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Home My WebLink About195-100XHVZE Pages NOT Scanned in this Well History File 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. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Dian~athan Lowell TO RE-SCAN Dat¢7~ Isl Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ II" STATE OF ALASKA t' ALASK~ OIL AND GAS CONSERVATION COMlvllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged a Abandoned 0 Suspended 0 WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 a Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL No. of Completions Zero Other 0 Stratigraphic Test 0 Service 2. Operator Na~e: 5. Date Comp.,,,)'~p., or Aband.... 12. Permit to !)rill Number BP Exploration (Alaska) Inc. 10'Z"f12003 Icj¡'h/b-:> .,&b 195-100/ 303-303 3. Address: 6. Date Spudded 13. API Number / P.O. Box 196612, Anchorage, Alaska 99519-6612 10/11/1995 50-029-22057-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: /' Surface: 11/12/1995 PBUS-27A 1633' SNL, 4048' WEL, SEC. 35, T12N, R12E, UM 8 KB EI t. (ft). 15 F. Id I P I( ). T f P d t. H . . eva Ion. . Ie 00 s . op 0 ro uc Ive onzon: - , . 1223' SNL 227' WEL SEC 03 T11 N R12E UM KBE - 64.47 Prudhoe Bay Field I Prudhoe Bay , ,., I , Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1541' SNL, 17' WEL, SEC. 03, T11N, R12E, UM 11220 + 8917 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 619393 y- 5979855 Zone- ASP4 11315 + 8923 Ft ADL 028260 TPI: x- 618019'" y- 5974966 Zone-'-Aàp4-'---- 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 618235 y- 5974651 Zone-'---'Ä-Sp¡"" N/A MD , - - ---, - ----------- , '"- -., -- - - ,- , 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 0 Yes a No N/A MSL 1900' (Approx.) 21. Logs Run: GR 22. CASING, LINER AND CEMENTING RECORD CASING -- - -- - "", SETTINGD~PTHMD ISeTTINqDEPTH TVD HOLE , '." - AMÖUNT SIZE --- , Wr. PER Fr. ,GRADE "Top" B0TTQM TOP BOTTOM SIZE .,' '-.",CEMENTING RECORD PULLED 20" Surface 110' Surface 110' 13-3/8" 68# NT80CYHE Surface 2689' Surface 2689' 17-1/2" 3296 cu ft Arcticset III & II 9-5/8" 47# NT80 Surface 10635' Surface 8745' 12-1/4" 2393 cu ft Class 'G' 7" 26# L-80 10363' 10649' 8548' 8755' 8-1/2" 280 cu ft Class 'G' 2-7/8" 6.16# FL4S 10410' 11220' 8582' 8917' 3-3/4' 39 cu ft Class 'G" 23. Perforations open .to Production (MP + TVD of Tç,p an~, 24. ,"- ,'- '.. -'-- TUEHNG"RECORD Bottom Interval, Size and Number; If none, state none): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 10290' - 10434' 10350' MD TVD MD TVD 25. --"" ,,--,,- " ,,_,f\~ID,.FRAcTURE:,CEMENT SQUEEZE, ETC. - -, ,,'-- -,- DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED E 10959' Attempt P&A with 11 Bbls Cement ~ ~~ 10360' 2nd Plug; 10 Bbls Class 'G' ,. 1\.\ 9996' Set EZSV with Whipstock on top ,. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production NI A Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO 1/23/2004 4 TEST PERIOD -+ 1,249 1,257 2,316 95° 1,006 Flow Tubing Casing Pressure CALCULATED -1Ir.. OIL-BSL GAs-McF WATER-BsL OIL GRAVITy-API (CORR) Press. 256 24-HoUR RATE""'" 7,494 7,542 13,896 26.6 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or watermJ~mëlt\;! '1Tmf:"1( necessary). Submit core chips; if none, state "none". 1""\1:: V I:: I V [: U None - MS !8fL fEB 0 ~l~~I~ JAN 26 2004 ~t~A\[NŒ~E[) rEB @ ~ 2004. ø -,' . . On If" I ~ r A 'Alaska Oil & Gas Cons. ComrmsslOn :-\ l1 I \, Anchorage Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE I 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10646' 8753' None Shublik 10701' 8791' Sadlerochit I Zone 4 10923' 8898' RECEiVE,D JAN 2 6 2004 . Gomrn~s5ion 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports Anchorage 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /fÔJ Title Technical Assistant Date Ol..~" PBU S-27 A 195-100 303-303 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I A roval No. Drilling Engineer: Phil Smith, 564-4897 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible. Water Injection I Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ( ( Well: S-27B Accept: 11/26/03 Field: Prudhoe Bay Unit Spud: 12/01/03 API: 50-029-22057-02 Release: 12/18/03 Permit: 203-168 Rig: Nabors 2ES PRE-RIG WORK 10/03/03 DRIFTED WI 2.18" CENT TO 10,942' WLM (STOPPED DUE TO DEV). PULLED GAS LIFT DESIGN FROM STA'S 1,3,4 & 5. SET 1 1/2' DGLV'S (RK) BACK IN STA'S 5 & 4. 10/04/03 SET DGLV @ STA. #38087' (SLM). LRS PUMPED 240 BBLS FLUID. UNABLE TO LOAD IA COMPLETELY DUE TO TBG, IA AND FLOWLINE PRESSURING UP. SET DGLV @ STA# 1 10,304' (SLM). PULLED C-SUB. 1 0/27/03 -"... ATTEMPT BULLHEAD KIk\::.";"T HT INJECTIVITY. RIH WITH 2.5" BDN TO 10410'. CIRCULATED KILL, WELL FLUID PACKED. PUMP 1 LS 15.8 PPG CEMENT PLUG, PLUG DID NOT HOLD. CLEAN OUT TO LINER - TOP AND POOH AT 80 o. ''RIH WITH SLIM HOLE BHA WI 1 3/4" BDN. TAG HARD AT 10,959' CTMD (-10935' MDBKB). APPEARS THAT 15' OF PERFS STILL OPEN. ' 10/28/03 ') CIRCULATE WELL AND ESTABLISH GOOD RETURNS (EST 70%). PUMPA()'ßB'LS - 15.8 PPG CLASS 'G' - CEMENT. LAY CEMENT IN LINER 1 FOR 1 FROM 10950' CTMD (10' ABO~:rAG) TAKING RETURNS AT MINIMUM WHP. EST. 5 BBLS CEMENT TO FORMATION. PULL TO SAFE AND HESITATE. BUMP WHP TO 200 PSIG - GOOD. BUMP WHP TO 500 PSIG - GOOD. EST TOTAL OF 6 BBLS TO FORMATION. REDUCE WHP AND RIH CONTAMINATING WI BIOZAN TO 10400' CTMD. POOH AT 80%. FP WELL TO 2500' WITH 60/40 METHANOL. LEFT WELL SHUT IN WITH 300 PSIG WHP. JOB COMPLETE. -- 11/21/03 CUT TUBING AT 10290' WITH 3 5/8" CHEMICAL CUTTER. STRING SHOT FIRED FROM 10279' TO 10292' AND 9 SHOT TUBING PUNCHER FROM 10250' TO 10252' FIRST. ALL RUNS CORRELATED TO TUBING TALLY SUMMARY. TAGGED BOTTOM AT 10360' ON ALL THREE RUNS. CIRC OUT TO FOLLOW. --.--' -",...-""_-......~tl_,,,,-I.t\lil DRIFT WI 3.705" CENT, SAMPLE BAILER TO CEMENT TOP @ 10361' SLM. PRESS TEST CEMENT TO 2000 PSI. 11/22/03 TIO=1760/700/350. CIRC OUT. SPEAR IN W/5 BBLS METH, PUMPED 1028 BBLS WATER, FOLLOWED BY 5 BBLS METH SPEAR, AND 150 BBLS DIESEL. CLOSED WING AND LET IAXT U- TUBE FOR 1 HOUR. CLOSE MASTER AND lA, OPEN WING AND FREEZE PROTECT FLOW LINE WITH 20 BBLS DIESEL, AND 2 BBLS METH. FINAL WHP=O/0/500. 11/23/03 T/I/O=400/400/320. CMIT TX IA 3500 PSI PASSED. (PREP FOR RWO). PRESSURED IA AND TBG TO 3500 PSI WITH 8 BBLS OF DIESEL. IA LOST 40 PSI TBG LOST 40 PSI IN FIRST 15 MINUTES. IA LOST 30 PSI, TBG LOST 50 PSI IN SECOND 15 MINUTES FOR A TOTAL OF IA 70 PSI AND TBG 90 PSI. BUMP IA AND TBG BACK UP TO 3500 PSI WITH .6 BBLS OF DIESEL. IA LOST 0 PSI, TBG LOST 0 PSI IN 15 MINUTES. IN SECOND 15 MINUTES IA LOST 0 PSI AND TBG LOST 0 PSI FOR A TOTAL OF 0 PSI IN 30 MINUTES. BLED IA AND TBG BACK TO 200 PSI. FINAL WHPS= 200/200/340. 