UP 5" DRILL PIPE AND RIH TO 2793' RIH WITH 5" DRILL PIPE TO 9933' ORIENT TOOLS ABOVE WINDOW. WORK BIT THROUGH WINDOW WITH NO PROBLE DRILL 81/2" DIRECTIONAL HOLE FROM 10024' TO 10339' SLIDING TIME-4 HRS ROTATING TIME-0.5 HRS DRILL 81/2" DIRECTIONAL HOLE FROM 10339' SLIDING TIME-3.7 HRS ROTATING TIME-2.3 HRS CIRCULATE BOTTOMS UP. MONI WELL, STATIC. POH SHORT TRIP TO 9 5/8" C G WINDOW. NO PROBLEMS. TAKE SURV HECK SHOTS AT 10464', 10433', 10370' AND 10 RIH TO BOTTOM PROBLEMS. DRILL 81/2" ECTIONAL HOLE FROM 10871' TO 11716' SLIDING E-1.5 HRS ROT NG TIME-5.8 HRS LL 81/2" DIRECTIONAL HOLE FROM 11716' TO 11792' SLIDING TIME-0.7 HRS ROTATING TIME-0.6 HRS LOST 60% RETURNS WHILE CIRCULATING. MONITOR WELL. STATIC LOSS RATE 10 BPH. MIX LCM PILL SPOT 40 BBL LCM PILL WITH 30 LBS / BBL LCM ON BOTTOM. LOSS RATE WHILE SPOTTING PILL 3.5 BBU MIN. LOST 100 BBL WHILE CIRCULATING. WHEN LCM PILL GOT TO BOTTOM LOSS SLOWED THEN STOPPED. POH TO 9 5/8" CASING WINDOW. SLIP AND CUT DRILLING LINE. SERVICE TOP DRIVE. RIH TO BOTTOM. CIRCULATE AND SPOT LINER RUNNING PILL. SLOW LOSSES WHILE CIRCULATING. TOTAL LOSS 140 BBL. POH TO CASING WINDOW. SLM. DROP RABBIT. SCANNEC"tju4[l2r Ò1:2ÔOr STATE OF ALASKA ALASKA \.IlL AND GAS CONSERVATION COMtvl'lvSION APPLICATION FOR SUNDRY APPROVAL \tJ6A- II LL( r;; ~ ðfv1t\ \ 1]- q lo-z- 4r-l{d--~-O~ 1. Type of Request: II Abandon 0 Suspend II Plugging 0 Time Extension 0 Perforate o Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance II Other o Change Approved Program 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 5. Type of well: IBI Development o Exploratory o Stratigraphic o Service 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 453' SNL, 372' WEL, SEC. 07, T10N, R14E, UM At top of productive interval 359' SNL, 3744' EWL, SEC. 17, T10N, R14E, UM At effective depth 681' SNL, 3996' EWL, SEC. 17, T10N, R14E, UM At total depth 684' SNL, 3998' EWL, SEC. 17, T10N, R14E, UM f, f:: (~ ,) ,L\ N ? :1; i) !~,ia8ka OJ¡ & Gas Cons. Com¡rì¡&;iIÍìI Ane; :l)mf¡A 12. Present well condition summary Total depth: measured 12446 feet true vertical 8976 feet Effective depth: measured 12442 feet true vertical 8976 feet Casing Length Size Structural Conductor 110' 20" x 30" Surface 13-3/8" 2671' Intermediate 9-5/8" 11871' Production Liner 631' 7" Sidetrack Liner 1104' 2-7/8" Plugs (measured) Junk (measured) Cemented 8.5 cu yds Concrete 3720 cu ft Permafrost 1689 cu ft Class 'G', 130 cu ft PF 454 cu ft Class 'G' None Perforation depth: measured 12040' - 12060', 12140' - 12160', 12330' - 12350', 12405' - 12425' true vertical 8871' - 8880', 8908' - 8914', 8955' - 8959', 8969' - 8973' Tubing (size, grade, and measured depth) 6. Datum Elevation (DF or KB) RKB = 72.81' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number X-09A 9. Permit Number 195-047 10. API Number 50- 029-20455-01 11. Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool MD TVD 110' 2671' 11871' 110' 2671' 8772' 11377' - 12008' 11338' - 12442' 8469' - 8853' 8444' - 8976' 4-1/2", 12.6#, L-80 to 11327' with 4-1/2" Tailpipe to 11403' Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker 'SAB' packer at 11327'; 4-1/2" Otis SSSV Landing Nipple at 2139' 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing operation February 1, 2002 16. If proposal was verbally approved o Detailed Operations Program 15. Status of well classifications as: IBI Oil 0 Gas 0 Suspended Service o BOP Sketch Name of approver Date Approved Contact Engineer Name/Number: Dave Wesley, 564-5773 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I ~ereby certify that the foregoi is true and COt ect to the best of my knowledge Signed Brian Robertson ~ 'I Title Senior Drilling Engineer Date # i::¡¡' ()'l,.. ·C9IÌfmi~i()n US'eOnly Conditions of Approval: Notify Commission so representative may, witness ·;'500 pSt 0 {:: Plug integrity _ BOP Test -À- Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- Y (; 1 Approval No. 30~- 0 W ClÇ+e--V 'Y~ ~~c;.~<- t'-. Ù' ~'("Ltf (. ; / '/ i " , I'" 'I I" " Commissioner Date i· , }--- í ,'v:' 1 Submit In Triplicate bp ... $:> ,% 4J,~+it" To: Tom Maunder - AOGCC Date: January 17, 2002 From: Dave Wesley - BPXA GPB Rotary Drilling Subject: Reference: DS X-09A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20455-01 Approval is requested for the proposed P&A of P8U well X-09A. This well has not produced since 1992. The original well, X-09, was drilled in 1980. From 1987 to 1991, production steadily declined, as we increased. The Ivishak was hydraulically fractured in 1991. Increased communication with t~aquifer was recognized, and the well was shut in November of 1992. X-09 was sidetracked as X-09A in 1995. This well bore failed to produce at economic rates, and as such, was never connected to production facilities. Frac sand obtained in drill cuttings supports the belief that X-09A intersected the earlier Ivishak frac. ./' The 9 5/8" casing has been determined to be competent via a CM IT to 3000 psi conducted on 11/12/01. There is a known Tubing X IA communication via a hole in the pup joint below the GLM#2, at a depth of 10,895' MD."'The last caliper was run in the tubing in 1992, and showed the tubing in moderate condition. The new well bore is proposed as a conventional sidetrack, targeting Zone 48 reserves, southwest of the current location. / The X-098 sidetrack is currently scheduled for Nabors 2ES beginning around March 1, 2002, after the completion of the 5-32A sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Pre-Ria Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Rig up slick line. Dummy off any remaining live GL V's above the planned 4 Y2" tubing cut depth at 1 0,050' MD. Drift 4 Y2" X 2 7/8" tubing to top of fill and document for upcoming cement P&A and tubing cut. If fill is tagged too high to allow the tubing cut at 10,050' MD, contact Drilling Engineer to discuss options. / 2. Rig up CTU. Perform a cement P&A of the Zone 48 perforations with 15.8 ppg class 'G' cement, using aggregate as required to aid in plugging perforations..,)Jse adequate cement volume to fill the 2 7/8" liner from the top of fill to the top of 2 7/8" at 11,338' MD, and fill the 4 1/2" tubing to a ~ximum depth of 11,200'''/MD (cover the sliding sleeve), plus squeeze../a minimum of 5 bbls into the perforations. Estimated minimum cement volume needed is 13.5 barrels. Do not exceed squeeze pressure of 3500 psi. 3. Rig up slick line and drift the 4 Y2" tubing to the top o~cement. The Drift run is to verify the tubing is clear to the proposed tubing cut depth of 10,050' MD, and may be run at the discretion of the Wells G rou p. 4. Rig up E-line. Cut the 4Y2" L-80 tubing at 10,050' MD. This cut will not be fished, so the use of a jet or chemical cutter is at the discretion of the Wells Group Representative. X-09A Application for Sundry 1 r- ~ 1 ~v .. <1 .l 'O'? \l' . 1')'- ~~ D Pi If, D1 5. Displace the well to clean seawater by circulating down tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel. 6. Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 7. Set a BPV in the tubing hanger. Secure well. 8. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 4 1/2" tubing from tubing cut and above. 5. P/U milling assembly and 4: drill pipe. RIH and drift to tubing cut. POOH and stand back BHA. 6. MU bridge plug. RIH and set at y>,020' MD. 7. Pressure Test well bore to 3500 si for 30 minutes. 8. RIH with 9 5/8" Baker whip stock assembly. Orient whip stock as desired and set on bridge plug. Mill window in 9 5/8" casing at 10,000' MD. POOH. 9. RIH with 8-1/2" drilling assembly (with MWD/GR) to whip stock. Kick-off and drill the 8-1/2" intermediate section to Top Sag -11,847' MD (-8875' TVD). 10. Run and cement 7",26# intermediate drilling liner to -150' back into window. POOH. 11. Make,)!p and RIH with a 6-1/8" directional assembly (with MWD/GR/RES). Test the 7" casing to 3500 psi for 30 minutes. / 12. Drill 6-1/8" production section as per directional plan to an estimated TO of 14,417' MO (-9040' TVD). 13. Run a 4 V2", 12.6# slotted production liner throughout the 6-1/8" well bore. Displace well to clean seawater above liner top. POOH. 14. Run the 4 1/2",12.6# L-80 completion, tying into the 4-1/2" lineytop. 15. Drop Ball and Rod to set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well to -2200' and secure the well. 18. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHe plug from 'X' nipple below the production packer and install gas lift valves. Estimated Pre-rig Start Date: 02/01/02 Estimated Spud Date: 03/01/02 Dave Wesley Operations Drilling Engineer 564-5773 X-09A Application for Sundry TREE: 6" CIW WELLHEAD: MCEVOY ACTUATOR: OTIS 95/8" DV PACKER 1 2578'1 13-3/8", 72 #/ft, L-80, BTRS 12671'1- KOP: 2800' MAX ANGLE: 62°/12,500' 4-1/2", 12.6#/ft, L-80, IPC, TUBING TUBING ID: 3.958 " CAPACITY: 0.01522 BBLlFT Top of 27/8" Liner 111,338' I TOP OF 111 377" 7" LINER·' . - 9-5/8", 47#/ft, 111,871'1- L-80, BTRS TOP OF WHIPSTOCK 112006' 1- PERFORATION SUMMARY REF LOG: Radius Inc. GR 7/11/95 SIZE SPF INTERVAL OPEN/SQZ'D 1-9/1 4 12040-12060' Open 10/17/95 1-9/1 4 12140-12160' Open 10/17/95 1-9/1 4 12330-12350' Open 10/17/95 1-9/1 4 12405-12425' Open 7/30/95 3-3/8" 4 11,995 - 12,027' P&A'd 7/95 3-3/8" 4 12,168 - 12,185' 3-3/8" 4 12,189 -12,213' 3-3/8" 4 12,230 - 12,262' 2-7/8" 4 12,268 - 12,287' REF LOG: SWS - BHCS 06-29-80 PBTD 7" , 29 #/ft, L-80, BTRS ]13.466'1 113.528'1- DATE 07 -08-80 12/25/90 07-31-95 10/17/95 12/25/98 X-09A fI> o o I I REV. BY COMMENTS INITIAL COMPLETION RDC REPERF LMH Post CT Sidetrack Liner Perfs CJS CT Add Perfs GLM Update to PC KB. ELEV = 72.81' BF. ELEV = 40.38' SSSV LANDING NIPPLE I 2139' I ( OTIS )( 3.813 " ID) GAS LIFT MANDRELS (OTIS W / RA LATCH) N° MD(BKB) TVDss DEV. 5 3005' 2931' 9° 4 5631' 4918' 54° 3 9142' 6923' 50° 2 10,895' 8083' 18° 1 11,141' 8244' 50° SLIDING SLEEVE OTIS "XA" (3.813" ID) TUBING SEAL ASSY. !20' BAKER SBR (BAKER SAB)(3.813"ID) 111,236'1 111,308" 111,327' 1 4-1/2", 12.6 #/ft, L-80 TAILPIPE 4-1/2" "X" NIPPLE 1 'I (OTIS) (3.813" ID) 11,371 4-1/2" "XN" NIPPLE I ' I (OTIS) (3.725" ID) 11,401 4-1/2" TBG TAIL 111,403' 1 (3.958"ID) I ' I (ELM D) 11,403 112,446'1 '2 ' 10111' II I [) /12210'1 112221' I 112400'1 FISH - 15' TAILPIPE COVERED W / CEMENT PRUDHOE BAY UNIT WELL: X-09L 1 (31-17-10-14) API NO: 50-029-20455- SEC 7' TN 10N . RGE 14E BP Exploration (Alaska) TREE = 6" CrN WELLHEAD= MCEVOY AcruAroR;;^' muu,uu^'UÓflS KB. B...EV = 72.81' BF. B...EV = 40.38 X-09A Pre Rig Max Angle = ·.·.·.·.·.·.·.·_·.·.·.·.·.·_·_·_W_WN.-.·~.·.·.·.·.·.··········J_·_·_·_~_·_~.w.-.w_-.-.·.- Datum MD = ~·_"W_y.-.-._._.·._.______. _,. W_='.w.-.-.-.-.-.- Datum ìVDss= 19 5/8" DV Packer l-f 25781 o o -1 4 1/2" X Landing Nipple, ID=3.813 113-3/8" 72#, L80, BTRS Casing 1---1 26711 14 1/2" 12.6# L-80 Tubing I Top of cement plug l-l 122101 I Pre-rig tubing cut l-l 10,0501 l-l 11,2001 I OTIS "XA" Sliding Sleeve 1-1 112361 I ITubing Seal Assembly 1---1 113081 I- I Baker SAB Packer; 3.813" I.D. 1---1 113271 1- ITOP OF 2-7/8" Linerl-l 113381 I I TOP OF 7" Liner 1-1 113771 1- 19-5/8" 47#, L80, BTRS Csg l-l 118711 I Top of Whipstock l-l 120061 I I Pre-rig CTU Cement P&A; TOC 113711 1-l4-1/2" OTIS 'X' NIP, ID=3.813 I 114011 1-l4-1/2" OTIS 'XN' ; ID=3. 725 114031 1-l4-1/2" TBG TAIL, 10=3.958 I I Fish - 15' tailpipe covered w I cement I 124421 1-l2 7/8" shoe 1 124461 1-1 Sidetrack TD I 7" 29#, L80, BRTS Liner I PBTD l-l 134661 l-f 135281 DA TE REV BY COMMENTS 01/17/02 DEW Proposed Pre Rig CTU Cement P&A; Tubing cut. PRUDHOE BA Y UNrr WB...L: X-09B ÆRMrr No: API No: 50-029-20455 Sec. 7, T10N, R14E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 TREE = . 6" CrN WEtLHEAD= MCEVOY m....·'....,__·_v_·_·_·....m...m'.....___~_._·,........ A CTUA TOR= OTIS u . ,nHW._~~_ . no ..._~_._......-.v.v.-~._.... KB. REV = 74.88 ._u............m._.~_______mm........ BF. REV = 40.38 CROp';YC . u.. . mU"'''1Õ:ÕOO -.-.-.-.-.-.-.-.-.-.------~.'--.-.-.-.-...-.-.-.-.-.-.-.-.'.'.-.-.'.-.-.-...'..-..'.'._'.-.-.-.-.-.-.-.-.-.-.-.-.-.---.---~'.-.......-.-.-.-.-.-.-.-.-.-.---.-..-.-.-.,-.',-.-.-.-.-.'.-.-.-. .~.~.~~§~..=.~~~:~:c~^~~~Xg Datum MD = 12150' 'w_~~u___~ ....,_._.,_._.' _~~__".~_~.,_._._.__. Datum 1VDss= 8880' ~. X-O~J Proposed CO~.lpletion 1 Top of Whip-stock l-i 10,000' I I Bridge Plug l-i 10,020' I~ I Pre-rig tubing cut l-l 10,050' I I OTIS "XA" Sliding Sleeve l-i 11236' I- I Tubing Seal Assembly l-i 11308' I- I Baker SAB Packer; 3.813" I.D. l-i 11327' 1- ITOP OF 2-7/8" Linerl-l 11338' I TOP OF 7" Liner l-l 11377' 19-5/8" 47#, L80, BTRS Csg l-i 11871' I Top of Whipstock 1-1 12006' I 19 5/8" DV Packer l-i 113-3/8" 72#, L80, BTRS Casing l-l 2671' 14 1/2" 12.6# L-80 Tubing. I Baker 'ZXP Liner top pkr; 'Hrv1C' Liner hanger l-l 9850' I Top of cement plug l-l 12210' I Fish - 15' tailpipe covered w I cement 17" 29#, L80, BRTS Liner I PBID l-l 13466' l-i 13528' DATE 01/17/02 REV BY DBN COMMENTS Proposed Sidetrack w I a Slotted liner Completion -14 1/2" X Landing Nipple, ID=3.813 2578' o o ST MD 5 3625 4 5769 3 8047 2 9848 1 11193 o o GAS LIFT MANDRELS 1VD DEV TYÆ SIZE L TCH 3400 9° OTIS 4 1/2 RA 5000 54° OTIS 4 1/2 RA 6350 50° OTIS 4 1/2 RA 7500 42° OTIS 4 1/2 RA 8500 42° OTIS 4 1/2 RA COMMENTS 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 1/2 4 1/2 X 1 4 1/2 X 1 11615' 1-14-1/2" 'X' Nipple, 10=3.813 11640' 1-l7" X 4 1/2" Baker S-3 Packer Baker 5" X 7" Tie Back Sleeve; 'ZXP Liner top packer; 'HMC' Liner hanger 1-l7" 26#, L-80 BTCM Liner .::::::=:=::::J .::::::=:=::::J .::::::=:=::::J .::::::=:=::::J .::::::=:=::::J t:::::==:J t:::::==:J / 14417' 1-i4-1/2" 12.6# L-80 Slotted Liner I 11371' 1-l4-1/2" OTIS 'X' NIP, ID=3.813 1 11401' l-i 4-1/2" OTIS 'XN' ; ID=3.725 11403' 1-i4-1/2" TBG TAIL, 10=3.958 I 12442' l-i 2 7/8" shoe I 12446' l-i Sidetrack TD PRUDHOE BA Y UNrT WELL: X-09B ÆRMrr No: API No: 50-029-20455 Sec. 7, T10N, R14E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 - -=--,--.-- f'-i ..,~ bp J""-~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 24,2001 Commissioner Julie Heusser Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Well Re-Naming Dear Commissioner Heusser: The operator requests the following Prudhoe Bay well and associated API number to be renamed. The well X-09A has been carrying an API suffix of -60 (used for a lateral well). Subsequent sundries then picked up the -60 API and assigned an L 1 to the well name. Old API Number Old Name Permit Number New API Number New Name 50-029-20455-60 X-09L1 195-047 50-029-20455-01 X -09 A Sincerely, 1!.~~ , Brandon c:t1<rance Production Engineer, GPB-PWZ BGF:pjp Cc: Well File Gary Benson Shannaine Copeland Amy Frankenburg Terri Hubble G ANC PDC /--. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: NAME CHANGE 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown_ Pull tubing 452' FNL, 372' FEL, Sec. 07, T10N, R14E, UM At top of productive interval 607' FNL, 1348' FEL, Sec. 17, T10N, R14E, UM At effective depth 681' FNL, 1283' FEL, Sec. 17, T10N, R14E, UM At total depth 684'FNL, 1280'FEL, Sec. 17, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Liner SideTrack Liner Length 110' 2638' 11838' 631' 1104' Size 20" x 30" 13-3/8" 9-5/8" 7" 2-7/8" Perforation depth: Stimulate Alter casing 5. Type of Well: Development _X Exploratory_ Stratigraphic_ Service (asp's 665523,5939668) (asp's n/a) (asp's 670031, 5934259) (asp's 670034,5934256) 12446 feet 8976 feet Plugs (measured) Plugging _ Perforate Repair well _ Other _X NAME CHANGE 6. Datum elevation (DF or KB feet) RKB 73 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 195-047 10. API number 50-029-20455-01 50-029-20455-60 11. Field / Pool Prudhoe Bay Oil Pool Measured Depth 143' 2671' 11871' 11377' - 12008' 11338' - 12442' True Vertical Depth 143' 2671' 8771' 8469' - 8853' 8444' - 8976' 12442 feet 8976 feet Junk (measured) measured Open Perfs 12040' - 12060', 12140' - 12160', 12330' - 12350', 12405' - 12425' Cemented 76.5 c.t. concrete 3720 c.f. Arcticset II 1819 c.f. true vertical Open Perfs 8872' - 8880', 8909' - 8914', 8955' - 8959', 8969' - 8973' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG to 11327' with 4-1/2" Tailpipe to 11403'. ~:; t: p (.. . ) Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" Baker SAB Packer @ 11327'. ''.¡as:;,: Oil (~:JE: (;un:: 4-1/2" Otis SSSV Landing Nipple @ 2139'. ''.:ìC!irJ¡:~rw 13. Stimulation or cement squeeze summary Well is currrently shut-in with no plans to produce trom this wellbore X-09L 1 . Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil X Gas Suspended 1 µ that e foregoing is true and correct to the best :i:I:Yp:~:h:~e:::~ Pad Production Engineer Brandon France Form 10-404 Rev 06/15/88 · ORIGINAL Service TREE: 6" CIW WELLHEAD: MCEVOY ACTUATOR: OTIS X-09A KB. ELEV = 72.81' BF. ELEV = 40.38' 95/8" DV PACKER 12578'1 e SSSV LANDING NIPPLE I 2139' I ( OTIS)( 3.813" ID) o o GAS LIFT MANDRELS (OTIS W/ RA LATCH) N° MD(BKB) TVDss DEV. 5 3005' 2931' 9° 4 5631' 4918' 54° 3 9142' 6923' 50° 2 10,895' 8083' 18° 1 11,141' 8244' 50° 13-3/8", 72 #/ft, L-80, BTRS 12671'1- KOP: 2800' MAX ANGLE: 62°/12,500' 4-1/2", 12.6#lft, L-80, IPC, TUBING TUBING ID: 3.958 " CAPACITY: 0.01522 BBUFT I I SLIDING SLEEVE OTIS "XA" (3.813" 10) TUBING SEAL ASSY. !20' BAKER SBR (BAKER SAB)(3.813"ID) 4-112", 12.6 #/ft. L-80 TAILPIPE 4-1/2" "X" NIPPLE I ' I (OTIS) (3.813" ID) 11,371 4-1/2" "XN" NIPPLE I ' I (OTIS) (3.725" ID) 11,401 4-1/2" TBG TAIL 111,403' I (3.958"ID) I 1 403' I (ELMD) 1, 111,236' 1 111,308' 1 111,327' 1 9-5/8", 47#/ft, L-80, BTRS 111,871' 1- 112,446' I Top of 27/8" Liner 111,338' 1 TOP OF 111 377' 1 7" LINER ' TOP OF WHIPSTOCK 112006' 1- PERFORATION SUMMARY REF LOG: Radius Inc. GR 7/11/95 SIZE SPF INTERVAL OPEN/SQZ'D 1-9/1 4 12040-12060' Open 10/17/95 1-9/1 4 12140-12160' Open 10/17/95 1-9/1 4 12330-12350' Open 10/17/95 1-9/1 4 12405-12425' Open 7/30/95 3-3/8" 4 11,995 -12,027' P&A'd 7/95 3-3/8" 4 12,168 -12,185' 3-3/8" 4 12,189 -12,213' 3-3/8" 4 12,230 - 12,262' 2-7/8" 4 12,268 - 12,287' REF LOG: SWS - BHCS 06-29-80 112210' 1 112221' I 112400' I FISH -15' TAILPIPE COVERED W/ CEMENT PBTD 113.466' I 7" , 29 #/ft, L-80, BTRS 113.528' I - DATE 07-08-80 12/25/90 07-31-95 10/17/95 12/25/98 REV. BY COMMENTS INITIAL COMPLETION RDC REPERF LMH Post CT Sidetrack Liner Perfs CJS CT Add Perfs GLM U date to PC PRUDHOE BAY UNIT WELL: X-09L 1 (31-17-10-14) API NO: 50-029-20455- SEC 7' TN 10N . RGE 14E BP Exploration (Alaska) ...,-. /- ALM STATE OF ALASKA -=r, OIL AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPER-A TIONS 1. Operations performed: Operation shutdown_ Pull tubing_ Stimulate _ Plugging_ Alter casing _ Repair well_ S. Type of Well: Development _ Exploratory _ Stratigraphic _ Service _ 2. Name of Operator BP Exoloration (Alaska) Inc. 3. Address P. O. Box 196612. Anchoraae. Alaska 99519-6612 4. Location of well at surface 453' SNL. 372' WEL. SEC, 04, T10N, R14E. UPM At top of productive interval 607' SNL. 1348' WEL. SEC. 17. T10N. R14E. UPM At effective depth NIA At total depth 809' SNL. 1009' WEL. SEC. 17. T10N. R14E. UPM 12. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Structu ral Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 110 2638 11838 20x30 13 3/8 95/8 8.5 c.V. 3720 c.f. 1819 c.f. measured 12040~12060~ 12140~12160~ 12330~12350~ 12405~12425' true verticaÞubsea 8799'-8807'; 8836'-8841'; 8882'-8886'; 8896'-8900' Perforate_ Other -x- 6. Datum elevation (DF or KB) B-2 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-09L 1 (41-17-10-14) 9. Permit number/approval number 95-47 195-086 10. API number 50- 029-20455-60 11. Field/Pool Prudhoe Oil Pool 143 2671 11871 True vertical depth BKB 143 2671 8771 RECEIVED AUG 24 1998 Tubing (size, grade, and measured depth)4 112" L-80 to 11327' with 4 112" tailpipe to 11433' Alaska Oil & Gas Cons. Commission Packers and SSSV (type and measured depth:9 518" Baker SAB packer at 11327';4 112" SSSV at 2139' Anchorage Intervals treated (measured) 13. Stimulation or cement squeeze summary well currently shut in with no plans to produce unless sidetracked in the future Treatment description including volumes used and final pressure 14. " i ~ I ".J ¡" -\ L_ Representative Dailv Average Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run_ Daily Report of Well Operations OilX- Gas Suspended 17. I hereby 'fy that the regoing is true and correct to the best of my knowledge. Service Title Supervisor Waterflood and Miscible Flood SUBMIT IN DUPLICATE __----=:¡--~J=' m .~--..... BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Steve McMains Subject: Completion Report for Well X-09L 1 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date: June 25,1997 Enclosed, as requested, is a copy of the X-09L 1 Completion Report form 10-407 originally subm itted in August 1995. The original report was subm itted with the well incorrectly named X-09A. The API number on this report is correct. I am submitting a cleaned up Completion Report with the correct well name. I am also subm itting 2 copes of the final well survey because there are none in the original Com pletion Report package. If there are any questions please contact me at 564-5894. Thank you. Sincerely, ~k~~ Theresa Mills Coiled Tubing Technical Assistant 3 RE(EiVED (j u L. 0 2 19 9 -, Mas.ka Oil & Gas GoO.5. LommisSllr Anchorage STATE OF ALASKA J ALASKÞ L AND GAS CONSERVATION ,V1MISSION .......L COMPLETION OR RECOMP LETION REPORT AND LOG . , . .::itatus of Well Classification of Service Well OIL ŒJ GAS 0 SUSPENDEC 0 ABANDONED 0 SERVICE 0 2. Name of Operator 7. Permit Number BP Exnloration 95-47 3. Address 8. API Number P. 0, Box 196612 Anchoraae Alaska 99519-6612 50- 029-20455-60 4. Location of well at su rface 9. Unit or Lease Name .Jt---r ::'_ r r. 453' SNL, 372' WEL, Sec, 07, T10N, R14E, UPM :. ,~ Prudhoe Bav Unit ?1.' · 10. Well Number At Top Producing Interval .;1 ,J. . " 1212' SNL, 1496' WEL, Sec. 17, T10N, R14E, UPM '.. ~c2Ø~~' riJ X-09L-1 p;ÆÞ¿. 11. Field and Pool At Total Depth -..' Prudhoe Bay Field/Prudhoe Bay Pool 8. 590' SNL, 1148 WEL, Sec 17, T10N, R14E 5. Elevation in feet (ind icate KB, DF, etc.) 16. Lease Designation and Serial No. KBE-72.81 AOL 47475 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if oHsh ore 116. No. of Completions 7/6/95 7/12/95 7/30/95 feet MSL ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ T VD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafro st 12446' MO /8903' SS 12442MO' 8903 ss YES ŒJ NO 0 2139 feet MD aDDrox 1900' 22. Type Electric or Othe r Logs Run Gamma Rav 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MC CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECOR[ AMOUNT PULLED 20 x 30 Insulated Conductor SURF 143 36 8.5 cu. vd. concrete 13 3/8 72 L-80 SURF 2671 17 1/2 3720 cu. ft 95/8 47 Sco-95 SURF I 11871 12 1/4 1689 cu. ft. Class G; 130 cu. ft. Permafrost I 7 29 L-80 11376 13528 81/2 454 cu. ft. Class G í 27/8 6.5 L-80 11338 12442 3 3/4 None I 24. Perforations open to Production (MD+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number ) SIZE DEPTH SET (MD) PACKER SET (MD) I 11995'-12027' MO (32ft) 8772'-8790'ss 4 1/2 11403 11327' 12405'-12425'MO(20ft) 8896'-8900'ss 26. ACID, FRACTURE, CEMENT SQJEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED I 27. PRODUCTION TEST Date First Production Method of Operation (Flow ing, gas lift, etc.) 7/28/95 Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD . Flow Tubing Casing Pressure CALCULATED . OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) I I Press. 