11/24/03 T/I/O=240/160/340, TEMP=SI. BLEED WHP'S (PRE-RWO). TBG FL NEAR SURFACE. IA FL AT SURFACE. BLED TBG FROM 240 PSI TO 0 PSI IN 20 MINUTES, lAP WENT ON VAC DURING BLEED. MONITORED FOR 30 MINUTES WITH NO INCREASE. OA FL AT 60', BLED OA FROM 340 PSI TO 30 PSI IN 2 HOURS (GAS & 3 BBLS OF FLUID). FINAL WHP'S=0+/VAC/30. ( ( BP EXPLORATION Page 1 ~ Operations Summary Report . Legal Well Name: S-27 Common Well Name: S-27B Spud Date: 7/12/1990 Event Name: REENTER+COMPLETE Start: 11/24/2003 End: 12/18/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/18/2003 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/24/2003 22:30 - 00:00 1.50 MOB P PRE Rig Down Rig Floor And Can-Rig Top Drive - Load Up Truck Shop 11/25/2003 00:00 - 03:30 3.50 MOB P PRE Blow Down And Disconnect Utilities Between Pit Complex And Sub Base - Move Cuttings Tank - Lower Cattle Shoot - Lay Mast Over And Pull Sub Base Off Of Well - Have Pre-Job Safety Meeting With Security, CPS, And Rig Team 03:30 - 14:00 10.50 MOB P PRE Move Sub Base From DS 13-30A To J-Pad 14:00 - 21 :00 7.00 MOB N RREP PRE Problems With Columbia Moving System Trouble Shoot And Change Out Hydraulic Drive Motor 21:00 - 00:00 3.00 MOB P PRE Move Sub Base From J-Pad To S-Pad Having Trouble Getting Over Rig Mats 11/26/2003 00:00 - 08:00 8.00 MOB P PRE Move Sub Base From J-Pad To Kuparuk River - Use Cats Coming Out Of Base Of River And Continue To S-Pad 08:00 - 12:00 4.00 MOB P PRE Lay Herculite And Spot Sub Base Over Well S-27B And Level - Raise Mast And Cattle Shoot - Rig Up Rig Floor - Move Camp Unit And Pit Complex From DS 13-30A To S-Pad 12:00 - 16:30 4.50 RIGU P PRE Lay Herculite And Position Pit Complex - Hook Up Utilities And Service Lines From Sub Base To Pit Complex - Spot Truck Shop And Welding Shop -Bridal Down And Pick Up Can-Rig Top Drive - Set Cutting Tank And Berm *NOTE* Rig Accepted For Well Work On S-27B At 16:30 On 11-26-2003 16:30 - 17:00 0.50 WHSUR P DECaMP Hold Pre-Spud And Environmental Meeting With All Personal Regarding S-27B Well Operations 17:00 - 19:00 2.00 WHSUR P DECaMP Install Secondary Annulus Valve - Rig Up Circulating Lines And Test Same To 3,500 Psi. (Test Good) 19:00 - 20:00 1.00 WHSUR P DECaMP Attempt To Circulate String Pressured Up - Pressure Up And Shift Open Hydraulic Valve 20:00 - 00:00 4.00 WHSUR P DECaMP Pump Safe-Kleen Sweep And Circulate Out Freeze Protection To Cuttings Tank At 5 BPM With 930 Psi. - Tubing And Annulus Pressure At 0 Psi. 11/27/2003 00:00 - 00:15 0.25 WHSUR P DECaMP Blow Down Circulating Lines And Rig Down Hoses 00: 15 - 00:45 0.50 WHSUR P DECaMP Dry Rod In TWC And Test From Below To 1,000 Psi. (Test Good) 00:45 - 03:30 2.75 WHSUR P DECaMP Bleed SSSV Control Lines - Nipple Down Production Tree, Tubing Head Adapter And Remove From Cellar Area -Inspect And Verify 41/2" TDS Lifting Threads On Tubing Hanger In Good Condition 03:30 - 08:00 4.50 BOPSUR P DECaMP Nipple Up BOP And Related Equipment 08:00 - 08:30 0.50 BOPSUR P DECaMP Rig Up BOP Testing Equipment 08:30 - 15:00 6.50 BOPSUR P DECaMP Fill BOP Equipment With Water - Test BOP And Related Equipment Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test *NOTE* Two Failures During The BOP Test: Lower Pipe Ram Door Seal And Gland Packing Nut - The Door Seal And Packing Were Replaced And Tested Good 15:00 - 16:00 1.00 WHSUR P DECaMP Rig Down BOP Testing Equipment - Pull TWC With DSM - Printed: 12/22/2003 9:17:26 AM , (" ( BP EXPLORATION Page 2 .. Operations Summary Report Legal Well Name: S-27 Common Well Name: S-27B Spud Date: 7/12/1990 Event Name: REENTER+COMPLETE Start: 11/24/2003 End: 12/18/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/18/2003 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/27/2003 15:00 - 16:00 1.00 WHSUR P DECOMP Clear Rig Floor 16:00 - 16:30 0.50 PULL P DECOMP Rig Up Power Tongs, Control Line Spooler, Casing Tools And Equipment 16:30 - 17:30 1.00 PULL P DECOMP Pick Up Joint Of 4" Drill Pipe, And Cross Overs - Slack Off And Make Up Landing Joint To Tubing Hanger - Back Out Lock Down Studs - Clear Rig Floor And Pick Up On 4 1/2" Tubing String - Unseat Tubing Hanger From Profile - Maximum Up Weight Pulled 130,000 Ibs. - Normal Up Weight At 130,000 Ibs. - Work Tubing Hanger To Rig Floor Thru BOP Stack - Monitor Well Bore (Static) 17:30 - 18:30 1.00 PULL P DECOMP Set Slips And Terminate Control Lines Break Out And Lay Down Hanger - Install Full Opening Safety Valve - Break Out Cross Overs And Lay Down Landing Joint 18:30 - 20:45 2.25 PULL P DECOMP POH Laying Down 41/2" Completion String From Chemical Cut Joint At 10,290' To SSSV - Terminate Control Lines Break Out And Lay Down SSSV 20:45 - 21:15 0.50 PULL P DECOMP Rig Down Camco Control Line Spooling Unit And Clear Rig Floor 21:15 - 00:00 2.75 PULL P DECOMP POH Laying Down 4 1/2" Completion String From 8,150' To 4,223' 11/28/2003 00:00 - 03:30 3.50 PULL P DECOMP POH Laying Down 4 1/2" Completion String From 4,223' *NOTE* Items Recovered During Decompletion: 1 FMC Tubing Hanger And Pup 1 Flow Coupling & SSSV With Pup Joint Top And Bottom 2 Stainless Steel Bands 27 Rubber Clamps And Pins SHOULD HAVE BEEN 29 (2 CLAMPS AND PINS LEFT IN HOLE) 257 Joints Of 4 1/2" Tubing 4 GLM With Pup Joints Top And Bottom 1 Cut Off Joint 4 1/2" Tubing 30.10' Long 03:30 - 04:30 1.00 PULL P DECOMP Rig Down Tubing Tongs And Equipment - Clear And Clean Rig Floor 04:30 - 07:30 3.00 WHSUR P DECOMP Make Up 9 5/8" Pack Off Pulling Tool And Cross Overs To 4" Drill Pipe - Check 9 5/8" X 13 3/8" Casing - Pressure Gauge Showing 0 Psi. Back Out Gauge To Verify OA Static - Some Pressure On OA Install New Gauge Showing 50 Psi. - Rig Up Bleed Off Line To Cuttings Tank And Bleed Off Pressure - 23 Barrels Diesel And Dead Crude Flowed To Cuttings Tank - Monitor Back Side (Static) 07:30 - 10:00 2.50 WHSUR P DECOMP Slack Off And Engage Pack Off With Pulling Tool - Back Out Lock Down Studs And Pull Pack Off To Rig Floor - Install New Pack Off And Run In Lock Down Studs Torque To 450 ftllbs. 10:00 - 11 :00 1.00 WHSUR P DECOMP Rig Up And Test Pack Off To 5,000 Psi. (Test Good) - Rig Down Testing Equipment - Pick Up Cellar Area 11:00 -11:30 0.50 WHSUR P DECOMP Install Wear Bushing And Energize LDS 11 :30 - 13:00 1.50 STWHIP P WEXIT Rig Up Floor Area - Load Pipe Shed And Bring BHA No.1 To Floor 13:00 - 15:30 2.50 STWHIP P WEXIT Pick Up BHA NO.1 - Pick Up Dailey Drilling Jars Make Up Bumper Sub, Upper Mill, Lower Mill, And Starter Mill - RIH Make Up Float Sub, And Pick Up (9) Steel Drill Collars, (18) 5" Printed: 12/2212003 9:17:26 AM ( ,( BP EXPLORATION Page 3- Operations Summary Report Legal Well Name: S-27 Common Well Name: S-27B Spud Date: 7/12/1990 Event Name: REENTER+COMPLETE Start: 11/24/2003 End: 12/18/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/18/2003 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/28/2003 13:00 - 15:30 2.50 SìWHIP P WEXIT HWDP, And Cross Over To 886' 15:30 - 22:30 7.00 SìWHIP P WEXIT RIH With BHA NO.1 Picking Up 5" Drill Pipe From 886' To 6,604' 22:30 - 00:00 1.50 SìWHIP P WEXIT Change Out Handling Equipment For 4" Drill Pipe - Make Up Cross Over Sub And RIH With BHA NO.1 Picking Up 4" Drill Pipe From 6,606' To 8,009' 11/29/2003 00:00 - 01 :30 1.50 SìWHIP P WEXIT RIH With BHA No.1 Picking Up 4" Drill Pipe From 8,009' Tag Tubing Stub At 10,285' (DPM) 01 :30 - 03:30 2.00 SìWHIP P WEXIT Held PJSM With Truck Drivers I Drilling Crews, And Service Personal Regarding Mud Displacement - Pumped 30 Barrel Hi-Vis Spacer Followed Up With 11.2 PPG LSND Mud At 12.6 BPM With 860 Psi. 03:30 - 04:00 0.50 SìWHIP P WEXIT Monitor Well Bore (Static) - Pump Dry Job - Blow Down Surface Equipment 04:00 - 07:00 