24-HOUR RATE 28. CORE DATA Brief description of lith ology, porosity, fracture s, apparent dips, and pre sence of oil, gas or wate r. Submit core chips. RECEiVP) >; t~ JUL o ::-~ 1997 ~aska Oil & G' . --. . . as (.;ons. L,ujms~.¡\. ~chorage l Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKER~ ~='- rORMA TION TESTS NAME II I II MEAS. DEPTr 12021 12319 Include inteNal tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTr GOR, and time of each pha se. 8787ss 8879 ss Shublik Sadleroçhit II II I 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and co rrect to the best of my k nowledge Signed ~ ~ ~ Vf1\1l0 Title (;nil Tllhinq c..._/!:...~~ TA Date (p /;):5 jq7 I ' INSTRUCTIONS General: This form is des all types of lands and Ie igned for submitting a co ases in Alaska. mplete and correct well c ompletion report and log on Item 1: Classification of water disposal, water sup Service Wells: Gas injec ply for injection, observ tion, water injection, st ation, injection for in-s eam injection, air inject itu combustion. ion, salt Item 5: Indicate which el evation is used as refere nce (where not otherwise shown) for depth measurem ents given in other spaces on this form and in any atta chments. Item 16 and 24 : If this well is completed for sep arate production from mor e than one interval (mult iple completion), so state in item 16, and in item 24 s how the producing interva Is for only the interval reported in item 27. Submit a sep arate form for each addit ¡onal interval to be sepa rately produced, showing the data pertinent to such in terva!. Item 21: Indicate whether from ground level (GL) 0 r other elevation (OF, KB , etc.). Item 23: Attached supplem ental records for this we II should show the detail ing and the location of t he cementing tool. s of any multiple stage c ement- SUbmerSible~{J:; ¡ V E D Item 27: Method of Operat ion: Flowing, Gas Lift, R od Pump, Hydraulic Pump, jection, Gas Injection, S hut-in, Other-explain. Item 28: If no cores take n, indicate "none". I· " LJ l) I 0 I) ~·é~ 1997 li1aska.ou & G' . as Lons. Cvmm~S~líì Imc/lOr¿1ge Form 1 0-407 , . STATE OF ALASKA ALA~KA OIL AND GAS CONSERVATION COMMISSION #ELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL rn GAS 0 SUSPENJBJ 0 ABANDONED 0 SERVICE 0 2. Name of Operator - _.. ~- 7. Permit Number ., ,.-.-~ - -' .......-.. BP Exploration i¡ . 95-47 .... 3. Address - ?~ø/~~ ~..::_~: 8. API Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20455-60 4. Location of well at surface '" ,7 ~I!¿'-~'I_, :t 1\ C 7~.1 9. Unit or Lease Name 4531 SNL, 3721 WEL, SEC. 04, T10N, R14E, UPM .- Prudhoe Bav Unit At Top Producing Interval , "... / ,0) !_ 10. Well Number / .,) ,~~ _.-: \:., , /,:~ ,';j~ s' fJ L.,- J Lfq& LJt.?~ Sa:.. í 71 'II ù fJ, ¡(.i'-f f:;. X-09A(41-17-10-14) v --5G7'-SNL;"1241!WEL,SEC.-'1 O,T10N," R14E;'UPM 11. Field and Pool At Total Depth ~-.-: Prudhoe Bay Field/Prudhoe Bay Pool 5901 SNL, 11481WEL, SEC. 10, r"oN, R14E, UPM 5. Elevation in feet (indicate KB, OF, etc.) 16. Lease Designation and Serial No. KBE=72.81 ADL 47475 12. Date Spudded 13. Date ToO. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, If offshore r 6. NO. of Completions 7/6/95 7/12/95 7/30/95 feet MSL ONE 17. Total Depth (MO+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafros t 12446MD /8903 SS 12442 MD / 8903 SS YESŒJ NJD 2139 feet MD 22. Type Electric or Other Logs Run GAMMA RA Y 23. CASING, LINER AND CEMENTIN3 RECDA) SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOlTOM HOLE SIZE C8v1ENTING RE<X>RD M10UNT PULLED 20 x 30 SURF 143 36 8.5 cu. yd. 13 3/8 72 L-80 SURF 2671 17 1/2 3720 cu. ft - 95/8 47 L-80 SURF 11871 12 1/4 1819 cu. ft. 7 29 L-80 11377 13528 81/2 454 cu. ft. 27/8 6.5 L-80 11338 12442 33/4 None 24. Perforations open to Production (MO+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11995' - 120271 MD (32 ft) 87721 - 8790 SS 41/2 11403 11327 124051 - 124251 MD (20 ft) 88961 - 8900 SS ?6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 7/28/95 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS,MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 24-HOU R RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. R E {~" y= ry ~ ¡;'=' . \, ~'r"'Jr!i!.<f1 .~. 1><_'; ij iL L-' I ¡) (j L. O( 1991 lilaska 0'1 & -', . -',. 1 Gas COilS. I.JI}¡!missi 11 n/~h;-. ...."'" Form 10-407 ~. . .v...,,~~, mil ill du licate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Sub P .....-~. 3D, GEOLOGIC MAR. i-DRMA TION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS.DEPTI-I TRUE VERT. DEPll-I GOR. and time of each phase. Shublik 12021 8787 SS Sadlerochit 12319 8879 SS 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge s¡9nedlJ6?ß j)Jf~ Title Coil Tubing Engineer Date ~ ~13 ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 : If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: I ndicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none", 8) tr~ 1(:' ['" ;: ;> Ii :-~ ~'<>; r% .~. è. Ito< â \ l (0 ~)1. ~ ..~,. .'... M"" f. [1 ~. ~ ~~ Form 10-407 ,JUL 0 (~ì)991 Alaska .oil & Gas Cons. lJummisS1u· Anchorage X-09A Completion TREE: 6" CIW WELLHEAD: MCEVOY ACTUATOR: OTIS 9518" DV PACKER 12578' 1 13-3/8", 72 #/ft, L-80, BTRS 126711/- 4-1/2", 12.6#/ft, L-80, IPC, TUBIN G TUBING ID: 3.958 " CAPACITY: 0.01522 BBU I I KOP: 2800'& 12,006(whipsto MAX ANGLE 80° /12,446' Top of 2 7/8" Uner (uncemented) 11,338 TOP OF 1 ' I 7" LINER 11 r377 9-5/8", 47#/fl L-80, BTRS 111 r871 I 1- PERFORATION SUMMARY REF LOG: SWS - BHCS 06-29-80 Whipstock @ 12,006' '\ SIZE SPF INTERVAL OPEN/SQZ'[ 3-3/8" 4 11,995 - 12,027' OPN 1-7-89 1 9/16' 4 12,405 - 12,425' OPN 7-30-95 3-318" 4 12,168 - 12,185' squeezed 3-3/8" 4 12,189 - 12,213' squeezed 3-3/8' 4 12,230 - 12,262' squeezed 2-7/8' 4 12,268 - 12,287' squeezed 112,131 I 1122211 I ~ """" " " " " Top Cmt Plu " " " " " " " " " " " .- " " " " TOP SAND BACK 112,400'1 POSTURCOTD_ PBTD I 12,4f1S1 , 7" , 29 #/11, L-80, BTRS 113r5281 I - KB. ELEV = 72.81 ' BF. ELEV = 40.38' SSSV LANDING NIPPLE I 21391 I (OTIS){ 3.813 "ID) GAS LIFT MANDRELS 5 4 3 2 1 9° 54° 50° 48° 50° SLIDING SLEEVE OTIS "XA' (3.813' ID) TUBING SEAL ASSY. 20' BAKER SBR 9-5/8' PACKER - (BAKER SAB){3.813·'D) 111 r23S' I 111 r3081 I 111 r327' I 4-1/2', 12.6 #Ift, L-80 TAILPIPE 4-112' "X' NIPPLE I I I (OTIS) (3.813 "ID) 11 r371 4-1/2" "XN" NIPPLE I 1 I (OTIS) (3.725" ID) 11 A01 4-112' TBG TAIL = (3.958'ID) (ELMO) I Daily Operations Well: Field: API: Permit: X-09A Prudhoe Bay 50-029-20455-60 95-47 Accept: Spud: Release: CTD Unit: 06/13/95 06/25/95 07/12195 Camco #4932 Date ~ º-ªØb. Footage Drilled 04/11/95 RIH WITH 30 FEELER KINLEY CALIPER TO 12,180' WLM. SOOH @ 60' PER MIN TO EOT @ 11400', POOH. GOOD SURVEY. RD, LWSI. 05/03/95 TIH WITH BHA # 1 TO DRIFT TUBING TO XN HIPPLE. 05/04/95 LIQUID PAK WELL W/300 BBL SW. LAY IN 12 BBLS CEMENT FROM 12,395' CORRECTED CTMD TO 12,072'. UNABLE TO ESTABLISH REVERSE CIRCULATION DUE TO OPEN SAG PERFS. POOH. LEAVE WELL SI DUE TO NO FLOWLINE. 05/07/95 TIH WITH BHA # 1. TAG HARD TO AT 12224' CTMO. CORRECT TO 12210' CWLD. LAY IN 10 BBL EW,6 BBLS CMT, 5 BBLS EW FOLLOWED BY 29 BBL DIESEL. SD. PU TO WCTOC AT 12048'. PUMP 1/2 BPM UNTIL DIESEL IS AT THE NZL. LEAVE WELL SI (AS THERE IS NO FLOWLINE). 05/09/95 RIH WITH 3.625 TS/TEL TO TO. TT AT 11390' WLM, TD AT 12118' WLM. CORRECTED TD AT 12131' WLM. OOH, TEL WAS NOT WITH US ANYMORE! RIH WITH BELL GUIDE, TRY TO FISH TEL OFF BOTTOM. OOH DID NOT HAVE TEL. RD 05/17/95 SET WHIPSTOCK VIA E-LlNE. TOP OF WHIPSTOCK SET AT 12,006' MD. WHIPSTOCK IS ORIENTED 10 DEGREES "LEFT" OF HIGH SIDE. 05/20/95 RU CAMCO #4906. MILL THRU XN NIPPLE. BEGIN WINDOW MILLING. 05/21/95 CONTINUE WINDOW MILLING. 05/22/95 CONTINUE WINDOW MILLING. 05/23/95 12033 - FINISHED MILLING WINDOW. DRILLED 10 FT OF SAG FORMATION. FRZ PROTECTED WELL. 06/13/95 1 12035 0 LOAD AND MOVE CT DRILLING UNIT TO LOCATION. RIG UP SUBSTRUCTURE AND POSITION CT FLOAT 1 CAB 06/14/95 2 12035 0 RIG UP CT DRILLING TOWER, INJ HEAD, LINES, CHOKE MANIFOLD AND PUMP. PRESS TEST BOPS I LINES. 06/15/95 3 12035 0 RIG UP 33/81 CT DRILLING BHA, MIU RADIUS 06/16/95 4 12035 0 TROUBLE SHOOT ELECTRICAL PROBLEMS. 06/17/95 5 12035 0 TEST UMBILICAL CABLE FOR ELECTRICAL SHORTS AND CHECK INJ HEAD. 06/18/95 6 12035 0 SET INJ HEAD ON GROUND WITH CRANE, TEST HEAD AND PRESS TEST CT. 06/19/95 7 12035 0 CHECK AND REPAIR HEAD, PRESS TEST CT TO CHECK FOR UMBILICAL SHORTS. 06/20/95 8 REPAIR HEAD 12035 0 06/21/95 9 12035 0 CONT. TO REPAIR INJ HEAD, RUN CHAINS, CHECK CLEARANCES. 06/22/95 10 12035 0 CONT. TO REPAIR INJ HEAD, RUN CHAINS, CHECK CLEARANCES, STAB PIPE, INJ MOTOR SEAL BLEW. 06/23/95 11 12035 0 REPAIR INJ HEAD MOTOR. RUN DUMMY STRING. OK. SWAP OUT TO DRILLING SPOOL. 06/24/95 12 12035 0 PU INJ HEAD. MU BHA. 06/25/95 13 12091 56 MU DRILEX BHA. DRILL FROM 12035' - 12091' (DOWN WEIGHT, TD APPROX 12087' UP). UNABLE TO BUILD ANGLE AWAY FROM WASHED OUT ORIGINAL WELL. STUCK BRIEFLY AT 12082' WASHING BACK TO BonOM. SUSPECT CEMENT CHUNKS. STEERING TOOL SHORTED OUT. POOH. 06/26/95 14 12091 0 POOH. TROUBLE SHOOT BHA. ISOLATED PROBLEM TO RADIUS FEED THRU WIRE CONNECTION. RD TOWER SECTIONS. BHA AND UPPER CONNECTOR OK. RU 4932 TO LAY CEMENT PLUG. RIH. 06/27/95 15 12024 -67 TAG TOP OF WHIPSTOCK AND CORRECT TO 12006' (-26'). HANGING UP. CIRC AT HIGH RATE TO WORK BY. TAGGED @ 12033', LEDGE. CIRC TO GET BY. TAGGED @ 12073', LOST 14' OF HOLE DUE TO CAVING CEMENT. CLEANED HOLE WITH 20 BBLS BIOZAN. FLUID PACKED IA. COOLED BELOW WHIPSTOCK WI APPROX 200 BBlS. lAYED IN 7 BBlS CEMENT. CEMENT IN PLACE AT 11 :00. UNABLE TO BUilD SQUEEZE PRESSURE ABOVE 500 PSI. HOLDING SOLID AT 150 PSI. W/ APPROX 2 BBlS CEMENT BEHIND PIPE DECIDED TO CONTAMINATE DOWN TO THE WINDOW. WANTED TO CONTAMINATE TO 1/2 WAY THROUGH WINDOW. TAGGED UP HARD AT 11987'. CEMENT WENT OFF 1 HOUR EARLY. RIGGED OWN SERVICE UNIT/RIGGED UP TOWER. PICKED UP BHA, MONEL, 2-718 MTR, 3.75 MILL. PT. ,..--~~ 06/28/95 16 12024 0 RAN IN W/ 2-7/8 MTR AND 3.77- MILL. GOT TO BTM. MOTOR FAILED IMMEDIATELY AND WERE UNABLE TO DRILL. GR TOOL ALSO COUILD NOT BE SWITCHED OVER FROM DIRECTIONAL MODE. PULLED OUT AND CHANGED MTR AND GRlDIR COLLAR. RAN IN CHECKING GR EVERY 30 MIN. (DISCOVERED STATOR FAILED IN FIRST MOTOR). LOGGED GR SURVEY AND CORRECTED MILL DEPTH. TAGGED TOP OF WHIPSTOCK @ 12006. TRIED GETTING PAST TOP OF WHIPSTOCK WITHOUT SUCCESS. KEPT STALLING AND WOULD NOT JUMP OVER. RADIUS SHORTED OUT WHILE ON BTM ALSO. PULLED OUT. FLUSHED COIL WI CLEAN (NON SLICK) SEA WTR FOLLOWED BY FRESH WATER. BLOWN COIL DRY WITH N21N PREPARATION FOR REMOVING UMBILICAL. 06/29/95 17 12024 0 LAY DOWN TOWER SECTIONS. UNSTAB PIPE. SUSPEND OPERATIONS TO CHANGE OUT DAMAGED COIL. 07/01/95 19 12024 0 LAY OUT DAMAGED COIL ON ROAD. REMOVE UMBILICAL. LAY OUT NEW COIL ONTO ROAD. CUT OFF 1600 FT 07/02/95 20 12024 0 BLOW WL INTO NEW COIL. PULL IN UMBILCAL AND ROLL UP COIL ONTO 985. TAKE TRAILER TO SHOP AND RE-RIG UP 07/03/95 21 12024 0 BLOW WL INTO NEW COIL. PULL IN UMBILCAL AND ROLL UP COIL ONTO 985. TAKE TRAILER TO SHOP AND RE-RIG UP Y CONNECTOR. RODE TO X-09 AND RE-RIG UP. FILL COIL AND OHM OUT WIRES. TOO MANY GOOD WIRES (10). RIG UP TOWER AND STAB PIPE. 07/04/95 22 12024 0 FINISH STABBING PIPE. INSPECT HEAD. FOUND 1 BUSHING BOLT MISSING AND 1 CRACKED. REPLACE SAME. NO BROKEN GRIPPER BOLTS DETECTED. RUN PIPE DWN TO WELDING TRAILER- NO SCARS. WELD ON NUBBIN AND X-RAY SAME. WIRE UPPER CONNECTOR AND CHECK WIRES. 07/05/95 23 12024 0 FINISH STABBING PIPE. INSPECT HEAD. FOUND 1 BUSHING BOLT MISSING AND 1 CRACKED. REPLACE SAME. NO BROKEN GRIPPER BOLTS DETECTED. RUN PIPE DWN TO WELDING TRAILER- NO SCARS. WELD ON NUBBIN AND X-RAY SAME. WIRE UPPER CONNECTOR AND CHECK WIRES. 07/06/95 24 12024 26 CONTINUE PRESSURE TESTING. MU BHA#1. TIH, TESTING TOOLS. TIE INTO GR (TOTAL DEPTH CORRECTION IS =+18'.) DRILL FROM 12024 - 12050 (12054 CORRECTED TD). ANGLE BUILT TO 59°. POOH AND CHANGE TO 2° MOTOR. RIH. 07/07/95 25 12171 147 CONTINUE RIH WI 2° MOTOR. TIED IN TO GR. OPENED CIRC SUB AND DISPLACED OVER TO FLQ-PRO. LOSING APPROX 15% RETURNS. APPROX 50 - 100 BBLS LOST TO FORMATION. SPOTTED LCM PILL. "SQUEEZED" TO A COUPLE HUNDRED PSI. RETURNS ALMOST 1:1. DRILL AHEAD TO 121711. EXPERIENCING DEPTH PROBLEMS WITH ENCODER. CHAINS SLIPPING? 100% LOST RETURNS AT BOTTOM. 07/08/95 26 12175 4 PUMPED 1000# LCM PILL. STILL LOSING 90% RETURNS. PUMPED 2000# LCM PILL. APPEARED TO DO SOME GOOD. DRILLED 21 AND PULLED UP HOLE. DETERMINED THAT INCREASED RETURNS WERE DUE TO A GAS KICK. UNABLE TO EFFECTIVELY HANDLE GAS AT SURFACE AND NOT ALLOWED TO PUT ANY POSSIBLE SOLIDS DOWN THE FLOWLINE. BULLHEAD KILLED. POOH TO EVALUATE FOR UNDER BALANCED DRILLING. 07/09/95 27 12179 4 LAY DOWN AND INSPECT TOOLS. LOST 1 BERRYLlUM COPPER SCREW IN THE WELL. SIWHP=500. BLEED TO OPEN TOP TANK, 0 WHP, 175 BBLS FLOWED BACK. NO FLOW. MU BHA. TAGGED AT 121791. ATTEMPT TO DRILL. WELL UNLOADING SOLIDS AND RETURNS GETTING GASSY. MOTOR WOULDN'T TURN IN OPEN HOLE. SLIGHT OVER PULL. PULL INTO LINER AND CIRC GAS OUT. 1: 1 RETURNS. WASH OPEN HOLE AND LINER WITH FLOPRO SWEEPS. THE OPEN HOLE IS CLEAN. NO OVERPULL. THE WELL IS ACTING LIKE AN ACCUMULATOR, BUT STILL GETTING RETURNS. UNABLE TO GET THE MOTOR TO TURN. POOH. 07/10/95 28 12248 69 DRILL WITH SEAWATER AND BIIOZAN SWEEPS. 07/11/95 29 12400 152 REPAIRED BROKEN BOLT ON INJECTOR HEAD. RIH. DISPLACED WELL TO FLo-PRO. DRILLING AT 124001. 07/12/95 30 12446 46 DRILLED TO TD AT 124461. POH TO RIG DOWN DRILLING UNIT. 07/21/95 12446 RU CTU FOR RUNNING LINER. 07/22/95 12442 PBTD TESTED BOPE. PU 2 7/8" LINER AND RIH. LANDED LINER WITH SHOE AT 12,442 AND TOP AT 11,338'. CIRCULATED HOLE AND SPOTTED LiOH BEHIND THE LINER. DISPLACED TO SEAWATER. (NOTE: LINER IS UNCEMENTED) 07/28/95 12442 PBTD RUTRICO UNIT FOR WELL CLEAN-UP. SLOWLY DROVE CHOKE OPEN AND WELL STARTED UNLOADING GIVING UP FRAC PROPPANT (MINOR AMOUNTS), TRACES OF FORMATION SAND AND FLo-PRO GELL. WELL IS SURGING WITH GAS LIFT AND THE VESSEL LIQUID LEG IS SHUT IN MOST OF THE TIME BUILDING LEVEL. SHOT CSG LIQUID LEVEL AT 5447FT. 07/29/95 12442 PBTD WELL FLOWING AT 936 BPD WITH 79% WATER CUT. SURGING AND UNSTABLE. 07/30/95 12442 PBTD WELL IS SURGING AND UNSTABLE AT 1488 BPD WITH 81% WATER CUT. FL SHOT AT 7415 FT. RU CTU. PERFORATE FROM 12405 - 12425 WITH 1 9/16" GUN, 4 SPF. 'to I } 1.-/ c-¡ G ,Ä, () (i C C: I (I di V -j d u .;:~ 1 \,1/ ell Ci e () 1 0';] -1 C a 1 ¡"I d t e r· -1 Ei]:::5 I n ve n t () r' V f'.j ';j, i f),';,te; Ub/O~)/97 PEP¡"'lIT D/\TA T D þ, T Þ,_P L U :3 f~ UN f) /I, T [: P r:: c: V D -...... ......- ........ ~~,- "-.v ~-.-~ '.~-~ ~-...- y.... ....-~ -.-.~ ".'~ ~W' .. ~~ ".-.-.- ''''." .....,. ".'" ""~ ......... .........'" -.-.,' ....... ....-.- "u ".-'- ....... ........ ..,.... ......... '..... ..... .....-, '.",. ....-.'" ....-.. ......... ........ ".". -....... ........ ........ V<"." .....- ~.... ,-.,' ......... ~..- ...-~. ~ 95-,Oh7 L^ E A 1< D E T E C T I () N G 1- 1/'" 'Nv 1.- ~O-11300 l---- 1 I fJ qr - I ~ '-f J j- I U "7 /' 2 'j / 9 5 'íO--h07 ~ C()1'1PL.ETICJN Df;.\ì·E 7/30 /qJ- / 7/);{ /17/ D !\ I L Y \hJ E l_ L. 0 P S '-R <-( / J I / q j / TO? / J r1J / q J--) J):r_ Š<Avv<.fJ It. D 1\1~íZ / J... ó IF ~ )), '-'lv/i.J 7/ u )/ q ? / A r" (:: d (" y d·j t c h :;; E! ïfl P 1 e s r' e q u -í (, e d ? \le:3 .~ /\nc1 ('(~ceí ved~'" 'i~· I~ \&/ EJ S the '0/'1 e 1 -1 COt", e d '? yes @ _ /\ n 031 V:3'j S &: d e :3 c r" -j p t -j 0 (I (' e c e .j v ;::~ d ? V~·:~:; 1'1 ....; A r' ewe 1 1t:: e :3 t ::; r' e qui r' e d ? y e :3 rÐ R e c e -, v i~~ d ? ~(:: ¡'I'"" \,1/ e 1 '1 '1 si n COin p'l -j E¡ nee ...___._______^ I n -j t -j a 1 COMMENTS êš 16 ).'/\ I CJkÀ 'r ,\ "'1 <J f1, I! J r 1\ t? A \.. G q - ~J" 4 1 o);., if- 7) I VI I i oJ v -1)/" ··..1 () 11 ...'.....<'.,. 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'..; , , .... .u_..._............u~n_·;'---.......,"......-"..n""""_',.,~........._""'~~"'·u...........,.,..,.............,.......~,~.___~............,._.,...,,_,_.....-<"....~,;~-.........."""',....,,~_;_.;___-..___................,.U..NU~_____.....'............n~~....._____;,_;"....~.....__~u_.nU..U__.n.'.--..n.."'r."_'_~____u.<.".~.__"_n n....._.......".,__·'n....·_"""..n-l".nn...._"......-.-un..'___...............,....,.........,.....,..................__.....-.N'-'Y"--'-"".....................,"·n_......,~.._,_.........~"'~"".._~..,.,..,.,.,"""'.....'._^'"n"....J.~n..u_'u·.,..,....,.._...-...,.,......_""^'u......"~u-...,.._..,....._.....".............___.n.......,un....u.._~____"'__.....'_~.__......"....u__uUU~n._nn_~_..__..,.__.__~___.."_________. _.~n_._......_ STATE OF ALASKA ALASKA ùlL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well Oil ŒI GAS 0 SUSÆN)8) 0 ABANOONED 0 SERVICE 0 2. Name of Operator 7. Permit Number BP Exploration 95-47 3. Address 8. API Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20455-60 4. Location of well at surface 9. Unit or Lease Name 453' SNL, 372' WEL, SEC. 07, T70N, R14E, UPM ^, f;~~i;~i¡ Prudhoe Bay Unit At Top Producing Interval ',~þ' 10. Well Number 1272' SNL, 1496' WEL, SEC. 17, T70N, R14E, UPM i~~~:~ X-09A(41-17-10-14) ¿ 11. Field and Pool At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 590' SNL, 7148 WEL, See 17, T10N, R14E 5. Elevation in feet (indicate KB, OF, etc.) 16. Lease Designation and Serial No. KBE=72.81 ADL 47475 12. Date Spudded 13. Date T.o. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore r 6. No. of Completions 7/6/95 7/12/95 7/30/95 feet MSl ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafros t 12446' MD /8903' SS 12442MD; 8903 ss YESŒI N:JD 2139 feet MD approx 1900' 22. Type Electric or Other Logs Run Gamma Ray 23. CASING, LINER AND CEMENTIf\G RECOR) SETTING DEPTH MD CASING SIZE WT. PER FT. GRÞDE TOP BOTTOM HOLE SIZE CEMENTIf\G RECORD AMOUNT PULLED 20 x 30 Insulated Conductor SURF 143 36 8.5 cu.yd. concrete 13 3/8 72 L-80 SURF 2671 17 1/2 3720 cu. ft 95/8 47 Sco-95' SURF 11871 12 1/4 1689 cu. ft. Class G; 130 cu. ft. Permafros 7 29 L-80 11376 13528 81/2 454 cu. ft. Class G 27/8 6.5 L-80 11338 12442 33/4 None 24. Perforations open to Production (MD+ TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 77995'-12027' MD (32ft) 8772'-8790'ss 47/2 11403 77327' 12405'-12425'MD(20ft) 8896'-8900'ss 26. ' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 7/28/95 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CI-K)KESIZE GAS-OIL RATIO rEST PERIOD Flow Tubing Casing Pressure PALCULATED OIL-BBL GAS-MCF WATER-BBL Oil GRAVITY-API (corr) Press. 24-HOU R RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ~~;s., ¡'-'''' \ : C' ~\j ~,,'t'l") ORIGINt\L '\6.._ .11 "" , iJ.o.... ',~ JAN 05 j995 Alaska on 8: (::]~¡ C.Ji1iî. (J(;rnrn¡seitm Ar.C~I(4ragø Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE .---- r-!," 29. 30. GEOLOGIC MARKERS rvMMA TION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEP1H TRUE VERT. DEPTH GOR, and time of each phase. Shublik 12021 8787ss Sadlerochit 12319 8879 SS 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe~~ Title Coil Tubing Engineer Date 1/ ~ / q ~ / INSTRUCTIONS General:- This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 : If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". rt"<{ !(~. ~ . (¡-J ;', ~,.1 ,~'..~ ~.).. ; U ftc~ r:.td/ ~t r, \1' l.,<,;i.40 ~~ . . JAN 05 1996 Form 10-407 AJæ:ìka Oil l:~ Car.; Con:;, Cc'(n!"n¡~~$ion !\nc;fltìf~)00 /--- /=,~ X-09A Completion TREE: 6" CIW WELLHEAO: MCEVOY ACTUATOR: OTIS (I) 95/B" OV PACKER 125781 I 13-3/B", 72 #/ft, L-BO, BTRS 1267111- 4-1/2", 12.6#/ft, L-BO, IPC, TUBING TUBING 10: 3.95B " CAPACITY: 0.01522 BBU KOP: 2BOO'& 12,006(whipsto MAX ANGLE BO° /12,446' Top of 2718" Liner (uncemented) 11,338 TOP OF I 1 1 7" LINER 11,377 9-5/B", 47#/ft, L-BO, BTRS 111,87111- PERFORATION SUMMARY REF LOG: SWS - BHCS 06-29-BO Whipstock @ 12,006 ' " SIZE SPF INTERVAL OPEN/SQZ'[ 3-3/8" 4 11,995 - 12,027' OPN 1-7-B9 1 9/16' 4 12,405 - 12,425' OPN 7-30-95 3-3/8" 4 12, 16B - 12,1 B5' squeezed 3-3/B" 4 12, 1B9 - 12,213' squeezed 3-3/B" 4 12,230 - 12,262' squeezed 2-7/B" 4 12,26B - 12,2B7' squeezed 112.131 I 1122211 I TOP SAND BACK KB. ELEV = 72.B1' BF. ELEV = 40.3B' SSSV LANDING NIPPLE (OTIS )( 3.B13" 10) 213911 GAS LIFT MANDRELS 5 4 3 2 1 90 540 500 4Bo 500 SLIDING SLEEVE OTIS "XA" (3.B13" 10) TUBING SEAL ASSY. 20' SAKER SBR 9-5/B" PACKER (BAKER SAB)(3.B13"10) 111 r23S1 1 111,3081 I h 1 ,3271 I 4-1/2", 12.6 #/ft, L-BO TAILPIPE 4-112" "X" NIPPLE 1 I (OTIS) (3.B13" 10) 11,3711 4-1/2· "XN" NIPPLE 1 I ( OTIS) (3.725· 10) 11,4011 4-112" TBG TAIL = (3.95B"10) (ELMO) 1 <q'III;"~!~~~~¡~i~~rlr¡¡~i~'li~~B~¡~~¡'¡r' ......:;:::;:;:;:::;:::;=;:::;:;::::=:::=;=:=;:;:;:;:;:;:::::::::::::::;:;:::;:::;:;:::::;::::::::=::::::;:::;:;:;:: tllllltllliIIIII11flll~iJII¡iiililililrl'I'rrlllll!l 112.40011 POST URCO TO _ PBTO 11 ~,4SS' I 7",29 #/ft, L-BO, BTRS 113,52811- ·~r· Daily Operations Well: Field: API: Permit: X-09A Prudhoe Bay 50-029-20455-60 95-47 Accept: Spud: Release: CTD Unit: 06/13/95 06/25/95 07/12/95 Camco #4932 Date Day Depth Footage Drilled 04/11/95 RIH WITH 30 FEELER KINLEY CALIPER TO 12,180' WLM. SOOH @ 60' PER MIN TO EOT @ 11400', POOH. GOOD SURVEY. RD, LWSI. 05/03/95 TIH WITH BHA # 1 TO DRIFT TUBING TO XN HIPPLE. 05/04/95 LIQUID PAK WELL W/300 BBL SW. LAY IN 12 BBLS CEMENT FROM 12,395' CORRECTED CTMD TO 12,072'. UNABLE TO ESTABLISH REVERSE CIRCULATION DUE TO OPEN SAG PERFS. POOH. LEAVE WELL SI DUE TO NO FLOWLINE. 05/07/95 TIH WITH BHA# 1. TAG HARD TD AT 12224' CTMD. CORRECT TO 12210' CWLD. LAY IN 10 BBL EW,6 BBLS CMT, 5 BBLS EW FOLLOWED BY 29 BBL DIESEL. SD. PU TO WCTOC AT 12048'. PUMP 1/2 BPM UNTIL DIESEL IS AT THE NZL. LEAVE WELL SI (AS THERE IS NO FLOWLINE). 05/09/95 RIH WITH 3.625 TS/TEL TO TD. TT AT 11390' WLM, TD AT 12118' WLM. CORRECTED TD AT 12131' WLM. OOH, TEL WAS NOT WITH US ANYMORE! RIH WITH BELL GUIDE, TRY TO FISH TEL OFF BOTTOM. OOH DID NOT HAVE TEL. RD 05/17/95 SET WHIPSTOCK VIA E-LlNE. TOP OF WHIPSTOCK SET AT 12,006' MD. WHIPSTOCK IS ORIENTED 10 DEGREES "LEFT" OF HIGH SIDE. OS/20/95 RU CAMCO #4906. MILL THRU XN NIPPLE. BEGIN WINDOW MILLING. OS/21/95 CONTINUE WINDOW MILLING. OS/22/95 CONTINUE WINDOW MILLING. OS/23/95 12033 - FINISHED MILLING WINDOW. DRILLED 10 FT OF SAG FORMATION. FRZ PROTECTED WELL. 06/13/95 1 12035 0 LOAD AND MOVE CT DRILLING UNIT TO LOCATION. RIG UP SUBSTRUCTURE AND POSITION CT FLOAT I CAB f- 06/14/95 2 12035 0 RIG UP CT DRILLING TOWER, INJ HEAD, LINES, CHOKE MANIFOLD AND PUMP. PRESS TEST BOPS I LINES. 