3.00 SìWHIP P WEXIT POH With BHA NO.1 From 10,285' To 886' 07:00 - 08:00 1.00 SìWHIP P WEXIT Handle BHA No.1 From 886' - Stand Back (18) Joints 5" HWDP, (9) Steel Drill Collars - Lay Down Daily Drilling Jars, Bumper Sub, Upper, Lower, And Starter Mill - Clear Rig Floor 08:00 - 13:30 5.50 SìWHIP P WEXIT Hold Pre-Job Safety Meeting - Rig Up Schlumberger Wire Line Services - Make Up Logging Tools - Logging Run No.1 RIH With CCL-CPST And Haliburton EZSV Packer To 10,285' Tag Tubing Stub - Log Up And Set Top Of EZSV At 9,996' WLM - - i-- Log Up 100 Feet - RIH Tag EZSV Confirm Setting Depth - POH With Logging Tools - Rig Down Schlumberger And Clear Rig Floor 13:30 - 14:30 1.00 EVAL P WEXIT Held PJSM - Test 9 5/8" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) 14:30 - 15:00 0.50 SìWHIP N RREP WEXIT Work On Iron Ruffneck 15:00 - 18:30 3.50 SìWHIP P WEXIT Pick Up BHA NO.2 - Pick Up 1 Joint 5" HWDP Make Up Upper Mill, Lower Mill, And Starter Mill - RIH Make Up Float Sub, MWD, And UBHO Sub - Install Pulser Orient And Surface Test - Pick Up Slide And Whipstock Trip Anchor Attach With 45,000 lb. Brass Lug Bolt - Pick Up Bumper Sub And RIH With (9) Steel Drill Collars, (18) 5" HWDP From Mast To 941' 18:30 - 22:15 3.75 SìWHIP P WEXIT RIH With BHA NO.2 Whipstock And Milling Assembly On 5" Drill Pipe From 941' To 6,660' 22:15 - 00:00 1.75 SìWHIP P WEXIT Change Out Handling Equipment For 4" DP - Install Cross Over And RIH With BHA NO.2 From 6,660' To 9,929' 11/30/2003 00:00 - 01 :00 1.00 SìWHIP P WEXIT Pick Up Single Of 4" Drill Pipe - Install Top Drive Blower Hose - Recorded Slow Pump Rates - String Weight Up 205,000#, String Weight Down 165,000# - Worked String To Orient Whipstock Slacked Off And Tripped Anchor With 32,000# - Tagged Bridge Plug With Bottom Of Whipstock At 9,997' Set - - At 6 Degrees Right Of High Side - Picked Up On String 10,000# Above Neutral Weight to Verify That Whipstock Set - Slacked Off 45,000# And Sheared Retaining Bolt. 01 :00 - 07:30 6.50 SìWHIP P WEXIT Milled Window in 9-5/8" Casing From 9,973' To 9,989' - Cement At Shakers While Milling At 9,983' - Exited Window At 9,989' And Continued To Mill Formation From 9,989' To 10,005' - String Weight Up 205,000#, String Weight Down 165,000#, String Rotating Weight 185,000#, Pump Rate 488 GPM, 2,132 Psi. RPM 80 To 100, Torque 10,000 ft I Ibs - 13,000 ftIlbs. Printed: 12/22/2003 9:17:26 AM . '. ( ( BP EXPLORATION Page 4t8Þ Operations Summary Report Legal Well Name: S-27 Common Well Name: S-27B Spud Date: 7/12/1990 Event Name: REENTER+COMPLETE Start: 11/24/2003 End: 12/18/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/18/2003 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task. Code NPT Phase Description of Operations 11/30/2003 01 :00 - 07:30 6.50 STWHIP P WEXIT Recovered 150 Ibs. Of Metal During Milling Operation 07:30 - 09:00 1.50 STWHIP P WEXIT Rotate And Reciprocate While Working Mills Thru Whipstock Window - Pump MIDF Super Sweep At 12.5 BPM EWith 2,300 Psi. 09:00 - 09:30 0.50 EVAL P LNR1 Pulled BHA Into Casing To 9,959' - Closed Upper Pipe Rams and Preformed FIT To 12.5 PPG EMW Strokes Pmp'd Pressure 5 190 psi 10 320 psi 15 450 psi 20 570 psi 23 630 psi Held Test F/1 0 minutes wI 50 psi Pressure Loss. MW 11.1 ppg, WindowTVD 8,265' Pressure 630 psi = 12.57 PPG. EMW. Bled Pressure To 0 Psi. - Opened Pipe Rams Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 09:30 - 10:30 1.00 DRILL P LNR1 POH With BHA NO.2 From 9,959' To 6,726' 10:30 - 11 :30 1.00 DRILL P LNR1 Slip And Cut 102 Feet Of 1 1/4" Drilling Line 11 :30 - 12:00 0.50 DRILL P LNR1 Service Top Drive, And Traveling Blocks 12:00 -14:15 2.25 DRILL P LNR1 POH With BHA NO.2 From 6,726' To 916' 14:15 - 16:00 1.75 DRILL P LNR1 Handle BHA NO.2 From 916' - Stand Back (18) Joints 5" HWDP, (9) Steel Drill Collars - Lay Down Bumper Sub, UBHO Sub I MWD Tools, Float Sub, (1) Joint 5" HWDP, Upper, Lower, And Starter Mill - Clear Rig Floor - Inspect And Gauge Upper String Mill At 8.5" 0.0. 16:00 - 17:00 1.00 BOPSUR P LNR1 Remove Wear Bushing - Pick Up Johnny Wacker And Flush Out BOP Stack - Lay Down Flushing Tool - Install Wear Bushing And Energize Lock Down Studs 17:00 - 18:00 1.00 DRILL N RREP LNR1 Rig Repair - Trouble Shoot And Repair Lay Down Machine Camera Monitor 18:00 - 20:30 2.50 DRILL P LNR1 Make Up BHA NO.3 - Pick Up Sperry Sun Motor, Make Up 8 1/2" Hughes HCM 605 PDC Bit - Pick Up MWD/LWD Tools, String Stabilizer, Float Sub - Orient And Initialize MWD/LWD Tools - Pick Up (3) Flex Drill Collars - Surface Test Sperry Sun Equipment - RIH With (9) Steel Drill Collars, (12) Joints 5" HWDP - Pick Up Daily Hydraulic Jars, (11) Joints 5" HWDP To 1,171' 20:30 - 00:00 3.50 DRILL P LNR1 RIH With BHA No.3 Directional Assembly On 5" Drill Pipe From 1,171' To 6,890' - Change Out Handling Equipment For 4" DP - Install Cross Over And RIH From 6,890' To 8,106' 12/1/2003 00:00 - 01 :00 1.00 DRILL P LNR1 RIH With BHA NO.3 Directional Assembly On 4" Drill Pipe From 8,106' To 9,785' -Install Top Drive Blower Hose 01 :00 - 01 :45 0.75 DRILL P LNR1 Orient Tool Face To 6 Degrees Right Of High Side, Shut Down Mud Pumps - Madd Pass Log For Tie In At 300' Per Hour From 9,785' To 9,993' - Slide Thru Whipstock Window 9,973' To 9,989' With No Problems 01:45 - 02:00 0.25 DRILL P LNR1 Ream Out Under Gage Hole From 9,993' To 10,005' Ul:UU - 1 :>:UU l;:S.uU DKILL P LNR1 Drilled 8 1/2" Directional Hole Bv "",:"':,'~ rlvm ~ ^ U -. LV v,, ~ I VVUtS Rotating 5,000# - 20,000#, WOB Printed: 12/22/2003 9:17:26AM STATE OF ALASKA ALASKA ,~_ AND GAS CONSERVATION CO~,,,,iSSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: [] Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance [] Other [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate [] Time Extension [] Change Approved Program [] Pull Tubin.q [] Perforate New Pool ~ Re-Enter Suspended Well ~ Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. [] Development [] Exploratory 195-100 /'' 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22057-01-00 7. KB Elevation (ft): KBE = 64.47' 9. Well Name and Number: PBU S-27A ~r 8. Property Designation: 10. Field / Pool(s): ADL 028260 Prudhoe Bay Field / Prudhoe Bay Pool 11'i ~ ;i; ,.=: i,':. i..,:, :..::: i.: ..::;:"~,: ::PRESENTWEI. LCONDtTION sUMMARY..:~:.: i':':. "T°tal Depth MD (ft): Total Depth'TVD (ft):/Effective Depth MD (ft)': IEffeCtive 'Depth TVD'(ft): 'PIugs (meaSUred):' Junk (measured): 11315 8923I 11220I 8917 11220 N/A Casin~l Len~lth Size M D TVD Burst Cella pse $.tr~lctural ~ F"'r~ I'"""- ~i t#~ ~ 69ndw~er 110' 20" 110' 110' ~ C::t.,,~_ 11 $~rfeq, e 2689' 13-3/8" 2689' 2689' Intermediate 10635' 9-5/8" 10635' 8745' FIF"F r~ / ~ ~n ~ ..Production ~'~" ~ ~''')~ ~ l~in~r 286' 7" 10363"- 10649' 8548' - 8755' 7240 5410 Liner 810' 2-7/8" 10410' - 11220' 8582' - 8917' ~,it~8 ~l e ~au ~;~h~ , ............. Perforation Depth MD (ft): I Perforation Depth 'I'VD (ft):I Tubing Size: Tubing Grade: I Tubing MD (ft,: 10920' - 11140' 8897' - 8912' 4-1/2", 12.6# L-80 10434' Packers and SSSV Type: 9-5/8" Baker 'SB-3' packer; Packers and SSSV MD (ft): 10350' 4-1/2" Otis SSSV Nipple 2122' 12. Attachments: 13. Well Class after proposed work: [] Description Summary of Proposal [] BOP Sketch [] Detailed Operations Program [] Exploratory [] Development [] Service 14. Estimated Date for ,.,,.