06/15/95 3 12035 0 RIG UP 3 3/8" CT DRILLING BHA, MIU RADIUS 06/16/95 4 12035 0 TROUBLE SHOOT ELECTRICAL PROBLEMS. 06/17/95 5 12035 0 TEST UMBILICAL CABLE FOR ELECTRICAL SHORTS AND CHECK INJ HEAD. 06/18/95 6 12035 0 SET INJ HEAD ON GROUND WITH CRANE, TEST HEAD AND PRESS TEST CT. 06/19/95 7 12035 0 CHECK AND REPAIR HEAD, PRESS TEST CT TO CHECK FOR UMBILICAL SHORTS. 06/20/95 8 REPAIR HEAD 12035 o F .. .. L ~ ..1 ¡ ~ ¡ } tr..... .,..... 06/21/95 9 12035 0 CONT. TO REPAIR INJ HEAD, RUN CHAINS, CHECK CLEARANCES. SEP 0 J '1995 06/22/95 10 12035 0 CONT. TO REPAIR INJ HEAD, RUN CHAINS, CHECK CLEARANCES, STAB PIPE, INJ MOTOR SEAL BLEW. A\aska Oil & Gas Cons. Commission Anchorage 06/23/95 11 12035 0 REPAIR INJ HEAD MOTOR. RUN DUMMY STRING. OK. SWAP OUT TO DRILLING SPOOL. 06/24/95 12 12035 0 PU INJ HEAD. MU BHA. 06/25/95 1 3 12091 56 MU DRILEX BHA. DRILL FROM 12035' - 12091' (DOWN WEIGHT, TD APPROX 12087' UP). UNABLE TO BUILD ANGLE AWAY FROM WASHED OUT ORIGINAL WELL. STUCK BRIEFLY AT 12082' WASHING BACK TO BOTTOM. SUSPECT CEMENT CHUNKS. STEERING TOOL SHORTED OUT. POOH. 06/26/95 14 12091 0 POOH. TROUBLE SHOOT BHA. ISOLATED PROBLEM TO RADIUS FEED THRU WIRE CONNECTION. RD TOWER SECTIONS. BHA AND UPPER CONNECTOR OK. RU 4932 TO LAY CEMENT PLUG. RIH. 06/27/95 15 12024 -67 TAG TOP OF WHIPSTOCK AND CORRECT TO 12006' (-26'). HANGING UP. CIRC AT HIGH RATE TO WORK BY. TAGGED @ 12033', LEDGE. CIRC TO GET BY. TAGGED @ 12073'. LOST 14' OF HOLE DUE TO CAVING CEMENT. CLEANED HOLE WITH 20 BBLS BIOZAN. FLUID PACKED IA. COOLED BELOW WHIPSTOCK WI APPROX 200 BBLS. lAYED IN 7 BBLS CEMENT. CEMENT IN PLACE AT 11 :00. UNABLE TO BUILD SQUEEZE PRESSURE ABOVE 500 PSI. HOLDING SOLID AT 150 PSI. W/ APPROX 2 BBlS CEMENT BEHIND PIPE DECIDED TO CONTAMINATE DOWN TO THE WINDOW. WANTED TO CONTAMINATE TO 1/2 WAY THROUGH WINDOW. TAGGED UP HARD AT 11987'. CEMENT WENT OFF 1 HOUR EARLY. RIGGED DWN SERVICE UNIT/RIGGED UP TOWER. PICKED UP BHA, MONEL, 2-7/8 MTR, 3.75 MILL. PT. ~--i-- 06/28/95 1 6 12024 0 RAN IN WI 2-7/8 MTR AND 3.77" MILL. GOT TO BTM. MOTOR FAILED IMMEDIATELY AND WERE UNABLE TO DRILL. GR TOOL ALSO COUILD NOT BE SWITCHED OVER FROM DIRECTIONAL MODE. PULLED OUT AND CHANGED MTR AND GR/DIR COLLAR. RAN IN CHECKING GR EVERY 30 MIN. (DISCOVERED STATOR FAILED IN FIRST MOTOR). LOGGED GR SURVEY AND CORRECTED MILL DEPTH. TAGGED TOP OF WHIPSTOCK @ 12006. TRIED GETTING PAST TOP OF WHIPSTOCK WITHOUT SUCCESS. KEPT STALLING AND WOULD NOT JUMP OVER. RADIUS SHORTED OUT WHILE ON BTM ALSO. PULLED OUT. FLUSHED COIL WI CLEAN (NON SLICK) SEA WTR FOLLOWED BY FRESH WATER. BLOWN COIL DRY WITH N21N PREPARATION FOR REMOVING UMBILICAL. 06/29/95 17 12024 0 LAY DOWN TOWER SECTIONS. UNSTAB PIPE. SUSPEND OPERATIONS TO CHANGE OUT DAMAGED COIL. 07/01/95 19 12024 0 LAY OUT DAMAGED COIL ON ROAD. REMOVE UMBILICAL. LAY OUT NEW COIL ONTO ROAD. CUT OFF 1600 FT 07/02/95 20 12024 0 BLOWWL INTO NEW COIL. PULL IN UMBILCAL AND ROLL UP COIL ONTO 985. TAKE TRAILER TO SHOP AND RE-RIG UP 07/03/95 21 12024 0 BLOW WL INTO NEW COIL. PULL IN UMBILCAL AND ROLL UP COIL ONTO 985. TAKE TRAILER TO SHOP AND RE-RIG UP Y CONNECTOR. RODE TO X-09 AND RE-RIG UP. FILL COIL AND OHM OUT WIRES. TOO MANY GOOD WIRES (10). RIG UP TOWER AND STAB PIPE. 07/04/95 22 12024 0 FINISH STABBING PIPE. INSPECT HEAD. FOUND 1 BUSHING BOLT MISSING AND 1 CRACKED. REPLACE SAME. NO BROKEN GRIPPER BOLTS DETECTED. RUN PIPE DWN TO WELDING TRAILER- NO SCARS. WELD ON NUBBIN AND X-RAY SAME. WIRE UPPER CONNECTOR AND CHECK WIRES. 07/05/95 23 12024 0 FINISH STABBING PIPE. INSPECT HEAD. FOUND 1 BUSHING BOLT MISSING AND 1 CRACKED. REPLACE SAME. NO BROKEN GRIPPER BOLTS DETECTED. RUN PIPE DWN TO WELDING TRAILER- NO SCARS. WELD ON NUBBIN AND X-RAY SAME. WIRE UPPER CONNECTOR AND CHECK WIRES. 07/06/95 24 12024 26 CONTINUE PRESSURE TESTING. MU BHA #1. TIH, TESTING TOOLS. TIE INTO GR (TOTAL DEPTH CORRECTION IS =+18'.) DRILL FROM 12024 - 12050 (12054 CORRECTED TD). ANGLE BUILT TO 59°. POOH AND CHANGE TO 20 MOTOR. RIH. 07/07/95 25 12171 147 CONTINUE RIH WI 20 MOTOR. TIED IN TO GR. OPENED CIRC SUB AND DISPLACED OVER TO FLO-PRO. LOSING APPROX 15% RETURNS. APPROX 50 - 100 BBLS LOST TO FORMATION. SPOTTED LCM PILL. "SQUEEZED" TO A COUPLE HUNDRED PSI. RETURNS ALMOST 1:1. DRILL AHEAD TO 12171', EXPERIENCING DEPTH PROBLEMS WITH ENCODER. CHAINS SLIPPING? 100% LOST RETURNS AT BOTTOM. 07/08/95 26 12175 4 PUMPED 1000# LCM PILL. STILL LOSING 90% RETURNS. PUMPED 2000# LCM PILL. APPEARED TO DO SOME GOOD. DRILLED 21 AND PULLED UP HOLE. DETERMINED THAT INCREASED RETURNS WERE DUE TO A GAS KICK. UNABLE TO EFFECTIVELY HANDLE GAS AT SURFACE AND NOT ALLOWED TO PUT ANY ,~, " .. ' .... "~ '. POSSIBLE SOLIDS DOWN THE FLOWLINE. BULLHEAD KILLED. POOH TO EVALUATE FOR UNDER BALANCED DRILLING. 07/09/95 27 12179 4 LAY DOWN AN D INSPECT TOOLS. LOST 1 BERRYLlUM COPPER SCREW IN THE WELL. SIWHP=500. BLEED TO OPEN TOP TANK, 0 WHP, 175 BBLS FLOWED BACK. NO FLOW. MU BHA. TAGGED AT 12179'. ATTEMPT TO DRILL. WELL UNLOADING SOLIDS AND RETURNS GETTING GASSY. MOTOR WOULDN'T TURN IN OPEN HOLE. SLIGHT OVER PULL. PULL INTO LINER AND CIRC GAS OUT. 1:1 RETURNS. WASH OPEN HOLE AND LINER WITH FLOPRO SWEEPS. THE OPEN HOLE IS CLEAN. NO OVERPULL. THE WELL IS ACTING LIKE AN ACCUMULATOR, BUT STILL GETTING RETURNS. UNABLE TO GET THE MOTOR TO TURN. POOH. 07/10/95 28 12248 69 DRILL WITH SEAWATER AND BIIOZAN SWEEPS. 07/11/95 29 12400 152 REPAIRED BROKEN BOLT ON INJECTOR HEAD. RIH. DISPLACED WELL TO FLQ-PRO. DRILLING AT 12400'. 07/12/95 30 12446 46 DRILLED TO TD AT 12446'. POH TO RIG DOWN DRILLING UNIT. 07/21/95 12446 RU CTU FOR RUNNING LINER. 07/22/95 12442 PBTD TESTED BOPE. PU 2 7/8" LINER AND RIH. LANDED LINER WITH SHOE AT 12,442 AND TOP AT 11,338'. CIRCULATED HOLE AND SPOTTED LiOH BEHIND THE LINER. DISPLACED TO SEAWATER. (NOTE: LINER IS UNCEMENTED) 07/28/95 12442 PBTD RU TRICO UNIT FOR WELL CLEAN-UP. SLOWLY DROVE CHOKE OPEN AND WELL STARTED UNLOADING GIVING UP FRAC PROPPANT (MINOR AMOUNTS), TRACES OF FORMATION SAND AND FLQ-PRO GELL. WELL IS SURGING WITH GAS LIFT AND THE VESSEL LIQUID LEG IS SHUT IN MOST OF THE TIME BUILDING LEVEL. SHOT CSG LIQUID LEVEL AT 5447FT. 07/29/95 12442 PBTD WELL FLOWING AT 936 BPD WITH 79% WATER CUT. SURGING AND UNSTABLE. 07/30/95 12442 PBTD WELL IS SURGING AND UNSTABLE AT 1488 BPD WITH 81% WATER CUT. FL SHOT AT 7415 FT. RU CTU. PERFORATE FROM 12405 - 12425 WITH 1 9/16" GUN, 4 SPF. DRILEX/RADIUS HORIZONTAL CASPER,WYO./HOUSTON,TEXAS BRITISH PETROLEUM Well Name Location ': X-RAY X-Q9,1 SIDETRACK PRUDHOE BAY,AK Date DIRECTIONAL DRILLER SURVEY PERSONAL 7/11/1995 LARREN HOLDREN BILL BLAND , MIKE MURPHY " his survey is correct to the best of my knowledge nd is supported by actual field ~~ ~.~ ... V~NY /.... )' () j .- \'0.- j -, / ¡ .'/.' ." ,\ f '.. :j' 'Jijll§k 4 7 REPRESENTATIVE Customer Well Name Location DRILEX/RADIUS HORIZONTAL BRITISH PETROLEUM X-RAY X-09A SIDETRACK PRUDHOE BAY,AK Date 7/11/1995 Filename : X-09A No Interpolation Height of Area Datum above Customer Datum 0.00 ft Height of Well Datum above Area Datum 0.00 ft All TVDs are relative to the Well Datum Level Plane of vertical section Latitude & Departure relate to vertical section Originates at Slot Coordinates Directions Referenced To Depth at Drill Floor Calculation Method Target Details No. 1 2 TVD 8880.00 8895.00 Lat -5367.00 -5545.00 Points of Interest No data Magnetic Declination :+28.39° AREA North +0° 0' 0" (T) Grid convergence +0.0000° 126.7° AREA CENTRE SLOT CENTRE Lat O.OOOft Dep O.OOOft GRID NORTH 0.00 ft MINIMUM CURVATURE Dep 4475.70 4745.00 DRILEX/RADIUS HORIZONTAL Customer BRITISH PETROLEUM Page 1 of 1 Well Name X-RAY X-09A SIDETRACK Date 7/11/1995 Location PRUDHOE BAY , AI< Filename : X-09A No Interpolation Height of Area Datum above Customer Datum 0.00 ft Height of Well Datum above Area Datum 0.00 ft All TVDs are relative to the Well Datum Level M.DEPTH ANGLE DIR C\L TVD VIS N+/S- E+/W- D'LEG ft deg deg ft ft ft ft ft °/100 12025.00 53.65 S17.15°E 0.00 8789.52 6465.92 -5112.21 4253.98 0.00 12033.00 58.00 S17.000E 8.00 8794.01 6471.26 -5118.54 4255.92 54.40 12058.00 63.80 S17.000E 25.00 8806.17 6488.86 -5139.42 4262.31 23.20 12083.00 68.00 S17.400E 25.00 8816.37 6507.29 -5161.21 4269.06 16.86 12109.00 71.00 S24.500E 26.00 8825.49 6527.86 -5183.93 4277.77 28.05 12139.00 72.50 S30.300E 30.00 8834.89 6553.48 -5209.21 4290.88 19.03 12183.00 74.20 S40.500E 44.00 8847.53 6593.53 -5243.50 4315.27 22.54 12200.00 73.90 S41.20oE 17.00 8852.20 6609.49 -5255.87 4325.96 4.33 12235.00 76.50 S45.700E 35.00 8861.14 6642.82 -5280.42 4349.23 14.48 12260.00 76.90 S48.700E 25.00 8866.90 6667.01 -5296.95 4367.08 11.79 12285.00 77.40 S49.60oE 25.00 8872.46 6691.32 -5312.89 4385.52 4.04 12312.00 78.10 S49.80oE 27.00 8878.18 6717.65 -5329.96 4405.64 2.69 12327.00 78.50 S49.10oE 15.00 8881.23 6732.31 -5339.50 4416.80 5.29 12353.00 79.00 S49.000E 26.00 8886.30 6757.74 -5356.22 4436.06 1.96 12433.00 79.80 S47.40oE 80.00 8901.02 6836.06 -5408.63 4494.68 2.21 12446.00 79.93 S47.14°E 13.00 8903.30 6848.78 -5417.31 4504.08 2.21 Origin of Bottom Hole Closure AREA CENTRE Bottom Hole Closure 7045 ft 140.3° PROJECT TO BIT 12446 OF 13 FEET IS PROJECTED SURVEY BPX Dlrectional Survey Report Company: BPX Well: X-09A Location: North Slope Alaska Field: PBU Operator: Bland/Murphy Job No: 5AG060 VS Azimuth VS Origin North VS Origin East 126.7 0.0 0.0 Method: Minimum Curvature ------- Survey File 5060 11 July 1995 Probe 0 Depth Units: Feet Dec: 28.4 BPX Dlrectional Survey Report Company: BPX Well: X- 09A Survey File 5060 Location: North Slope Alaska 11 July 1995 Field: PBU Probe 0 Operator: Bland/Murphy Depth Units: Feet Job No: 5AG060 Dec: 28.4 VS Azimuth 126.7 VS Origin North 0.0 Method: Minimum Curvature VS Origin East 0.0 St MD Inc Az North East TVD VS DL 0 12025 53.7 163.0 -5112.2 4254.0 8789.0 6465.9 0.0 1 12033 58.0 163.0 -5118.5 4255.9 8793.5 6471.3 53.8 2 12058 63.8 163.0 -5139.4 4262.3 8805.6 6488.9 23.2 3 12083 68.0 162.6 -5161.2 4269.1 8815.8 6507.3 16.9 4 12109 71.0 155.5 -5183.9 4277.8 8825.0 6527.9 28.1 5 12139 72.5 149.7 -5209.2 4290.9 8834.4 6553.5 19.0 6 12158 73.7 146.1 -5224.6 4300.6 8839.9 6570.4 19.2 7 12183 74.2 139.5 -5243.7 4315.1 8846.8 6593.5 25.4 8 12200 73.9 138.8 -5256.1 4325.8 8851.5 6609.5 4.3 9 12235 76.5 134.3 -5280.6 4349.0 8860.4 6642.8 14.5 10 12260 76.9 131.3 -5297.2 4366.9 8866.2 6667.0 11.8 11 12285 77.4 130.4 -5313.1 4385.3 8871.7 6691.3 4.0 12 12312 78.1 130.2 -5330.2 4405.4 8877.5 6717.6 2.7 13 12327 78.5 130.9 -5339.7 4416.6 8880.5 6732.3 5.1 14 12353 79.0 131.0 -5356.4 4435.9 8885.6 6757.7 2.0 15 12401 79.3 132.0 -5387.7 4471.2 8894.6 6804.7 2.1 16 12433 79.8 132.6 -5408.8 4494.5 8900.4 6836.0 2.4 17 12446 79.8 132.6 -5417.5 4503.9 8902.7 6848.7 0.0 MD Ine Az North East TVD VB DL J 12025 53.7 163.0 -5112.2 4254.0 8789.0 6465.9 0.0 1 12033 58.0 163.0 -5118.5 4255.9 8793.5 6471.3 53.8 2 12058 63.8 163.0 -5139.4 4262.3 8805.6 6488.9 23.2 3 12083 68.0 162.6 -5161.2 4269.1 8815.8 6507.3 16.9 4 12109 71.0 155.5 -5183.9 4277.8 8825.0 6527.9 28.1 5 12139 72.5 149.7 -5209.2 4290.9 8834.4 6553.5 19.0 6 12158 73.7 146.1 -5224.6 4300.6 8839.9 6570.4 19.2 7 12183 74.2 139.5 -5243.7 4315.1 8846.8 6593.5 25.4 8 12200 73.9 138.8 -5256.1 4325.8 8851.5 6609.5 4.3 9 12235 76.5 134.3 -5280.6 4349.0 8860.4 6642.8 14.5 10 12260 76.9 131.3 -5297.2 4366.9 8866.2 6667.0 11.8 11 12285 77.4 130.4 -5313.1 4385.3 8871.7 6691.3 4.0 12 12312 78.1 130.2 -5330.2 4405.4 8877.5 6717.6 2.7 13 12327 78.5 130.9 -5339.7 4416.6 8880.5 6732.3 5.1 14 12353 79.0 131.0 -5356.4 4435.9 8885.6 6757.7 2.0 15 12401 79.3 132.0 -5387.7 4471.2 8894.6 6804.7 2.1 16 12433 79.8 132.6 -5408.8 4494.5 8900.4 6836.0 2.4 17 12446 79.8 132.6 -5417.5 4503.9 8902.7 6848.7 0.0 Customer Well Name Location M.DEPTH ft 12025.00 12033.00 12058.00 12083.00 12109.00 12139.00 12183.00 12200.00 12235.00 12260.00 12285.00 12312.00 12327~00 12353.00 12433.00 12446.00 DRILEX/RADIUS HORIZONTAL BRITISH PETROLEUM X-RAY X-09Ll SIDETRACK PRUDHOE BAY,AK '-Cf! It Page 1 of 1 Date 7/11/1995 Filename : X-09Ll No Interpolation Height of Area Datum above Customer Datum 0.00 ft Height of Well Datum above Area Datum 0.00 ft All TVDs are relative to the Well Datum Level ANGLE deg 53.65 58.00 63.80 68.00 71.00 72.50 74.20 73.90 76.50 76.90 77.40 78.10 78.50 79.00 79.80 79.93 DIR deg S17.15°E S17.000E S17.000E S17.400E S24.500E S30.300E S40.500E S41.200E S45.700E S48.700E S49.600E S49.800E S49.100E S49.000E S47.400E S47.14°E C\L ft 0.00 8.00 25.00 25.00 26.00 30.00 44.00 17.00 35.00 25.00 25.00 27.00 15.00 26.00 80.00 13.00 TVD ft 8789.52 8794.01 8806.17 8816.37 8825.49 8834.89 8847.53 8852.20 8861.14 8866.90 8872.46 8878.18 8881.23 8886.30 8901.02 8903.30 Origin of Bottom Hole Closure AREA CENTRE Bottom Hole Closure 7045 ft 140.3° VIS ft 6465.92 6471.26 6488.86 6507.29 6527.86 6553.48 6593.53 6609.49 6642.82 6667.01 6691.32 6717.65 6732.31 6757.74 6836.06 6848.78 PROJECT TO BIT 12446 OF 13 FEET IS PROJECTED SURVEY N+/S- ft -5112.21 -5118.54 -5139.42 -5161.21 -5183.93 -5209.21 -5243.50 -5255.87 -5280.42 -5296.95 -5312.89 -5329.96 -5339.50 -5356.22 -5408.63 -5417.31 E+/W- ft 4253.98 4255.92 4262.31 4269.06 4277.77 4290.88 4315.27 4325.96 4349.23 4367.08 4385.52 4405.64 4416.80 4436.06 4494.68 4504.08 D'LEG °/100 0.00 54.40 23.20 16.86 28.05 19.03 22.54 4.33 14.48 11.79 4.04 2.69 5.29 1.96 2.21 2.21 -~- ., DRILEX/RADIUS HORIZONTAL CASPER,WYO./HOUSTON,TEXAS BRITISH PETROLEUM A / 0:/- \ /C¡ 7 tr ì" L· v Well Name Location X-RAY X-09L1 SIDETRACK PRUDHOE BAY,AK Date DIRECTIONAL DRILLER SURVEY PERSONAL 7/11/1995 LARREN HOLDREN BILL BLAND,MIKE MURPHY This survey is correct to the best of my knowledge and is supported by actual field data./~ I / /:·-'.;0->;L;'~. . . . . ·~:2;<~-o¿:-';-;-./CbMPANY REPRESENTATIVE DRILEX/RADIUS HORIZONTAL Customer Well Name Location X--Olft BRITISH PETROLEUM X-RAY X-09L1 SIDETRACK PRUDHOE BAY,AK Date 7/11/1995 Filename : X-09L1 No Interpolation Height of Area Datum above Customer Datum 0.00 ft Height of Well Datum above Area Datum 0.00 ft All TVDs are relative to the Well Datum Level Plane of vertical section Latitude & Departure relate to vertical section Originates at Slot Coordinates Directions Referenced To Depth at Drill Floor Calculation Method Target Details No. 1 2 Lat -5367.00 -5545.00 TVD 8880.00 8895.00 Points of Interest No data Magnetic Declination :+28.390 AREA North +00 0 I 0 I I (T) Grid convergence +0.0000° 126.7° AREA CENTRE SLOT CENTRE Lat O.OOOft Dep O.OOOft GRID NORTH 0.00 ft MINIMUM CURVATURE Dep 4475.70 4745.00 2.21 4.04 2.69 5.29 1.96 2.21 19.03 22.54 4.33 14.48 11.79 D'LEG °/100 0.00 54.40 23.20 16.86 28.05 4504.08 4385.52 4405.64 4416.80 4436.06 4494.68 4290.88 4315.27 4325.96 4349.23 4367.08 E+/W- ft 4253.98 4255.92 4262.31 4269.06 4277.77 -5417.31 -5312.89 -5329.96 -5339.50 -5356.22 -5408.63 -5209.21 -5243.50 -5255.87 -5280.42 -5296.95 N+/S- ft -5112.21 -5118.54 -5139.42 -5161.21 -5183.93 PROJECT TO BIT 12446 OF 13 FEET IS PROJECTED SURVEY 6848.78 6691.32 6717.65 6732.31 6757.74 6836.06 6553.48 6593.53 6609.49 6642.82 6667.01 VIS ft 6465.92 6471.26 6488.86 6507.29 6527.86 Origin of Bottom Hole Closure AREA CENTRE Bottom Hole Closure 7045 ft 140.3° 8903.30 8872.46 8878.18 8881.23 8886.30 8901.02 8834.89 8847.53 8852.20 8861.14 8866.90 TVD ft 8789.52 8794.01 8806.17 8816.37 8825.49 13.00 25.00 27.00 15.00 26.00 80.00 30.00 44.00 17.00 35.00 25.00 C\L ft 0.00 8.00 25.00 25.00 26.00 S47.14°E S49.600E S49.800E S49.10oE S49.00oE S47.40oE S30.30oE S40.50oE S41.20oE S45.70oE S48.700E DIR deg S17.15°E S17.00oE S17.00oE S17.40oE S24.50oE 79.93 77.40 78.10 78.50 79.00 79.80 72.50 74.20 73.90 76.50 76.90 ANGLE deg 53.65 58.00 63.80 68.00 71.00 Height of Area Datum above Customer Datum 0.00 ft Height of Well Datum above Area Datum 0.00 ft All TVDs are relative to the Well Datum Level No Interpolation Page 1 of 1 Date 7/11/1995 Filename : X-09L1 'I ,-07 A BRITISH PETROLEUM X-RAY X-09L1 SIDETRACK PRUDHOE BAY,AK DRILEX/RADIUS HORIZONTAL 12446.00 12285.00 12312.00 12327.00 12353.00 12433.00 12139.00 12183.00 12200.00 12235.00 12260.00 M.DEPTH ft 12025.00 12033.00 12058.00 12083.00 12109.00 2ustomer well Name Location Well Name Location Date DIRECTIONAL DRILLER SURVEY PERSONAL --, DRILEX/RADIUS HORIZONTAL CASPER,WYO./HOUSTON,TEXAS BRITISH PETROLEUM / C) ,.1----- \ /01 tf ¡ - v X-RAY X-09L1 SIDETRACK PRUDHOE BAY,AK 7/11/1995 LARREN HOLDREN BILL BLAND , MIKE MURPHY This survey is correct to the best of my knowledge and is supported by actual field data. /_ / / /' /' (,-;/.-~,/ ..._:". I<?r- ..t ~._ " . . . . . . '~.+-o~'--/'.-.{ç-~-COMPANY REPRESENTATIVE -1 DRILEX/RADIUS HORIZONTAL )(-0/4 Customer Well Name Location BRITISH PETROLEUM X-RAY X-09L1 SIDETRACK PRUDHOE BAY,AK Date 7/11/1995 Filename : X-09L1 No Interpolation Height of Area Datum above Customer Datum 0.00 ft Height of Well Datum above Area Datum 0.00 ft All TVDs are relative to the Well Datum Level Plane of vertical section Latitude & Departure relate to vertical section Originates at Slot Coordinates Directions Referenced To Depth at Drill Floor Calculation Method Target Details No. 1 2 TVD 8880.00 8895.00 Lat -5367.00 -5545.00 Points of Interest No data 126.7° AREA CENTRE SLOT CENTRE Lat O.OOOft Dep O.OOOft GRID NORTH 0.00 ft MINIMUM CURVATURE Dep 4475.70 4745.00 Magnetic Declination :+28.39 AREA North +0° 01 Olf (T) Grid convergence +0.0000° ~- /rc~~. Jt- ¡(f( mi BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Frl~. :x -t/f A- C()-Lf7 To: Jack Hartz, AOGCC Fro m : Len I Seymour f" ' '~": ~ l.. ""L.a '11 t;U NOV 1 Î. '\995 .~ v f l:i , j ) I . j; )./ ,/ "I , )//j/, ¡' i.' I i " Date: 11/6/95 Alaska .Oil & Gas Cons.Commissio.n . ! Anchoragtt Re: Waiver of initial static survey requirement for well X-09A. This letter is to follow-up a verbal conversation on 11/3/95 between Beverly Luedke-Chan, BPX (Alaska) Inc. and Jack Hartz, AOGCC where the AOGCC agreed to waive the need for an initial static survey on well X-09A in the Prudhoe Bay field. Well X-09 was sidetracked earlier this year. X-09A came in with not enough oil to economically produce. It has no surface facilities. A static survey was obtained on the original well, X-09, 3/27/95. cc: X-09A well file Beverly Luedke-Chan /.--=-..~ State or Alaska Oil Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 907 -279-1433 Radius, Inc. Horizontal Guidance Systems POBox 272704 Houston TX 77277 -2704 tt ç/ v\ 1 q(~C{ Re: Natura! Gamma Ray MDITVD for PBU X-09A and PBU S-17AL 1 BP Exploration Operator The Commission acknowledaes the receiDt of the followina data: . H_ - ___u...____" __,u,_ "---..;;1-- .-.- . ---'r- -- -..- .-,.- "'.'..;;1 -,---, Well Name PBU X-09A PBU S-17AL 1 Description Gamma Ray Gamma Ray However in accordance with AOGCC regulation, 20 ACC 25.071 (5), (5) a sepia and a reproduced copy of alllögs fun iñ the well (includiñg dipmetêf and composite logs, if available), except velocity surveys and experimental logs. Pleªse forwrd the sepiª copies for the logs listed abQve, ! have atœched photQcopies of the log headersJef ¥9lir assist you in your retrieval and submittal. If you have any questions, please call the designated operator of the wells or you may contact me at 1-907-279-1433. Thank you. Received by: L ~r~ Date: (('/1,3 )qr Copy sent to ara::0es _ no LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: Date: 14 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS WELL ~<;/þ~Co # DESCRIPTION ECC No. C-29 1 PLS FINAL BL+RF Run # 1 2352.04 X-09LI q ') ". 0 4J 1 PLS FINAL BL+RF Run # 1 5638.05 E-27 ~1/IO~ 1 PDK FINAL BL+RF Run # 1 6233.03 Please sign and return to: RECI/V 4(JG2 EO Skq Oil '" 1 19n & 0~ .is 3 CIS C. A17cho 01)$. C. ¡qUe 01l7/1J . Date: ~SSio,,·. Ii BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 / / // / / //' // / Subject: Well X-09L 1 API 50-029-20455':'60 Well Permit (95-47) // / // // Well name X-09L 1 and API # n~eds to be changed back to well X-09A and API 50-029-20455-01. Perfqr-itions that were originally left open were squeezed off leaving no ~pén perforations in the original wellbore. Attention: David Johnston, Chairman / // ) 0\ vy{ ~ % D'Î VrJ r y ~D6\U ~.~~~\:~ / Yours Sincerel~y/' b~);~ Br /~¡ Williams U Drilling Engineer FH cc. Well file ~ Petrotechnical Data Center STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLIC.,--'rION FOR SUN'DRY A~/~-)ROV ALS to y 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well_ Plugging _ Time extension Stimulate Change approved program _ Pull tubing _ Variance ..lL- Perforate _ Other _ 2. Name of Operator BP Ex loration (Alaska Inc. 3. Address P. O. Box 196612, Anchòrage, Alaska 99519-6612 4. Location of well at surface _ '') 453' SNL, 372' WEL, SEC. ~ T10N, R14E, UPM At top of productive interval 607 SNL, 1348' WEL, SEC. 17, T10N, R14E, UPM At effective depth N/A At total depth 809' SNL, 1009' WEL, SEC. 17, T10N, R14E, UPM 12. Present well condition summary Total depth: . measured true vertical 5. Type of Well: Development ..lL- Exploratory _ Stratigraphic _ Service Effective depth: measured true vertical feet Plugs (measured) feet feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Cemented Length Size 20x30 13 318 9518 8.5c.y. 3720 c.f. 1819 c.f. 110 2638 11838 measured true vertical subsea Tubing (size, grade, and measured depth) 4 112" L-80 to 11327' with 4 112" tailpipe to 11433' 6. Datum elevation (DF or KB) KBE=72.81 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-09L 1(41-17-10-14) 9. Permit number 95-47 10. API number 50- 029-20455-60 11. FieldlPool Prudhoe Oil Pool feet .- r-~ f ) f~? .J! \ (''"\ f.., f. I i -'J 1\ ¡ ,/ _\ 1 0/-________ ¿ I}. ¡¡ 1. -""'~-__J Measured depth True vertical depth BKB 143 2671 8771 143 2671 11871 RECIE\VED MAY -8 199~ 1\\ö.ska OH & Gas Cons. Commiss n Anchora Packers and SSSV (type and measured depth) 9518" Baker SAB packer at 11327';4 112" SSSV at 2139' 13. Attachments Description summary of proposal --X..- Detailed operations program _ 14. Estimated date for commencing operation BOP sketch 15. Status of well classification as: Title SupeNisor Waterflood and Miscible Flood FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ subsequen. porm r~uired 10- t{ ò 7 :'Igned tly -,~l ,Johnston 16. If proposal was verbally approved Oil.X- Name of approver Date approved Service 17. I hereby cert' hat the for going is true and correct to the best of my knowledge. Signed Approved by order of the Commission Form 10-403 Rev 06/15/88 Gas Suspended _ Approval No. C¡S' O~~ Approved Co _ Returned 5/ID)05 Commissioner Date ,Z:; '~ ?: 5' SUBMIT IN TRIPLICATE -&-~ '~ a {/ Well X-09L 1 tubing-annulus communication Request for variance Well X-09 was shut-in in 1992 with a hole in the tubing because it was deemed uneconomic to fix (high TGOR). BP would like to sidetrack the well with coiled tubing to X-09L 1 , leaving the production tubing in. It is requested that a variance be granted to flow and test the well once it is sidetracked, until such time as corrective action can be taken. Proposed schedule is as follows... 