~. 15. Well Status after proposed work: Commencing Operations: October 9, 2003 [] Oil [] Gas [] Plugged [] Abandoned 16. Verbal Approval: Date: [] WAG [] GINJ [] WINJ [] WDSPL Commission, Rcpres. en!~ti~e:, , i'7. i hereby certify that the foregoing i's true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name Bill Isaacson Title Senior Drilling Engineer ~'~, i ~ / 6/ Prepared By Name/Number: Si~lnature . . ~. ~ Phone 564-5521 Date JO 6 O~ Terrie Hubble, 564-4628 "· ' '"'. '" .' '.": "' ' :'. '~'"' '" c°mmiS..s.i°nuseOnlY; ..'" : .. ." '.'.' ' i.:. ' ' " Sundry N;mber:~. Conditions of approval: Notify Commission so that a representative may witness [] Plug Integrity [] BOP Test [] Mechanical Integrity Test [] Location Clearance Other: 'T'~%"[- '~0 i;)~' ~ 7~'C~C~ ~¢%('., Subsequent form required 10- ~ C~''~ ,,,,Approved By: . -, COMMISSIONER THE COMMISSION D Form 10-403 Revised 2/2003 / ~'[ ~,,~ ~,~,~ ,Duplicate 0 bp To: From: Subject: Winton Aubert - AOGCC Date: October 6, 2003 Phil Smith - BPXA GPB Rotary Drilling S-27A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well S-27A. Currently the well is shut-in, and offers no value due to its lack of annular integrity. A sidetrack / tubing change is seen as the most viable option to restore wellbore integrity, access additional reserves, and maximize value. The S-27B sidetrack is currently scheduled for Nabors 2ES beginning around 11/10/03, after completing the Y-23B sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Scope Pre-Riq Operations: 1. Rig up slick line, remove the 4 Y2" SSSV from the landing nipple at 2122' MD if in-place. Drift the 4 Y2" tubing and 2 7/8" liner to deepest hole angle will allow (hole angle reaches 70° _+300' from the IBP set at 11,220'). 2. Replace all live GLVs with dummy GLVs 3. Shoot fluid levels in the IA and OA and load each with diesel. The last OA fluid level in December was at 240' (14 bbls volume). If IA fluid level is deeper than 2100', load first with seawater to 2100'. Pressure test the IA to 3000 psi for 30 minutes. Monitor tubing and OA pressures during the test. 4. Function tubing hanger and casing lock-down screws. Remove one 9 5/8" packoff LDS and flush out any plastic packing in the void. Retest packoff. If no plastic packing is found in the pack-off DO NOT inject new packing. Re-test the IA to 3000 if the pack-off passes the pressure test. 5. RIH with coiled tubing cement nozzle to top of 2 7/8" liner/ef-1'0,410'. Ensure the tubing is fluid packed to surface. From the CTN, bullhead two liner volumes ('[0~¢Sbls) out of the coil. Hesitate squeeze away up to five bbls to leave top of cement at the top of 2<7-./8'' liner or lay excess cement in the 4 tubing to no higher than 10,350' (dress-off if necessary). 6. RIH with Schlumberger string shot and chemical cutter for 4 Y~" tubing. Cut the 4 Y~" at 10,300 (+_20') to avoid cutting a tubing collar. 7. Circulate to seawater & freeze protect to 2100' w/diesel. Bleed well pressures to zero. 8. Set a BPV. Remove wellhouse and flow lines. Complete handover to 2ES noting the rig prep details and total costs accrued against the AFE. Ri.q Operations: 1. MIRU Nabors2ES 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. 4. Pull 4 Y~" tubing from the cut. S-27A Application for Sundry 5. M/U 8 Y2" milling BHA. RIH and drift down to the remaining tubing stump. Change the well over to 11.2 ppg LSND milling/drilling fluid. 6. RIH with 9-5/8" bridge plug on wireline and set at 10,030 MD. Test 9-5/8" casing back to surface to verify integrity. 7. Replace and test the 9 5/8" mandrel hanger packoff to 5000 psi. 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Mill window in 9-5/8", 47# casing at 10,000' MD. Drill 20' past middle of window. Perform FIT to 12.5 ppg EMW. POOH 10. MU 8-1/2" drilling assembly with Dir/GR and RIH. Kick off and drill the 8-1/2" intermediate interval to top Sag River at an estimated depth of 10,775' MD. Drop ESS, POH. 11. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 9,850' MD. Displace cement with mud. POOH. 12. MU 6-1/8" BHA with Dir/GR/Res/ABI and RIH. 13. Drill the shoe tract and swap the well over to 8.4 ppg Drill-In fluid. Drill 20' new formation and perform FIT to 10.0 ppg. 14. Drill the 6-1/8" production interval building at 10°/100' to horizontal, targeting Z4A/B Ivishak. 15. Pick up PDC, drill ahead to an estimated TD of 16,445' MD. 16. Run and cement a 4 Y2", 12.6#, L-80 production liner. POOH. 17. Test the 9 5/8" X 7" X 4 Y2" liner to 3,500psi for 30 minutes. 18. R/U and RIH with Schlumberger DPC perforating guns. Perforate +1000' at hydrostatic overbalance. Circulate well to seawater, POOH. 19. Run a 4 1/2" x 3 Y2" 13-Cr completion, locating into the 4 W' liner top. 20. Set the 7" production packer, test the tubing and annulus to 3,500psi for 30 minutes. 21. Nipple down the BOPE. Nipple up and test the tree to 5,000psi. 22. Freeze protect the well to ~2,100' and secure the well. 23. Rig down and move off. Post-Rig Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-rig Start Date: Estimated Spud Date: Phil Smith Operations Drilling Engineer 564-4897 10/15/03 11/10/03 S-27A Application for Sundry WELLHEAD = FMC ;~;4~(~i~'';' ................................. ELEV = 56.04' ELEV = 28.36' (OP = 3182' Angle= 90@ 11023' ~tum MD = 10838' TVD = 8800' SS S-27A I( ' ~,FETY NOTES: 3" FLOWLINE IN SKID PORTIONS .' THIS WELL'S FLOWLINE ARE 3" AND SUBJUCT - 70° @ 10887' AND 90° @ 11023' 2122' H4-1/2,, OTIS SSSV NIP, ID = 3.813" 13-3/8" CSG, 68#, NT-80, ID = 12.415" I'--[ 2689' IMinimum ID = 2.372" @ 10410' TOP OF 2-7~8" LNR GAS LIFT MANDRELS I TOP OF 7" LNR I-'[ 10363' I TOP OF 2-7/8" LNR I'--~ 10410' 10434' 10635' WHIPSTOCK I--~ 10644' 10338' 10349' 10350' 10402' 10423' 10434' I 10448' I--{4-1/2" PARKER SWS NIP, ID= 3.813" I--I BAKER TBG ANCHOR I--~ 9-5/8" BARKER SB-3 PKR, ID = 3.99" I----~4-1/2" PARKER SWS NIP, ID= 3.813" I--']4-1/2" PARKER SWS NIP, ID= 3.813" I--~ 4-1/2" W/LEG I I--~ELMDT'FLOGGED 11/17/95 I MILLOUT WINDOW 10649' - 10655' 7" LNR, 29#, L-80, TC-4S, 0.0371 bpf, ID=6.184" I--~ 11635' PERFORATION SUMMARY REF LOG: ATLAS BHCS ON 07/26/90 ANGLEATTOP PERF: 74 @ 10920' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10920- 11140 O 11/95 11315' Ho, l 12-7/8" LNR, 6.16#, FL4S, .00579 bpf, ID: 2.372" ]--~ 11220' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/11/90 ORIGINAL COMPLETION 11/20/95 PAB SIDETRACK COMPLETION 03/14/01 SIS-MH CONVERTED TO CANVAS 03/02/02 RN/TP CORRECTIONS PRUDHOE BAY UNIT WELL: S-27A PERMIT No: 195-1000 APl No: 50-029-22057-01 SEC 35, T12N, T12E BP Exploration (Alas ka) S-27B roposed Complc ..on (wp06) 13-3/8", 68#, NT-80 ~1 4-1/2" x 3 1/2", 13Cr80, VAM ACE II 3000 'MD TREE= 4" CIW WF1 LHEAD = FMC ACTUATOR = OTiS -BFq' '~-~'; ............................... 