1. Receive variance from State. 2. Coiled tubing sidetrack X-09 to X-09L 1 (permit applied for) 5/95-8/95. 3. POP (put on production) well through a temporary tie-in and perform several well tests to determine if a permanent tie-in and tubing patch are justified (7/95-10/95). 4. Permanently tie-in the well and install a tubing patch. Done by 1/1/96. 5. Evaluate patch. Perform RWO if necessary. Note: because the well has not yet been sidetracked, much of the application data is blank (depths, etc.). At the State's request, we could resubmit the application once the well has been sidetracked. However, we would like the variance before the well is sidetracked if at all possible, as the decision to sidetrack is dependent upon being able to test the well before setting a patch and installing a permanent surface facility tie-in. RECEIVED MA'( -' 8 1995 A.\~.ska Oil & Gas Cons. Commission Anchora - --+ '" Ii BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johnston, Chairman Subject: Well X-09L 1 Well Permit (95-47) Date: April 28, 1995 Please note that the location of well at surface has the wrong Sec. number. The number on the well permit (95-47) is Sec. 04. However, this should be Sec. 07. This error occurs in all Sundry Notice starting March 7, 1986. Brock Williams CTU Drilling Engineer r-' I rH cc. Well file Petrotechnical Data Center -~ ~7'" -~~' p ~~ ¡·'7( ;f !r' ìu1¡7~;- RECE\'JED ~~ '( _ '\ \995 C m\SS\on ( Œ\ & Gas Cons. om p.\~sW1 A{\c\1ara~e --"""" Ii BP EXPLORATION Date: April 27, 1995 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johnston, Chairman Subject: Well X-09A Well Permit (95-47) Well name X-09A permit # 95-47 needs to be changed to well X-09L 1 so that it reflects the API suffix of 1601. Yours Sincerely, ;ZS~ /J~ Brock Williams CTU Drilling Engineer FH cc. Well file Petrotechnical Data Center RECE\VED APR 2 8 1995 A\a.Ska UlÌ & Gas Cons. Commission Anchora,:" 0S"rr ~ 1f Œ lffi r ~ f í~1 iJ TONY KNOWLES, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION I 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 13, 1995 Brock Williams Coil Tubing Engineer BP Exploration (Alaska), Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit X-09~ LI BP Exploration (Alaska), Inc. Permit No. 95-47 ~ Sur. Loc. 453'SNL, 372'WEL, Sec. ~ T10N, R14E, UM Btmnhole Loc. 809'SNL, 1009'WEL, Sec. 17, T10N, R14E, UM Dear Mr. Williams: 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 determinations are made. The permit is for a new segment from existing well X-09 Permit No. 80-28, API No. 50-029-20455-00. Production should continue to be reported as a function of the original well identifier. 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 may be given by contacting the commission petroleum field inspector on the North Slope pager at 659-3607. David W. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habi~at Section w/o encl. Department of Environmental Conservation wlo encl. 1a. Type of work Drill 0 Re-Entry 0 2. Name of Operator BP ExDloration 3. Address P. O. Box 196612 Anchoraae Alaska 99519-6612 4. Location of well at surta,ce ?Øâ453' SNL, 372' WEL, SEC. ;(T10N, R14E, UPM At top of productive interval 607' SNL, 1348' WEL, SEC. 17, T10N, R14E, UPM At total depth 809' SNL, 1009' WEL, SEC. 17, T10N, R14E, UPM 12. Distance to nearest 13. Distance to nearest well property line AOL 28314 @ 1009' feet No close approach feet 16. To be completed for deviated wells Kickott depth 12000 feet Maximum hole angle 90 18. Casing program size Casing Hole 3.75 2.375 ALASKA STATE OF ALASKA _AND GAS CONSERVATION CO PERMIT TO DRILL 20 AAC 25.005 ,ISSION -, Redrill ~11 b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil [X] Deepen DI Service 0 Development Gas 0 Single Zone 0 Multiple Zone 0 5. Datum Elevation (DF or KB) 10. Field and Pool KBE=72.81 feet Prudhoe Bay Field/Prudhoe 6. Property Designation Bay Pool AOL 47475 7. Unit or property Name Prudhoe Bay Unit 8. Well_~umber Number ~t) X-09,'{:I1-17-1 0-14) 2S 1 00302630-277 9. Approximate spud date Amount Apri/20, 1995 $200,000.00 4. Number of acres in property 15. Proposed depth (MD and TVD) 11. Type Bond(see 20 AAC 25.025) Specifications Weight Grade Coupling Length 4.4 70 Coil 1095 2560 12730' MO, 8901 'TVO feet 17. Anticipated pressure (see 20 MC 25.035 (e)(2)) o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 pslg Setting Depth Top Bottom M D TVD M D TVD 11330 12425 8886 Quantity of cement (include stage data) No Cement 8350 _'" __roo.. RF( ¡-'VtlJ . - 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical measured true vertical 2152' 7" 454 cu ft 11376'-13528' measured 11995'-12027'(Sag R), 12168'-12195', 12189'-12213', 12230'-12262'(lvishak) true vertical 8772'·8791'(Saa R).8872'-8923'(three Ivishak intervals} 20. Attachments Filing fee IR] Property plat 0 BOP Sketch IR] Diverter Sketch 0 Drilling program ŒI Drilling fluid program IR] Time vs depth plot 0 Refraction analysis 0 Seabed reportD 20 AAC 25.050 requirementsD 21. I .herebY ~ti~ tha} thV~r;;g.»ing_ is true and correct to the best of my knowledge L/ J } ~ .....__ SIgned ØZ4J~ /J){ff Á-/L/ÞúA Title Coil Tubing Engineer Date I(/¡ 7) . Commission Use Only PermibNumber r~~//.6-e:.. .s:.QA1¿ iii Approvfil date See cover letter /:5-97 50-02,7-2-07'S.5-60 I J..//I~ 79~ for other requirements Conditions of approval Samples required 0 Yes J3 No Mud log required 0 Yes ]X No Hydrogen sulfide measures 181 Yes 0 No Directional survey required ~ Yes 0 No Required working pressure for BOPE I D2M; ~~ D5M; 010M; 015M; Other: ungma Signee --S~Së>ø Approved by David W. Johnston Form 10-401 Rev. 12-1-85 Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: p\PR - 6 1995 . \';,sKa UÜ & Gas Cons. Commission 1-\..... . Anchor, ' 13528' feet 9634 feet 12264 feet 8998 feet Plugs (measured) Junk (measured) Length Size Cemented Measured depth True Vertical depth 110' 20x30" 8.5 cu yd 143' 143' 2638' 13 3/8" 3720 cu yd 2671' 2671' 11838' 95/8" 1819 cu ft 11871 ' 8771' 8467'-9634' Commissioner by order of !- me commission Date 'f !J 7) 7~ Submit in triplicate -- , BPX X-09 Sidetrack Summary of ODerations: X-09 is currently shut-in due to high water cut. The well is being sidetracked to achieve lower water cut production. This sidetrack will be conducted in two phases with an operation shut-down of 4-6 weeks in between Phase 1 and Phase 2. Phase 1: Cut Window: Planned for April 20 thru April 24 - The existing Ivishak perforations will be isolated with a 50 ft cement plug. - A whipstock will be set on Eline at the top of the Sag at 12,000' MD. - Utilizing a conventional coil tubing unit, a window will be cut in the 7" and 10ft of formation will be drilled. - Coil unit will then be rigged down and 4-6 weeks will elapse before resumption of operations. Phase 2: Drill Directional Hole: Planned for May 29 thru June 9 - Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan to planned TO of 12,730' MD (8,9011 TVD). Mud Program: - Phase 1: Seawater - Phase 2: Xanvis (8.6 - 9.0 ppg) or Seawater (8.6 ppg) Casing Program: - A 2.318 coil liner will be run from 12,425' back into tubing. The liner will not be cemented. Apx 300 ft of hole will be left open. Completion Issues: - The existing tubing has a hole in the vacinity of the bottom gas lift station. The well will be tested following the drilling and a coil tubing patch will be run if test demonstrates commercial rates. Well Control: - See attachments. - Phase 1 will utilize "Type B" BOP arrangement (no circulation system, all returns will be sent down flowline). - Phase 2 will utilize "Type A" BOP arrangement. - Both BOP arrangements allow for tree to remain in place and for the BHA to be fully lubricated above the swab valve. - Lubricator/pack off is pressure tested on each trip. Directional - See attachements. - Kick Off: 12,000' MD (8,775' TVD 88) - TO: 12,730' MO (8,9011 TVO S8) - Magnetic and inclination sUNeys will be taken every 25 ft. No gyro will be run. Logging - A gamma-ray log will be run over all of the open hole section. RECE\VED ~\PR - 6 1995 ,_ - _.\/' 0'\1 & Gas Cons. Commission I-\.\i:t'j~a I Anchor~ I CUiient Condition TREE: S" crw WELLHEAD: MCEVOY ACTUATOR: OTIS X-09 @ 95/8" DV PACKER 12578' I 13-318", 72 #/tt, L-80, BTRS 12671'1- KOP: 2800' MAX ANGLE: 62°/12,500' 4-1/2", 12.6#/tt, L-80, IPC, TUBING TUBING ID: 3.958 " CAPACITY: 0.01522 BBlIf"1 I I TOP OF 7" LINER h 1 r377' 1 r.;~"Ì3~~~/tt, 111 r871' 1- PERFORATION SUMMARY REF LOG: SWS - BHCS 06-29-80 KB. ELEV = 72.81' BF. ELEV = 40.38' SSSV LANDING NIPPLE 1 2139'1 (OTIS)( 3.813" ID) o o GAS LIFT MANDRELS 5 4 3 2 1 9° 54° 50° 48° 50° 111 r23S' I 111 r308' I h 1 r327' I SUDING SLEEVE OTIS "XA" (3.813" ID) TUBING SEAL ASSY. 20' BAKER SBR 9-518" PACKER - (BAKER SAB)(3.813"ID) 4-1/2", 12.6 #lft, L-80 TAILPIPE 4·1/2" "X" NIPPLE I I I (OTIS) (3.813" ID) 11 r371 4 1/2" "XN" NIPPLE I I (~TIS) (3.725" ID) 11 ,401' 4·1/2" TBG TAIL = (3.958"ID) (ELMD) , SIZE SPF INTERVAL OPEN/SQZ'D 3-318 " 4 11.995· 12,027' OPN 1-7-89 3-318 " 4 12,168 - 12,185' OPN12125190 3-318 . 4 12,189·12,213' OPN12J25190 3-318 " 4 12,230 - 12,262' OPN12125190 2-718" 4 12,268 - 12,287' SQZD/3-17 -86 Shublj 112221' I TOP SAND BACK - 112,400'1 POSTURCOTD_ PBTD 11 ~J4F\F\' , 7" ,29 #/ft, L-80, BTRS 113r528' I - RECEIVED AFJR - 6 î99b Ä.\(;;.~ka Oil & Gas Cons. Commission Anchon I Proposed Sidetrack I X-09A TREE: 6' crw WELLHEAD: MCEVOY ACTUATOR: OTIS @ 9 5/8' DV PACKER 125781.1 13-318", 72 #Ift, L-80, BTRS 1267111- KOP: 2800' MAX ANGLE: 62°/12,500' 4-1/2', 12.6#Ift, L-80, IPC,1UBING TUBING ID: 3.958 " CAPACI1Y: 0.01522 BBLlFl I I TOP OF I I 7' LINER 11 r3771 ~~~'à~~~m, 111 r871 1 1- Set Whipstock a 12,000 I PER~ORATION SUMMARY REF LOG: SWS - BHCS 06-29-80 SIZE SPF INTERVAL OPEN/SQZ'D 3-318 ' 4 11,995 - 12,027' OPN 1-7-89 3-318 ' 4 12,168 -12,185' OPN12125190 3-318 ' 4 12,189 - 12,213' OPN12125190 3-318 ' 4 12,230 - 12,262' OPN12125190 2-718' 4 12,268 - 12,287' SaZD/3-17-86 112,1 00 I Top Cmt Plug 112221' I 112,40011 POSTURCOTD_ PBTD 11 ~J4hh' 1 7' ,29 #/ft, L-80, BTRS 113,5281 I - KB. ELEV = 72.81' BF. ELEV = 40.38' SSSV LANDING NIPPLE I 21391 I (OTIS )( 3.813' 10) GAS LIFT MANDRELS 111 r236' 1 111 r3Q8' 1 h 1 r327' I SUDING SLEEVE OTIS "XA' (3.813' ID) TUBING SEAL ASSY. 20' BAKER SBR 9-518' PACKER - (BAKER SAB)(3.813"'D) 4·112', 12.6 #lft, L-80 TAILPIPE 4-1/2' 'X" NIPPLE 1 1 I (OTIS) (3.813 "iD) 11 r371 4-1/2 I "XN" NIPPLE I 1 I (OTIS) (3.725 "iD) 11 ,401 4-1/2" TBG TAIL = (3.958"ID) (ELMD) 1 RE(EIVED APR -- 6 '1995 Alaska OJ¡ & Gas Cons. Commission Anchorí. -_.-_.~----_._--_._---_._-'---'-------------------_._---..----..----.------------. 8700 - 8800 Qí CD LL - 8900 c > t- Marker De TSGR X-09A Vertical Section TSHU S ,7961 ft TVD Departure (Feet) 6400 S,S751ft TVD 6600 8000 TSAD 6800 7000 7200 7400 7600 7800 -i Target Kick Off De rtr @KO __~__ '20~e~~g~_@_~O_.:.=_5~ ~eº-_____ ___ __ __________ TSHU -------------------------------- MD KO Pt MD New Hole 12,000 730 DL 2= 11.3 deg/100 Incl Crv 2= 83 deg Total MO TVD TO 12,730 8,901 -; - ßJTSAD Target Depth 9000 _. Build Rt de /100 MD ft ....... Curve 1 14.5 160 5:- (r. :;¡;;- Curve 2 3.0 220 f,\.~ .,....., }": ,. Ai 2.0 350 Curve 3 .~ m :.Þe) n :::T OJ Original Hole g.m !~1 00 0 C"':, ~ 0 ~ < ~ C") 0 rn :=;¡ Drawn: 3/31/95 § 14:58 ëñ' en õ· ~ Plan Name: First Directional Plan · -,.."-.~-,.__...__._"._._"---,~-"-"_.--."_'-_'.__'__.---------.---------------.