28.36' KOP = 3182' ~tum ~ = 10838' 9850' 9-5/8" X 7" Liner Hanger and ZXP Liner Top Packer 10000' ~.: ...... KOP 10,000 10030' 10350' 10363' 10410' 10434' 10635' 9-5/8", 47#, NT80S 7" X 4-1/2" Premier Permanent Packer @ 10,550' 7" X 4-1/2" HMC Liner Hanger with ZXP Liner Top Packer andTBR @ 10600' 7", 26#, L-80, BTC-M @ 10,775' 4-1/2", 12.6#, L-80, IBT-M @ 16,445' 7", 29#, L-80 @ 11,635' 2-7/8", 6.16# Liner @ 11,220' Date Rev By Comments PRUDHOE BAY UNIT 9/2/03 PGS Proposed Completion Design WELL: S-27B APl NO: Permit NO: . ..... GPB Rotary Drilling BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date: July 30, 1996 AttentiOn· Steve McMaines Subject: S-27A Directional Data A Coiled Tubing sidetrack well S-27A was drilled and a Well Completion Report (form 10 -407) was filed 12/07/95. Survey data submitted with that report was in error. Enclosed is a revised Well Completion Report with a corrected bottom hole location and the corrected survey. Please note that this is a Drilex surveyed well, and not one of the Anadrill wells we discussed. If there are any questions please contact me at 564-5894. Thank you. Sincerely, Theresa Mills Coiled Tubing Technical Assistant STATE OF ALASKA ALASK/ .... ILAND GAS CONSERVATION CC 'VIISSION COMPLETION OR RECOMP LETION I'iEPORT AND LOG ,. Status of Well Classification of Service Well OIL [] GAS [] SUSPEI~)ED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number . BP Exp/oration 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50.029-22057 4. Location of well at surface 9. Unit or Lease Name '?t.c~¢~ !' '~"~'~ Prudhoe Bay Unit 1633' SNL, 4048' WEL, SEC. 35, T12N, R12E ' """"'-"r~/*""4~ i lO. Well Number At Top Producing Interval '. ~[~ t~.~.~1~..~ · S-27A 1108' SNL, 292' WEL, SEC. 3, T11N, R12E At Total Depth~~ ... ~~ 11.PrudhoeField andBayPOOIFie/d/Prudhoe Bay Pool 1563' SNL, 5216' WEL, Sec. 2, T11N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE= 64.47' ADL 28260 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/11/95 11/12/95 11/22/95I N/A feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11315'MD (8858'ss) 11140'MD (8847'ss) YES [] r,x:) []I 2122 feet MD 1900' (approx.) 22. Type Electric or Other Logs Run Gamma Ray 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Surface 11 O' 13 3/8" 68t/ NT8OCYHE Surface 2689' 17 1/2" 3296 cu ft Arctic Set III & II 9 5/8" 471/ NT80 Surface 10635 12 1/4" 2393 cuft Class G 7" 261/ L-80 10363' 11250 8 1/2" 280 cuft Premium G 2 7/8" 6.161/ FL4S 10410' 11220' 3 3/4" 39 cuft Class G 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11140'-110920'MD (22Oft, 4 SPF) 8849'-8835'TVD 4 1/2" 12.6# 10448 10350 L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13 3/8"X 9 5/8" annulus Downsqueeze with 125 bbls dry crude 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 11/22/95 I gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ct oil, gas or water. Submit core chips. O IGI[xIALR[cF- V D Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS~ ..... ':~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,= Sag 10646 6668 ss Shublik 10701 6725 ss Zone 4 10923 8831ss 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~~~ ~'~ Title CTD TechnicalAssistant Date 7/$0/96 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". Form 10-407 TREE: WELLHEAD: ACTUATOR: 4" CIW S-27A OTIS Completion KB. ELEV = 56.04' BF. ELEV = 28.36' CMT'd 13 3/8", 68#/ft, I I~ NT-8OCYHE, BTRS 2689' I KOP: 2800' MAX ANGLE: 47°/8800' 4 1/2", 12.6#/ft, L-80, TDS I NON-IPC TUBING I :TUBING ID: 3.958' I CAPACITY: 0.0152 BBL/FTI._. 4 1/2", 12.6 #Iff, L-80 TAILPIPE TOP OF 2 7~8" LINER 10,410' 9 5/8", 47#/ft, NT-80S, NSCC I10,635' PERFORATION SUMMARY REF LOG: RADIUS GAMMA RAY SIZE SPF INTERVAL OPEN/SQZ'D 2" 4 10920- 11140 OPEN 11/22/95 MARKER JOINT I 10,775' 7" OTIS WD PACKER 4 1/2" "X" NIPPLE (OTIS) (3.813" ID ) 4 1/2" "XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" WLEG (PARKER) (3.86" ID) (ELMD) XXN PLUG w/SCALE CAP. TD @ 10,972', ELMD, ON 10-31-91. PBTD I 11,1 7", 26 #/ft, L-80, rc4s I 11,250'1 r11.o11,1 TOC SSSV LANDING NIPPLE (OTIS)(3.813"ID) I 2122' I GAS LIFT MANDRELS fCl MCO w/1-1/? RK LATCH) N°- MD(BKB) TVDss DEV. 5 3163' 3104' 8° 4 5659' 5142' 45° 3 8089' 6865' 43° 2 10,047' 8263' 43° 1 10,309' 8454' 44° 41/2' "SWS"NIPPLE I I (PARKER) (3.813' ID) 10,338' BAKER TUBING I 10,349'1 ANCHOR 9 5/8" BAKER PACKER 110,350'1 (SB-3) (3.99' ID) TOP OF TIW 7" LINER I 10,363' I 4 1/2" "SW~5' NIPPLE (PARKER) (3.813' ID) -- 4 1/2" 'SWS' NIPPLE (PARKER) (3.813" ID) 4 1/2' PARKER WLEG 2 7/8" FL4S Liner Top of Liner Cement [ 10,423'1 1,10,434'1 ELMDI 10,448'1 SHUBLIK SADLEROCHIT Daily Operations Well: S-27A Accept: 10/12/95 Field: Prudhoe Bay Spud: 10/14/95 APl: 50-029-22057-01 Release: 11/13/95 Permit: 95-100 CTD Unit: 4985 / 4905 07/12/95 RIH WITH 3.50" X20' DRIFT & TEL. EOT @ 10,406WLM, TD @ 10,875 WLM (CORRECTED TD = 10,917' MD). POH. RAN 30 ARM KINLEYCALIPER FROM 10,886 TO EOT. POH. GOOD SURVEY. RD. 07/21/95 BULLHEAD KILLED WELL WITH 275 BBLS FSW. HAD HYDRAULICS PROBLEMS WITH INJECTOR HEAD WHILE RIH. HYDRAULICS CAME BACK. POOH. MECHANICS WORKED ON HYDRAULICS AND RETURNED TO - SERVICE. RIH AND LOST HYDRAULICS. RECOVERED HYDRAULICS. POOH. RDMO AND RETURN TO SHOP. O7/24/95 RU CAMCO 4932. RIH AND TAGGED TD AT 10,917'. ClRC 246 BBLS FILTERED SEAWATER TO COOL WELLBORE. LAYED 7 BBLS CEMENT FROM 10907 - 10724'. PUH AND CIRC AT 0.5 BPM TO OPEN TOP TANK, GOOD RETURNS. POH KEEPING HOLE FULL. O7/25/95 RU WIRELINE AND TAGGED TD AT 10,882' CORRECTED WLMD. WELL DRANK ALL CEMENT. LAYED 2670 LB. OF 20/40 CARBOLITE FROM 10,882 - 10,787' (630 LBS BEHIND PIPE). SQUEEZED SAG R PERFS WITH 7 BBLS CEMENT TO A FINAL PRESSURE OF 1500 PSI. LRO CEMENT TO 10,720' CTD. 07/26/95 TAGGED TD (TOP OF CEMENT) AT 10,709. UNDERREAMED TO 10,719 CTD AND PUH TO LOCATE TUBING TAIL. UNABLE TO LOCATE TUBING TAIL. UNDERREAM ACROSS 10,600 - 10,719' AND CLEANED THE HOLE WITH A BIOZAN SWEEP. POOH CHASING OUT THE BIOZAN. 07/27/95 RU CAMCO 4932. TAG TD AND LOCATE TUBING TAIL. CORRECTED TD IS 10,735'. RIH REAMING DOWN AND TAG HARD BOTTOM @ 10,726' CTD. UNDERREAM HARD CEMENT TO 10,728'. UNDERREAM AND BACK REAM OVER THE INTERVAL 10,600 - 10727' CTD 3 TIMES. CIRCULATE HOLE CLEAN WILTH 20 BBLS BIOZAN SWEEP. OPEN CIRC SUB AND POOH CHASING BIOZAN TO SURFACE. RIH WITH DRILEX 2-7/8" MOTOR WITH A 2° BENT HOUSING AND DRIFTED THROUGH THE TUBING TAIL. FREEZE PROTECTED THE TUBING TO 2000' WITH DILUTE METHONAL. O7/28/95 SET WHIPSTOCK VIA E-LINE. TOP OF WHIPSTOCK SET AT 10,666' MD. WHIPSTOCK IS ORIENTED 7 DEGREES "LEFT" OF HIGH SIDE. RA TAG IS AT 10,675'. (NOTE: PINS WERE NOT PULLED FROM WHIPSTOCK CAUSING SET TO BE INCOMPLETE) 07/29/95 SET WHIPSTOCK #2 W/TOP @ 10,644', RA TAG @ 10,653 AND ORIENTATION 12°LEFT. 07/29/95 RU CTU. IN HOLE. ATTEMPT TO MILL WINDOW. FLEX JOINT TWISTED OFF LEAVING FLEX JOINT AND BIT O7/3O/95 RU SLICKLINE AND ATTEMPT TO FISH FLEX JOINT. UNSUCCESSFUL. 7/31/95 FREEZE PROTECTED WELL WITH 21 BBLS MEOH. 08/O 1/95 RU SLICKLINE AND RECOVERED FLEX JOINT AND BIT. 08/06/95 RAN BULLNOSE MILL & 2-7/8 MTR. DIFFICULT LOCATING W TEL. TAGGED BTM @ 10651 CORR DEPTH. MILLED DOWN TO 10660 FAIRLY QUICKLY. STALLED SEVERAL TIMES @ 10660. DECIDE TO TRIP & CHECK MILL. FLAGGED COIL ON WAY OUT. MILL WEAR LOOKS NORMAL- CONCAVE CENTER DEEPENED 1". LAYED DOWN TEL. PICKED UP ClRC SUB FOR FINAL CLEANOUT. PICKED UP 3.81 TAPERED MILL AND STRING MILL. GOT TO FLAG- CORRECTED +25 FT TO GET TO FLAG DEPTH. COIL STILL RUNNING WAY SHALLOW. TAGGED @ 10652. MILLED AND REAMED EASILY DOWN TO 1O664.5' PICK UP DEPTH. WORK STRING REAMER THRU WINDOW. SMOOTH WORKING THRU WINDOW, OPEN HOLE STAYING CLEAN. PUMP BIO-ZAN SWEEP TO CLEAN HOLE, DISPLACE W/EFFLUENT WATER TO PREPARE FOR CAMERA. OOH, SMOOTH WEAR PATTERN ON MILL AND REAMER. REAMER HAD INDICATION OF WORKING ON METAL ON TOP AND BOTTOM TAPER OF CUTRITE BLADES. O8/O8/95 RU HALLIBURTON AND RAN VIDEO CAMERA TO INSPECT WHIPSTOCK. ALL OK. O8/O8/95 FREEZE PROTECTED TUBING WITH 37 BBLS MEOH. O8/21-23/95 FINISH RU OF TOWER ELEC. AND HYD. PU LUBRICATOR. BRING DWN COIL. CHECK OUT UMB. OK. PLUG IN REEL BAD. MAKE UP NEW PLUG IN. MADE UP EXTERNAL CONNECTOR. WORKED ON CONTROL SKID- ELECTRICAL PROBLEM-WON'T FIRE UP. PERFORM FULL BOP TEST. TREE VALVES LEAKING. TEST ORIENTER OK, RIH WITH MOTOR. TAG TD, TEST ORIENTER - OK, PUMP 58 BBL HIGH VIS SWEEP, START DRILLING WITH FLOPRO, TAKE SURVEY EVERY 15 FT. O8/24/95 DRLG, BUILDING HOLE ANGLE, GR NOT WORKING, UNABLE TO ORIENT AND STEERING TOOL SHORTED OUT, POOH, LAYOUT AND REPAIR RADIUS STEERING TOOL, CHANGE-OUT MOTOR TO 1.60 DEG BENT MOTOR, STILL UNABLE TO ORIENT, LAYOUT BHA IN TRAILER, TEST BHA, SECURE LOCATION AND HAUL BHA TO CAMCO SHOP FOR REPAIRS. O8/25/95 WO ARRIVAL OF CAMCO ENGINEER FROM HOUSTON SO AS TO COMMENCE TOOL REPAIRS. 08/26/95 MU CT CONNECTOR AND PULL TEST TO 60K#. CHECKED INJECTOR, OK. MU UPPER CONNECTOR. ISOLATED ORIENTER FAILURE TO BAD SOLENOID. REPLACED SOLENOID AND REDRESSED BH/~ O8/27/95 MU BHA. TESTED ORIENTER ON SURFACE. FLUID TEMP AT 40°, AND IT TOOK 2 HOURS FOR PRESSURE TO GET TO THE ORIENTER! RIH. BHA SHORTED OUT AT 9500'. POOH. THE SHORT IS IN THE CAMCO BHA (DISCONNECT). THE CT CONNECTOR IS ALSO SHOWING DAMAGED WIRES. SEND BHA BACK TO SHOP FOR REPAIRS. O8/28/95 MU CT CONNECTOR. PULL TESTED TO 50K#. MU UPPER CONNECTOR. CONTINUE BHA REPAIRS (SHORT IN DISCONNECT). FUNCTION TESTED TOOL. ORIENTER SOLENOID FAILED AGAIN. REPLACED SAME. FUNCTION TESTED ORIENTER OK. M/U CAMCO AND RADIUS BHA. TEST ORIENTER THROUGH CT - OK, PRESS TEST LUBRICATOR, RIH WITH DRILLING BHA. 08/29/95 TAG TD, ATTEMPT TO LOG GR, HAD DEAD SHORT AFTER SWITCHING TO LOG GR, DEAD SHORT IS DOWNHOLE, POOH TO LOCATE SHORT, COULD NOT LOCATE SHORT IN EITHER RADIUS OR CAMCO BHA. NO WATER IN CONNECTION. MU BHA. SURFACE TEST GOOD. RIH. TOOL SHORTED AGAIN AT 8300' WHEN SWITCHING FROM STEERING TO GR. ATTEMPT TO OPEN CIRC VALVE, CIRC VALVE NOT WORKING EITHER, BUT GETTING STEERING INFO AGAIN, CORRECT TO MD OF 10727 FT BKB, LOG DIR SURVEWS UP THROUGH WHIPSTOCK, LOOSE STEERING INFOWHEN INC. PUMP PRESS, RECOVER FLOPRO FROM WELL, CIRC IN FSW AND FREEZE PROTECT TUBING AND CT WITH MEOH, REPAIR 2 BURNED OUT CIRCUIT BOARDS IN CONTROL SKID, DETERMINE THAT CAMCO BHA HAS A SHORT ON RADIUS WIRE AND THAT WE ONLY HAVE 2 GOOD WIRES THROUGH UPPER CONNECTOR AND UMBILICAL. O8/3O/95 SEND CAMCO BHATO DEADHORSE FOR CHECK AND REPAIRS. CUT OFF CT CONNECTOR. MEGOHM WIRES IN UMBILICAL. APPEAR TO HAVE FOUR GOOD WIRES IN UMBILICAL. RE-INSTALL CT CONNECTOR AND PULL TEST TO 50,000¢. TROUBLESHOOT CAMCO BHA. FOUND SHORT IN UPPER CONNECTOR AND IN SLIP RING CONNECTOR. SEALS ON ORIENTER PISTON LEAKING AND BACK-UP RINGS WORN. DECIDE TO SUSPEND OPERATIONS UNTIL ARRIVAL OF BACK-UP 2 7/8" TOOLS FROM HOUSTON. 08/31/95 PURGE METHANOL FROM CT W/N2. INSTALL BOOM SECTION IN CRANE. RD BJ AND MI SOLIDS VAN. RD SQUEEZE UNIT. HAUL OFF ALL FLUIDS. SET INJECTOR HEAD OFF. RD TOP TOWER SECTIONS. LEAVE SUB- STRUCTURE AND DO'II'OM TOWER SECTION RIGGED UP. UNSTAB CT AND LEAVE INJECTOR HEAD ON LOCATION. HAUL CT UNIT TO CAMCO/DEADHORSE. Date Day Depth 10/10/95 1 10727 COMMENCE RU. WINDS ARE 15 - 25 MPH, GUSTING TO 35 MPH. RU SUB STRUCTURE AND TOWER SECTIONS 1 AND 2. WINDS TOO HIGH TO LIFT INJECTOR HEAD. SPOT TRAILERS. RU SQUEEZE UNIT. 10/12/95 2 10727 CONTINUE WITH RIG UP, PICK UP TOWER SECTION NO. 3 [16 FI'I, PICK UP INJECTOR HEAD, MU GUY WIRES, MU LUBRICATOR SECTIONS. MU CT CONNECTOR. PULL TEST TO 45K#. WEIGHT INDICATOR NOT WORKING. HOLD SAFETY MEETING. PERFORM FULL BOP TEST. MU CAMCO BHA. 10/13/95 3 10725 CONTINUE TO MU CAMCO BHA. PICK-UP BHA INTO LUBRICATOR, PICK-UP EXPANSION JOINT, INSTALL HEAT SOCK AND TARP WIND WALLS, PURGE BJS PUMPS AND LINES, FILL CT, PURGE CT, PRESS TEST CAMCO BHA, PICK UP MOTOR, RIH WITH DRILLING BHA. (COMPLEXER NOT WORKING). MOVE BJ DUE TO DOYON RIG PROXIMITY. BLEED IATO 850. TROUBLE SHOOT ENCODER. RAN GR TIE IN LOG. TAGGED BOTTOM AT 10725'. TOOL FACE ON BOTTOM IS 100°L, TOO FAR LEFT. MAJOR DOGLEG ON BOTTOM. REAM W/FSW, TOOL FACE ON HS. RETURNS GASSY AND WIND DIRECTION WRONG. TAKING RETURNS DOWN THE FLOWLINE. STEERING TOOL SHORTED OUT. ALSO HAD PROBLEMS ORIENTING TO THE RIGHT OF HS. POOH. RETURNS CLEANED UP, NO GAS. RADIUS TOOL OK. ORIENTER NOT WORKING. RADIUS WIRE SHOWING A SHORT. LD CAMCO BHA. 10/14/95 4 10770 LD CAMCO BHA. M/U CAMCO BHA #2, OK, RIH. RAN GR TIE-IN AND TAGGED FACE AT 90°R. DRILLED TO 10735' W/ LOOKS OK. HOLE IN GOOD CONDITION. TEST OK, RIH WITH DRILLING BHA, TEST ORIENTOR AT 4000 FT, BOTTOM AT 10725'. REAMED FROM WINDOW TO TD WITH TOOL 45°R TF. SURVEY SHOT ON BOTTOM SHOWED 163° AZIMUTH. CHANGED OVER TO FLO-PRO. LOSING RETURNS. DRILLED TO 10749', 10°R TF. LOSING APPROX 25% RETURNS. DEPTH INDICATOR NOT WORKING. TROUBLE SHOOT SAME. RUN GR, CORRECTED TD IS 10751'. WO MORE MUD. DRILL TO 10770', 10°L TF. USING MECHANICAL COUNTER. LOSSES ARE IMPROVING. BUILD RATE LOOKING GOOD. 10/15/95 5 10878 CONTINUE DRILLING BUILD SECTION AT 15'/HR. LOSING APPROX 5% RETURNS, 10 BBLS/HR. LOST RADIUS DIRECTIONAL TOOL AT 10878 FT, LOG GR, POOH TO CHANGE OUT MONEL (BAD ACCEL.). SWIVEL BAD ON SECOND MONEL. INSTALL SWIVEL FROM MONEL #1 INTO MONEL #2. GR IN MONEL #2 NOT WORKING. CHANGE OUT SAME. NO WORKING SPARE MONELS CURRENTLY AVAILABLE. CHANGE OUT DAMAGED KEMLON CONNECTOR. RIH W/BHA #3 (1.5° MOTOR). 10/16/95 6 10940 RIH W/BHA #3 (1.5° MOTOR). TIED IN W/GR. LEDGE ENCOUNTERED AT APPROX 10800' WHEN WASHING TO BOTTOM. DRILLED 34 FT WITH ALL TOOLS WORKING, LOST RADIUS DIRECTIONAL INFO. AT 10904 FT, DRILLED BLIND TO 10927 FT, LOGGED GR UP TO WINDOW, POOH, REPAIR RADIUS TOOL [HAD A LOOSE GROUND WIRE], M/U RADIUS MONEL AND 1.62 DEG MOTOR, RIH WITH DRILLING BHA #4. MUD IS DILUTED TO 12000 LSRV. CHANGED OVER TO NEW MUD. TIED IN W/GR. ENCOUNTERED SMALL LEDGE AT 10801'. DRESSED OFF. TAGGED AT 10932'. SLOW DRILLING DUE TO THICKER MUD. DRILLED TO 10940'. LOSING 40% RETURNS. SPOT LCM PILL. 10/17/95 7 11044 LOSING 40% RETURNS. SPOT LCM PILL. LOSING 100°/o RETURNS? OOOPS. DISCOVERED RUPTURED BURST DISK IN SQUEEZE UNIT. THE SOURCE OF THE LOST RETURNS ARE THE GREEN TANK! RECONDITION FLOPRO, DRILL AHEAD SLOWLY WHILE WORKING ON MUD. DIRECTIONAL IS ON TARGET, HOLE IS IN GOOD SHAPE. DRILLING BREAK AT APPROX 10995 (CORRECTED). LOGGED UP AND DISCOVERED CAMCO COUNTER NOT AGREEING WITH MECHANICAL COUNTER. RADIUS AND MECHANICAL COUNTER OK. GEOLOGIST PICKING TSAD @ 8829' TVD. DRILLED PYRITE AT 8'/HR. DRILLED TO 11040'. WIPER TRIP. HOLE SMOOTH. DRILL AHEAD. 