-------- X-09A Ft East Of Sfc Location + Plan View ..1--1- I -- -4,800 --..+ -5,000 -5,200 -5,400 -- -5,600 -5,800 -6,000 -6,200 -6,400 -6,600 -6,800 3, 00 4,400 4,650 4,900 5,150 5,400 5,650 5,900 Original Wellbore Ft South Of Sfc Location Down-to-the NW 20' Fault :¡;;, ~.. w, ~"., p.; ~- J> :;;0 p,:: u m ::.b c :::0 n =:I 0 tLI ~. In m 0 C":.r -,: 0 0; '" -' < ~ '-D 0 <-.0 m 0 3 CiI 3 ~::J ~. ~. =' ¡Well Name X-09A ClOSURE I o~:tance 7,313 ft 1 39 deg NEW HOLE EIW eX) N/S (Y) Kick Off 4,248 -5,093 Top Sad 4,441 -5,336 State Plane 669,964 5,934,332 TO 4,785 -5,530 State Plane 670,308 5,934,138 Surface Loc 665,523 5,939,668 TSAO Step Out 188 MO of TSAO -> TO 396 Curve 1 Curve 2 Curve 3 AzCh -9.0 -11.0 0.0 Drawn: 3/31/95 14:58 Plan Name: First Directional Plan -'1, 2.3.2B Blind/Shear ...:' "'Blind/Shear ....)... ....-ri Coil Tubing BOPE Pipe Rams Slip Rams Manual Swab Valve I Pump-In Sub I . BOP Stack Type B To be used when no mud will be circulated Spacer Spools (as needed for Height) ~ I Existing Flowline I Hydraulic Actuated Valve I Manual Master Valve I RECEIVED J\P~1 - 6 1995 i~,ir.-t.:jk;,~ un & Gas Cons. Commission Anchort Lih Gas In (if applicable) .. iii! i ~. J I L.3.2A Blind/Shear Blind/Shear Coil Tubing BOPE Pipe Raxns Slip Rams I Pump-In Sub I . BOP Stack Type A To be used for drilling with mud Spacer Spools (as needed for Heioht) ~ . -- ~ Manual Swab Valve ~ I Existing Flowline I Hydraulic Actuated Valve I Manual Master Valve I RECEIVED ~\PR - 6 "ì99t; :i.ic,s\{a Uil & Gas Cons. Commission Anchon Lih Gas In (if applicable) Seaw er : FLUID FLr~~·~ SCHEMATIC (with Type r~' BOP) MeOH Green Tank (Divert) ad Crude (vac trucks) Tank Farm - QQ QQ ~, , , , , , Q9 , Charge Pump Cuttings MI Van 3 B.J Pumper Nonnal flow Gas Divert Fluid transfer from tank fann/upright tanks to BJ/MI Manually operated valve Cosasco Valve /~ ~ / / / / / / / / / Choke Manifold ~ ~ «-tlJ I t CTU Squeeze Manifold R ECE\VED p,PH -- 6 1995 i\\c:,~;Œ. Oil & Gas Cons. Commission Anchor,- WELL HOUSE SEAWATER II ~~~~~~~~~~~~~~~~~~~1 ~~¡~: GrlEEN (DIVErlT) TANI< 1((11. 1!"li 1\11;; lilli" ~ eN CHA~~·~"~UMP ······~~~ATERS~ L^B ! : E : ~I _ flnST AID STATIONS EMERGENCY ESCAPE PACKS scon AIR PACKS PRESSURIZED N2 BOTTLES On-tER FIRE HAZARDS - PAINT, LUBnlCANTS, RAGS, CHEMICALS,... HALON DUMP/STORAGE EYE WASH STATION FUEL STORAGE H2S SENSORS OR WARNING LIGHTS GENERATOAÞ~ e s o o X E . . Å CLASS I, DIV IT· MI VAN 3 I- BJ PUMPER 5' ~. Å Å H2S/LEL SENSORS OR WARNING LIGHTS T I GLYCOL STORAGE . ESD fiRE EXTINGUISHERS + C.' J,> -D v.:o ::Þ ~ :::(] g fu- =:J- (,fJ ! g g OJ :::; ~ C") ~ g (.Tt § w· tr.. õ' :::1' Site Plan (with Type 'A' BOP) WIND SOCK S I, DIV I AND DIV II . BLEED TRAILER e WELL (Sarod Out) WELLS SHOWN ON 50' CENfERS .~ GENERATOR ~PROX 120' \, /0 SCS HE^TER_~ _lei ~~~~~ -L£] .. ~ GENEn^TOr¡~ ~ SOHIO TRAILER DIRECTIONAL DRILLERS rn Ë"'" rT'!I < r-n C1 1.2.23v5 COMPANY .fi jJ IN IT CLASS ..I?ev WELL PERMIT CHECKLIST FIELD & POOL C;; ~C>/)r) ADMINISTRATION PR ~ ENGINEERING APPR Jl3- -- GEOLOGY APPR ~ /--ð>~'/ 1- 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached. . . . . . Lease number appropriate. . Unique well name and number. . Well located in a defined pool. . . . . . . . . . . . . Well located proper distance from drlg unit boundary. . Well located proper distance from other wells. . Sufficient acreage available in drilling unit. . If deviated, is wellbore plat included . . . . . Operator only affected party. . . . . . . . . . . . . Operator has appropriate bond in force. . . . . . . . . .Y Permit can be issued without conservation order. . . . . Y Permit can be issued without administrative approval. . .Y Can permit be approved before 15-day wait. . . . . . . . Y ..... WELL NAME me{ )(-07't'? GEOL AREA ~ n UNIT#' PROGRAM: exp D dev D redrll';1i serv D .//~0 ON/OFF SHORE ClA./ N N N N N N N N N N N N N REMARKS -f-£~~~{-v &-~& Wa/£ A-P:¡:" ¡¡. SZ>- o?Jf- ~S5-()O t:1 o z o 1-3 :E: þj 14. 15. 16. 17. 18. 19. 20. 21- 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided . . . . . . . . . . . . . Y N (- JA _ ð Surface casing protects all known USDWs . . . . . . Y N l (~ !'~ CMT vol adequate to circulate on conductor & surf csg. . Y N ~: :~~l a::~~:t:l~o k:~:i:r~~:~t~~:i:~r~~o::~f . c:g . .... ~ ~ ~. Q- :t=J 11A.--~ Â -fl ~ Casing designs adequate for C, T, B & permafrost.. (Ï) N " --_P Adequate tankage or reserve pit. . . . . . . . . . . . <!!t:> N ß "I~.. ~ CHf ~p-. . ~ I; .A ð U... e If a re-drill, has a 10-403 for abndnmnt been approved. .~ I~~ ~~ ~ ~,~~ ~~ Adequate wellbore separation proposed. . . . . . . . ·A· Y N ^~ Cì~ If di verter required, is it adequate. . . . . . . .J IT ~ ,.,.'"""""'"'" (I.... Drilling fluid program schematic & equip list adequate .(2) N ;"~. ~~ ~- BOPEs adequate . . . . . . . . . . . . . . . . . . . . .~ N ~ ~~ BOPE press rating adequate; test to 3S2'V psig.lj) N Choke manifold complies w/API RP-53 (May 84).. ...~ AlJ4- Work will occur without operation shutdown. . . . (S) N Is presence of H2S gas probable . . . . . . . . . ex> N 30. Permit can be issued w/o hydrogen sulfide measures. . . .Y 31. Data presented on potential overpressure zones 32. Seismic analysis 9f shallow gas zones. 33. Seabed condition survey (if off-shore) . 34. Contact name/phone for weekly progress reports [exploratory only] GEOLOGY: RP9Ifc:::- COMMISSION: :~ TAB~ ~ 7~ Af]: ENGINEERING: BEW~ ~o .mH~ HOWfjo - A:\FORMS\cheklist rev 03194 H 1-3 trj - )cuf~+ /Pf ~ ~ H z 1-3 ::r: H (j) (j) ,// 44; ~ Þ> n trj ~~~~ .J1j- --- NOTICE The following well logs and oversized documents have been placed in offsite storage. If you would like to view the original documents, please contact the AOGCC librarian. AOGee 3/4/2005 STATE ALASKfl M. MURPHY DRLX HOLDREN CASING RECORD SIZE UGT. FROM 5/8w 47" SURF 29" 11377' ~ SysterT1S Inc. NATURAL GAMMARAY MD/TVD E..t ~ J_~.G.__.~..9 . API " 50-029 20455-60 COMPANY UELL FIELD COUNTY ~R I 1:.J §..tI... . P.. ~.I g º~. ~J)J1 ~.-..~ ªfI... ..' . P.T(LJ Q.!1.º.E.. .13 .A..Y.lJ N.J. T ~..9.B.T..~ ~~ Q P'E.. B_9 R· . LOCATION: 453 FNL & 372 FEL SEC 7 PERMANENT DATUM: TWP 10N MSL RGE 1~..t.=: ELEV:0' .. . ,.."..".. "M'_ ..._~__._ ." .',' ... .... LOG MEASURED FROM 7 2.. ~.~. ! DRILLING MEASURED FROM FT ABOVE PERM DATUM KBE DATE RUN No. TD LOG RUN DEPTH - DRILLER 12446' ~95 DEPTH - LOGGER 12435' '1·1i.:·~a (/ì! .,: r;ar: (:"'" <". 'if'"'''' . ""it! "~"rl)" BOT TOM LOG G E DIN T 1 2435 ' . ':,.. :"';1'Y:! '. c~ '." ~ TOP LOGGED INT 11695' TYPE FLUID IN HOLE FLO-PRO MUD SALINITY PPM CL. 21000 DENSITY 8.6 LEVEL FULL MAX TEMP DEG F 200 OPERATING RIG TIME 8 MINUTES OPERATOR U BLAND UITNESSED BY BP PE STAFF RUN BORE HOLE RECORD NO. BIT FROM TO 1 3.75w 12025 12446 9 7w P.O. Ba: 2727D4 Bønstaa.. Taas T1711-27D4 (113) 43.1 2!KIO .,..." ... ... . ~ ., ... - ...~ OTHER SERV: COIL TUBING DRLG ASSY ELEVATION: KB. 72.8' DF, G L. 3 ª:.? .' TO 11871' 13528' E a: 0:: 19 o œ: a.. ~ ð? ro )- a: -1 Q.. (\1 a.. ~ ..... I'- (Jì X . . W -1 H u.. """ lO (Jì I N .. W E H I- .N I (Jì CSJ CSJ CD ..... .. W I- ([ Q l- LL IS! CSJ f'.. """' """' I I- a.. W Q I- 0:: a: I- Ul 1} LiZ) r r:ð t{7 Radius, Inc. Horizontal Guidance SysterYìs NATURAL GAMMA RAY MD/TVD FILING NO. API tt 50-029- 20455-60 COMPANY WELL FIELD COUNTY B~JIJ S.H P ETROLE U M E XP LOR A T ION X. =-_~nª-!L....._.. ...___...._....._..__._.. . . ._._.._............ e.E..~Jn:LºJ;...J?..RY_._.~~..I.I.n.... N.._~n_...§..LQ.P.~_...ªº.B.g_y...GJ:I..._....... S TAT E 8.~JtS(.B LOCATION: 453 FNL & 372 FEL SEC 7 PERMANENT DATUM: TWP 10N ........"...-...-........,-....--.,..-, ... ._.--':'1..§._'=.....____....._._.____.._._..........._........ RGE 14E E LEV : 0..:_.._.__.____ _..··_..~~____"__,·.",·..,.,....._'."_·.H._.'.._ " ,,- ._"'~.._-_.-_.'"..."..__._---...._---_.... LOG MEA SUR E D FROM _.._00.______ F T ABOVE PERM D A T U M DR ILL I N G MEASURED FROM __K.êJ;__...._______.__...._...____.__..__.._.__.._ DATE JULY 11 1995 RUN NO, FINAL DEPTH - DRILLER 12,446' DEPTH - LOGGER 12,435' BOTTOM LOGGED INT 12,435' TOP LOGGED INT 11.695' TYPE FLUID IN HOLE FLO-PRO MUD SALINITY PPM CL. 21000 DENSITY 8.6" LEVEL FULL MAX TEMP DEG F 200 DEG OPERATING RIG TIME 8 MINUTES OPERATOR W, BLAND WITNESSED BY BP PE STAFF RUN BORE NO. BIT 3.75" M. MURPHY DRLX: HOLDREN P.O. Box 272704 Hønston.. Tøxas T12n-2704 (713) 433 250D OTHER SERV: COILED T8G, DRLG. ASSY. TRI-AXIAL STEERING ELEVATION: KB. 72.8' DF, G L, ~ª __ _.ª_'________ HOLE RECORD CASING RECORD FROM TO SIZE WGT, FROM TO 12025 12446 9 5/8" 47" SURF 11871' 7" 29" 11377' 13528' 45" 12.6" SURF 11403' E: Œ 0:: (..9 o 0:: 0.. ::( U Œ III )- Œ .-J 0.. (\J 0.. :J (f) Sj I-- T"""I Z ['- H (I) 0 X Q.. )- W W .-J > H œ: " LL ::J If) (f) (\j If) IS) oð (\j ~ If) w m If) > 0 m (I) œ: I-- ~ I ::J " (1) u " ..--I If) ..--I Q CD W > """" )- E I-- (\j -1 H ~ :J I- "- .. 3: :E (S) 0 I t9 œ: T"""I 0 u.. T"""I -1 (S) Q OJ :E T"""I ([ .. m w IS) l- I ([ X Q l- LL ~ "\t '1 (\J T"""I I I- 0.. W Q I- 0::: ([ I- (f) ~ (;)ò ~dll.· ~: "'" V ".: '.':, (Loak' Detoct i on,i ": :;r ~, ! PRODUCTION LOGGING S~~VI.CE~ . , :::",-,'·::':':f¡ '5638.05 ,,~BP':' EXPLORA T I O'N (ALASKA) H NC'~' XtØ;9L' .. ... ........ .... .... n' i PRUDHOE BAY::~; !N~R~H¡sL()PE . STATE A(~~KA, 1...,0 c;AT LON,~' 'l: ), ~ );, ': -~ i ,i (,\:' 'i '{" f ,)URE,^CE· : t,; ::.' i, ::1 453 r\ FNL +-.,:,~-r{gt~F[L~ c _:{ : :r".;:' .;~.:' Î :~ ,.>EC; :7. !::;,.~I:T\JP~,I~~.. RGE 14E. ~'. " CO~:~ANY :.~ "l'~ ',i \ WEL;L::' , API::.NO.::: ;, ~_:,':.': .,1,: ì <?':',,:,\:~; '.<:< '5 Ø,:'0.29 - 2 ø 4 5 5~' 60 , \ .~,i'.,,,,:':..~ ',"'..:.. ~<; '"i... , "<..;,, ,",'" ..:}, ':,):.;:,,::::r:,~..,..):~; ·'·'::.',;:·;i."':':;:','F.t:~AL PRINT :,'>:;"':'.:,:',;-.,:';.':(: I ' ''';::·':·:::''~,.::i:,::::.!:)~ '~ " F I E:tD: (\. : ;\' OTHER Sf,RUICES NONE ~} II): " , PERM:ÔNENT DATUM M~$ ~ L. ¡Etj¿~AnoN ø FT. " Lo~;H,t~SUREDFRoM,..R.K.B~,·' Ff'''''À~OUE PERMfiÑEtÚ,·DATU~1 ~~ DR] Lb:'\,MEAS. FROM R.K . B, GL' TE" ~ : ,:' ',~., '" D()':,':'~.':,~ --J \ :';:<!;:~, ,'i', RÜ-Ñ '.' ,.':.":~' ::::. .. '. SERUlêE ÔRDER' ~ 'fi3\ì5~' U\' i (:'; :¡' fu' , .};{ :.,\" ,..i .:'~',~ \' : -__~......._,__ ~__ ...,.J..........~ ___.. _ºf.E.',IH+t)RI-LLER · ., , 1 2446'·'¡ PBTD·..·,:~ 4/~ ,_' Ii' ':,¡.' ;~.'; ',:.'~,~'r,"" ':.'~' ~',',:.. : DE.·PTH~LOGGER , " , '11'30Ø:'1 tD NOT¿r~(D V& ' -Y~^' .ii,.( ',::;\"~ i'-:".::; '.~ .,..,.-,................~ -~--_.. ........~~--~~,..,- (..."&~......._~----, ' ';BqT~O~l L9GGED· r.~11R.uAL..+ ;ll~~~~ ;:,.:;, :'..:'~: :--~ce-&-_.-!.-fq~-'-'-'-'----+-~~~7f. " TOP~kOGGEO INTERUAL ':' .sø (...; !r~:~t ;'};'~I~' . A q$ ", v,"(t, . "",'d": 1lPE'>ftULº-_tN_~OL~=-_ 'y fRODqÇË{)~<FLuIDSilJc;fQ~ ;~~.-~_-1t :.;": :" , ' SAll!dlII PPM CL-=--~ N .I~. . . : ~ . ¿J·'I'J~. ___.__ . "v[)E:NSI TY LB/GAL. :' .' N;.·f\,~:,.;, .'.'¡', '''~£l l : . , :TLEÕ[r~ .' \ ':; FtO~lNG· ¡ _.___.~),,~, >~ ;':;: MAX}~:~EC. TEMP. DEG. F . 12\; ""(; ':: :;. ,. ¡,' OPR~);R'fG TIMY--:--¡--- :!¡ ,c~ANE::rRHCK' \ ~. ;i !;T ''', ;:'..'; EQUIP~~:; N~"í LOCAr!~_ }ïrr=-653ï-r:=rnORn~ SLOPE ~L,:,','''''''..,.,'." ':-,.', ..,::..... ,', .:;', RECOROED BY, ::: :R.i ECK :~..,: ~ . ~ÏJïTNEgSËD By-'------y,· ;J~~ SH~ARP!;.·:,,:: ~ BOREHOLE RECORD: ,(' . BIT FROt1\ ... ~ ' . ... ~.'.' ",,' , ",' ~", . ,,', .' .:. : ~.' ", . ," j'''i;('~' . ::::.~;;-[. í:.......--.............. I .~ i ..~,-, CASING RECORD ~El GlH -12 LB 47 LB 29 Lß IZ.6 LB FROM .~ 0" " o 11377' " o . 11338',. TO ". 2671" .>: 1187:,1' ':, :~... : 13520', J: I 11403'.· ,~ 12442' :. 4 Ilr 'l UB" .