10/18/95 8 11105 DRILL AHEAD WITH HIGH PUMP PRESSURES, BHA APPEARS PARTIALLY BLOCKED, FOUND TOP SAD AT 8834 FT TVDSS, SLOW DRILLING THRU SHALE AND PYRITE, HOLE IN GOOD CONDITION. DRILLED TO 11105' AT 3'- 4'/HR. HOLE ANGLE MATCHING SUSPECTED DIP. POOH TO CHANGE TO TANDEM MOTOR. BIT WAS CORED AND JETS PLUGGED W/STATOR RUBBER. FLUSHED COIL. SERVICED INJ HEAD. RIH W/BHA #5. 10/19/95 9 11194 RIH W/BHA #5. TIE-IN WITH GR, DRILL HIGH ANGLE HOLE AND TURN HOLE TO LEFT, DRILLING MOSTLY SHALE AT 8' - 9'/HR, LOGGED GR UP FROM 11,194 FT (8844 TVD) AND LOST SIGNAL FROM RADIUS TOOL. POOH. MOISTURE PROBLEM IN RADIUS CONNECTOR. FREEZE PROTECT COIL. TROUBLE SHOOT RADIUS CONNECTOR. MU BHA#6. 10/20/95 10 11194 MU BHA ¢6. RIH WITH 1.3 DEG BENT MOTOR, COILED TUBING PARTED AT BASE OF INJECTOR HEAD WHILE RIH AT 10800 FT BKB, HAD WENT THRU WINDOW WITHOUT TAGGING ANYTHING AND WAS RIH WITH 26,000 LBS OF WEIGHT AND 2000 PSI PUMP PRESS WHEN CT FAILED. CLOSED MASTER VALVE, WIRELINE RAN LEAD IMPRESSION BLOCK AND SAW END OF UMBILICAL AT 242 FF BKB. ATTEMPTED TO SET OVERSHOT W/9' EXTENSION. STACKING OUT ON UMBILICAL. BUILDING ANOTHER 10' SECTION AT REPORT TIME. 10/21/95 11 11194 WO MACHINE SHOP TO BUILD EXTENSION AND CUTTER. RIH W/OVERSHOT AND 19' EXTENSION ON BRAIDED LINE. STILL STACKING OUT ON UMBILICAL. AT LEAST 19' UMBILICAL ABOVE COIL. RIH W/ CUTTER AND 10' BARREL. WORKED CUTTER. UNABLE TO PULL WITH WL. LEFT CUTTER IN THE HOLE. RIH W/COIL AND ENGAGE CUTTER. PULLED FREE AT 6000¢. CUTTER HAD STRIPPED KYNAR AND E- LINES OFF CONTROL LINE. MODIFY CU%FER. UNABLE TO WORK MODIFIED CUTTER OVER FISH. 10/22/95 12 11194 UNABLE TO WORK MODIFIED CUTTER OVER FISH. RIH W/COIL AND CIRCULATE OUT MUD. LEAVE MEOH CAP. RUN OVERSHOT, 2-3/8" GRAPPLE AND 20' EXTENSION. WORKED OVER TOP OF FISH AT 255' TO 275'A. HUNG UP WHEN POOH. JARRED OFF. FISHED OVERSHOT. RAN LIB. INDICATES THAT CONTROL LINE IS BENT OVER 2". SWABBING IN MUD. RIH W/COIL AND CIRCULATE OVER TO FSW W/MEOH CAP. MODIFY CUTTER. UNABLE TO ENGAGE FISH W/MODIFIED CUTTER. LIB SHOWS CONTROL LINE BALLED UP. RUN WIRE GRAB. LATCH FISH AND JAR OFF. RIH W/COIL. ENGAGE FISH AND PUH 22'W/8K¢ OVERPULL. LOST WEIGHT AND POOH. LIB SHOWS CONTROL LINE IN THE CENTER OF THE TUBING. RUN CUTTER (KILO SOCKET) AND SWALLOW UMBILICAL. JAR OFF. LATCH W/COIL. CUT UMBILICAL W/ 10K¢ OVERPULL, 30' OF STRETCH. RECOVER 18' OF UMBILICAL. (THE TOP 12' WAS SMOOTH CONTROL LINE.) RECOVER ANOTHER 18' UMBILICAL. 36' RECOVERED SO FAR, PUTS THE TOP AT 291'. 10/23/95 13 11194 RECOVERED AN ADDITIONAL 14' OF UMBILICAL, 50' TOTAL. LESS THAN 2' REMAINING ABOVE THE COIL. TOP OF COIL IS AT 302'. RAN IMPRESSION BLOCK AND SAW UMBILICAL IN CENTER OF TBG, RAN 2 3/8" CT OVERSHOT WITH 3.82" OD BELL GUIDE, UNABLE TO LATCH, BELL GUIDE GOING OVER CT, MADE 8" LONG 3.82 BELL GUIDE, SET TWICE WITH SLICKLINE, RIH WITH CT AND TRY TO PRESS GRAPPLE FURTHER ONTO CT FISH, GRAPPLE PULLED FREE AT 12,000 LBS, POOH TO CHECK GRAPPLE, NOT GETTING OVER COIL. MU BHA ¢8, GUIDE SHOE W/2-3/8" SIZING MILL AND NO GRAPPLE. DRESS OFF FISH TO 304.6'. RIH W/BHA ¢9, OVERSHOT W/GRAPPLE. STACKED OUT ON FISH AT 303.8'. PULLED UP, CLEAN OFF BOTTOM AT 50K¢. 10K¢ OVER PULL W/BIT AT APPROX 10950'. PULLED BHA TO SURFACE. MU INTERNAL CONNECTOR. POOH W/FISH. DISPLACED COIL FISH TO MEOH. FREEZE PROTECTED 4-1/2" TUBING TO 725' W/MEOH. FSW SPACER BETWEEN MUD AND MEOH. LD BHA. 10/24/95 14 11194 LD DRILLING BHA. PURGE CT WITH N2, HAUL SECOND REEL TO LOCATION, SET INJ HEAD ON JIG, CUT CT, PICK REEL NO.1 OUT OF REEL STAND, SET REEL NO. 2 IN REEL STAND, M/U INTERNAL CONNECTOR TO GUIDE CT INTO INJ HEAD. SECURE CT AND CUT OFF BRACES. LIFT INJECTOR HEAD INTO PLACE, INSTALL GUY WIRES. MU EXTERNAL CT CONNECTOR, PULL TEST TO 45,000#. BEGIN INSTALLING UPPER CT CONNECTOR. PREP TO TEST BOP. 10/25/95 15 11194 TEST BOP AND CHOKE MANIFOLD. R/U HYDRAULIC CONTROL SKID, CHASE SURFACE ELECTRICAL SHORTS, PURGE CONTROL LINE IN UMBILICAL WITH DI-ELECTRIC FLUID, HEAT COIL BY PUMPING WARM MEOH. ATTEMPT TO REMOVE CT CAP, UNABLE TO REMOVE SET SCREW. DRILL OUT AND RE-TAP SET SCREW. MAKE UP CAMCO BHA, RADIUS TOOLS, DRILEX MOTOR. 10/26/95 16 11260 PU CAMCO, RADIUS, AND DRILEX T.OOLS. PRESSURE TEST, RECOVER MEOH AND TIH. WASH IN HOLE FROM WINDOW TO 10960'. SHALE FALLING IN. REAM TO CLEAN HOLE. WORK TO TD AND RUN GR LOG TO CORRELATE. CORRECT DEPTH (+12') TO CORRELATE TO GR LOG. WASH AND CLEAN HOLE. DRILL TO 11224', SURVEY (SURVEY DEPTH=11207' INCL-85.1° AZIMUTH-149.7°). DRILL TO 11254', SURVEY AND GR LOG TO 1o75o' (SURVEY DEPTH=11237' INCL-86.30° AZIMUTH-146.6°). CONTINUE DRILLING 10/27/95 17 11379 DRILL FROM 11260'. RUN SURVEYS AND GR LOGS. BIT PLUGGED, PROBABLY RUBBER FROM STATOR IN MOTOR. POOH. LD MOTOR, PU NEW MOTOR, TIH. HOLE PLUGGED AT WINDOW. WASH AND REAM THRU WINBOW. WASH AND REAM IN HOLE. 10,800' AT REPORT TIME. 10/28/95 18 11379 WASH AND REAM IN HOLE. ClRC TO CLEAN HOLE. OPEN ClRC SUB AND WASH UPHOLE TO WINDOW PUMPING AT 2 BPM. STUCK GOING INTO TAILIPE. PACKED OFF, LOSING CIRCULATION. PRESSURE 4 1/2" TUBING TO 500 PSI AND WORK PIPE. WORKED FREE AND HAD 100% RETURNS. HAVING PROBLEMS MAINTAINING CHARGE PRESSURE TO BJ. MUD AIRED UP AND FOAMY. POOH AND FREEZE PROTECT CT. BREAK DOWN TOOLS, RADIUS KEMLON CONNECTION HAD LEAKED AND ARCED OUT. REPLACE KEMLON CONNECTOR, PICK UP TOOLS, CHANGE OUT BIT. CHECK ELECTRONICS. TIH. TAG UP AT 10690', BEGIN WASHING AND REAMING IN HOLE. BJ PUMP WENT DOWN, PULL INTO CASING AND SHUT DOWN FOR PUMP REPAIRS. REPAIR BJ PUMP AND WASH IN HOLE 10/29/95 19 11576 FINISH WASH IN HOLE. RUN GR LOG FOR CORRELATION. BEGIN DRILLING, TAKING SURVEYS AND SHORT TRIPS. DRILL TO 11494' MD (8860' TVD). RUN GR LOG. DECISION MADE TO CONTINUE DRILLING TO 9000' TVD. BEGIN DROPPING ANGLE AT 4°/100'. PROJECTED TD 11970' MD. DRILLING AHEAD, LOSING MUD AT RATE OF 5-7 BBL/HR.DRILL TO 11576. SURVEY AND GR LOG UP TO CASING. OPEN CIRC. SUB AND CLEAN UP CUTTINGS IN 7" CASING. 10/30/95 20 11576 CONTINUE CLEANING UP CUTTINGS IN 7" CASING. ATTEMPT TO CLOSE CIRC SUB TO RESUME DRILLING- NO SUCCESS. POOH TO REPAIR CIRC SUB AND CHANGE MOTORS. UNABLE TO REPAIR CIRC SUB. CHANGE OUT CAMCO BHA FOUND SHORT IN CONNECTOR BETWEEN CAMCO BHA AND RADIUS TOP CONNECTION- REPAIR SAME. ATTEMPT TO PRESSURE TEST, FOUND SHORT IN CAMCO BHA. CHECK BHA, FOUND LEAKS IN LOWER PORTION OF BHA RESULTING IN DIRECT SHORTING. LD CAMCO BHA, SEND TO SHOP .FOR REPAIRS. 10/31/95 21 11576 WAIT ON CAMCO BHA REPAIRS. 11/1/95 22 11576 WAIT ON CAMCO BHA REPAIRS. 11/2/95 23 11576 WAIT ON CAMCO BHA REPAIRS. PU TOOLS, PERFORM ELECTRICAL CHECKS. PU STEERING TOOL AND MOTOR, PRESSURE TEST AND TIH. WASH AND REAM IN HOLE. HOLE IS "KNOTTY". PUMP PRESSURE LOW. WASH AND REAM TO 11441' AT REPORT TIME 11/3/95 24 11576 ORIENTER NOT OPERATING, ATTEMPT VARIED PUMP RATES AND HYDRAULIC PRESSURES-NO SUCCESS. POOH, PRESSURE TEST TOOLS. RADIUS WIRE SHORTED OUT ON PRESSURE TEST, FAULT WAS ON CAMCO SIDE OF CONNECTION. UNABLE TO OPERATE ORIENTER ON SURFACE. WAIT ON NEW TOOL FROM CAMCO. PU NEW TOOL. PRESSURE TEST. RECOVER MEOH. 11/4/95 25 11576 OPERATE ORIENTER ON SURFACE. WAIT ON NEW TOOL FROM CAMCO. PU NEW TOOL. PRESSURE TEST. RECOVER MEOH. TIH. ATTEMPT TO WASH AND REAM TO BOTTOM. HOLE PACKING OFF, LOSING CIRCULATION. CLEAN UP HOLE FROM 10956' TO WINDOW. POOH. SET OFF INJECTOR HEAD, SET OUT TOWER SECTIONS. SPOT 1 3/4" CTU. 11/5/95 26 11650 PBTD RIGGED UP 1-3/4 INCH COIL. CHANGED OUT DRLG BOP TO 1-3/4 SLIPS AND PIPES. RAN IN AND LAYED 4 BBL CMT PLUG FROM 10950 TO 10700 CTD. GOT HUNG UPWHILE PULLING ABOVE CMT PLUG @ 10660. DRAGGED HVY FOR 10 FT UNTIL ON THE SKATE. JETTED CASING W/10 BBL BIOZAN TO CONTAMINATE. CONTAMINATE DWN TO 10670. PULLED UP ABOVE WATER SPACERS AND WAITED FOR CMT TO THICKEN BEFORE PULLING OUT THE REST OF THE WAY. FINISH POOH, PICK UP TOOLS, MOTOR, AND MILL. WOC. PRESSURE TEST AND RECOVER MEOH. 11/6/95 27 10720 PICKED UP 3.72 MILL AND 2-78 MTR. RAN IN AND JETTED OUT 7 INCH. SET SPACERS AND BIOZAN CONTAMINANT TO PIT UPON BOTTOMS UP. WASHED INTO OPEN HOLE. WASHED SOFT CMT DWN TO 10712. DRILLED HARD CMT FROM 10712' TO 10720'. CIRCULATED BOTTOMS UP, CLEANED UP 7" CASING AND POOH. PICKED UP TOWER SECTIONS AND INJECTOR HEAD. CHANGE RAMS FROM 1 3/4" BACK TO 2 3/8". PRESSURE TEST BOP. MAKE UP CAMCO BHA, PICK UP AND MAKE ELECTRICAL CHECKS. 11/7/95 28 10841 PICKED UP CAMCO BHA AND RADIUS TOOL. TESTED SAME. PICKED UP DRILLEX MOTOR AND BIT. RAN IN AND JETTED 7 INCH CASING AND OPEN HOLE. LOGGED GR TO GET ON DEPTH. TAG BTM @ 10718 FT. DRILLED TO 10730' WHERE THE BOTTOM FELL OUT. TAGGED HARD CEMENT AGAIN @ 10792'. SIDETRACKED FROM ORIGINAL HOLE TO 10841'. 11/8/95 29 10905 DRILLED W/TURN TO 10840. BEGAN BUILDING ANGLE FROM 10840 TO 10900 MD. HOLE ONLY BUILDING @ 11 DEG/100, NOT ENOUGH. TRIED TO DO GR LOG @ 10900, RADIUS TOOL SHORTED. PULLED OUT. KEMLON CONNECTOR BAD. RAN BHA #17, 1.9° MOTOR. NO PROBLEMS GETTING TO BOTTOM. RAN GR LOG FROM TD @ 10905' TO WINDOW. TOOL SHORTED OUT AGAIN ON 2ND TRIP TO BOTTOM. NO DRAG DURING LOGGING PASS. 8K# DRAG AT 10770' ON FINAL PULL. POOH. 11/9/95 30 10905 POOH TO INSPECT BHA. TOOL SHORTED ON BTM. PULLED OUT. FOUND RADIUS CONNECTOR WET AND CAMCO THROUGH WIRE SHORTED (IN THE SLIP RING). CHANGED OUT CAMCO TOOLS. REPAIRED RADIUS TOOL. RAN BACK IN. RADIUS SHORTED AGAIN ONCE MOTOR VIBRATION STARTED. POOH. BOTH TOOLS SHORTED (KEMLON CONNECTOR AND ?). CHANGE OUT BHA. REDRESS MONEL. 11/10/95 31 10905 REPLACED CAMCO BHA. REPAIRED RADIUS CONNECTOR. (IT APPEARS THAT THE SHORT IN THE RADIUS CONNECTION IS CAUSING THE SLIP RING TO SHORT. THERE'S CURRENTLY NO BREAKER WHEN A GR SHORT OCCURS). PT BHA. RIH AFTER RECOVER MEOH. TOOL SHORTED AGAIN ON BOTTOM ONCE PUMPING BEGAN. POOH. TOOLS WORKING AT SURFACE. TROUBLE SHOOT AND DISCOVER MACHINING PROBLEM. DISCOVERED KEMLON CONNECTOR SLEEVE TOO SMALL IN ID (INCORRECT PART!) WAS NOT ALLOWING WET CONNECT RUBBER BOOT TO SEAL OVER PIN SUB. CHANGE TO CORRECT SLEEVE. RIH. INTERMI-I-FENT SIGNAL ON STEERING TOOL ONLY. GR OK. STEERING WOULD QUIT AT HIGHER PUMP RATES. DECIDE TO ATTEMPT TO DRILL, SHUTTING DOWN TO CHECK STEERING. LOST STEERING SIGNAL ALTOGETHER. GR STILL OK. KEMLON OK. BAD STEERING TOOL OR COUPLER. BAD LUCK. POOH. LD TOOLS. 11/11/95 32 11025 INSPECTED RADIUS TOOLS. KEMLON CONNECTOR OK BUT CONNECTOR BETWEEN GAMMA SUB AND STEERING TOOL WAS IN POOR MECHANICAL CONDITION. TEST CONNECTION- APPEARS TO BE ELECTRICALLY UNSOUND. WORK ON SWAPPING OUT CONNECTOR ENDS. RIH W/BHA. DRILLED BUILD SECTION TO 11005'. TSAD @ 10910', 8831 TVDSS. AVG ROP = 30 FPH. POOH TO CHANGE OUT MOTORS. RIH W/BHA #19, 1°, TANDEM MOTOR. CONTINUE DRILLING SAND TO 11025. 11/12/95 33 11315 DRILL TO 11220', 30 FPH. SWITCHED TO GR AND RADIUS SHORTED OUT. WASHED HOLE AND LINER. POOH. RADIUS AND CAMCO BHAs CHECKED OUT OK. CHECKED UMBILICAL. WIRE #4 (RADIUS) BAD. SWITCHED WIRES. MU BHA (SAME TOOLS) W/3/4° MOTOR. RIH AND RUN GR LOG. WE'RE JUST BELOW 45N SHALE. BUILD ANGLE TO GET BACK ABOVE IT. PROBLEMS GETTING WT TO BIT FROM 11265 - 11280. DRILLING BREAK AT 11300'. LOST APPROX 50% RETURNS. PUH AND WAIT FOR MORE MUD. 11/13/95 34 11315 DRILLING BREAK F/11300'- 11315'. LOST RETURNS. WASH BACK INTO 7 INCH CASING. WAIT FOR MORE MUD. CIRCULATED AGAIN- FULL LOSSES WHILE IN LINER, 90% LOSSES WHILE PULLING OUT OF HOLE. DECISION MADE NOT TO CONTINUE. RIGGED DOWN CTU DRLG UNIT. 11/14/95 35 11315 WO COMPLETION PROGRAM AND ELEMENTS FOR OPEN HOLE INFLATABLE PLUG 11/15/95 36 11315 RIGGED UP 1-3/4 INCH SERVICE COIL AND 7-1/16 BOP STACK, SCAFFOLDING, ETC. PICKED UP BAKER TUBING END LOCATOR AND 3.25" NOZZLE. HAD TROUBLE GETTING PAST CAMCO 6" BY 4-1/16" CROSSOVER WITH THE END OF THE TOOL STRING. BAD LOCATE ON JEWELRY. FLAG PIPE. POOH. LD TEL. RAN IN W/3.5 INCH NOZZLE AND 3-3/8 DISCONNECT. CORRECTED DEPTH TO FLAG MADE ON PREVIOUS RUN. WASHED 7 INCH LINER AND OPEN HOLE. FEW BOBBLES IN OPEN HOLE WHILE PUMPING 1.5 BPM, LOOSING 60% OF THE MUD TO THE LOSS ZONE. TAGGED @ 11227, COULD NOT JET THROUGH. SHORT TRIPPED IN HORIZONTAL SECTION UP TO 10900 AND WASHED BACK DOWN. WASHED OUT OF HOLE. LOOSING 30% OF RETURNS AFTER WASH JOB. 11/16/95 37 11208 WASHED OUT OF HOLE. LOOSING 30% OF RETURNS AFTER WASH JOB. PULLED OUT AND RAN 3-3/8 INFLATABLE BRIDGE PLUG. 50% LOSSES PRIOR TO SETTING. SET AT 11217' (TOP AT 11208') W/HOT SEAWATER. GOOD SET. FULL RETURNS AFTER SET. WASHED HOLE AND LINER W/HIGH VIS SWEEP. CHASED CCH. RU TO RUN LINER. 11/17/95 38 11208 RU TO RUN LINER. RUN 26 JTS 2-7/8", 6.16#, FL4S TUBING (RABBITTED W/2.25" DRIFT), 810' TOTAL. RAN LINER TO TD @ 12208. NO NOTICEABLE DRAG W/CENTRALIZERS. LINER TOP AT 11398'. RELEASED FROM LINER. POOH. RD DSR STACK. PUT FSW/MEOH CAP ON THE WELL. RU E-LINE FOR JEWELRY LOG. 11/18/95 39 11140 RIH W/E-LINE FOR JEWELRY LOG. RUN GR/CCL AND LOCATE LINER TOP AT 10410 ELMD. BOTTOM OF LINER AT 11220' ELMD. MIRU CTU 4905. PERFORM FULL BOP TEST, PUMP 1.25" BALL, PUMP TIW DART AND SHEAR CMTG TOOL AT 32.9 BBLS DISPLACEMENT/2760 PSI. RE-DRESS TOOL AND RIH. STAB INTO SEAL BORE AT 11155'. BREAK CIRCULATION AND ClRC BOTTOMS UP. PUMP 7 BBLS CEMENT AND DISPLACE W/DART. DID NOT SEE DART BUMP. (SUSPECT WE BUMPED AT TOO LOW A RATE). PUMPED 33.1 BBLS. UNSTAB. PUH TO 10150'. RAISED RATE AND BUMPED PLUG @ 33.6 BBLS/3750 PSI. CEMENT IN PLACE AT 23:00. FLUSHED COIL ABOVE LINER AND CHASED CCH. RECOVERED .25 BBLS CMT. RIH W/2.25" NOZZLE. TAGGED CEMENT IN LINER AT 11140'. WASHED LINER. PUMPED HIGH VIS SWEEP. CHANGED WELL OVER TO FSW. 11/19/95 40 11140 CHANGED WELL OVER TO FSW. RD SQUEEZE UNIT, B J, MI. RU TRICO. UNDERBALANCED WELL THROUGH GENERIC DESIGN IN TOP TWO STATIONS. RUN GUN #1 TO SHOOT 11140 - 11120. TAGGED BOTTOM AT 11140 (CORRECTED BASED ON YESTERDAY'S TAG). FIRED GUN #1. POOH. (FLOPRO IN FLUID SAMPLES). 11/20/95 41 11140 FLOW WELL THRU TRICO UNIT WITH 1.8 MMPD GAS LIFT, FIRE GUNS #1 - #4, ALL 20 FT GUNS, 4 SPF TO PERF 11140' - 11060'. THE WELL WAS STILL FLOWING BACK FLOPRO, SOME TRACES OF CARBOLITE. RATES AND CUT DIFFICULT TO DETERMINE BECAUSE OF CHANGING CONDITIONS AND HEAVY EMULSION. LOST GUN #4 IN THE WELL. DISCONNECT HAD FAILED, SUSPECT DUE TO FATIGUE. FISH SAME. (PUSHED GUN TO NEW BOTTOM AT APPROX 11120' TO RECOVER). FLOWED BACK APPROX 300 BBLS FROM THE FORMATION SO FAR. FLOPRO CLEANING UP BY MORNING. BEST GUESS ON RATE IS 500 BPD, 70% WATER. STILL CLEANING UP. LD GUN #4 AT REPORT TIME. 11/21/95 42 11140 LD GUN #4. RIH WITH GUN #5; PERFORATE FROM 11,060 - 11,040, FLOW WELL THRU TRICO TEST SEPARATOR. PERFW/GUN #6 FROM 11,040 - 11,020. FIRST RUN W/GUN #7 MISSFIRED DUE TO DAMAGE TO CROSS OVER SUB. RE-RAN GUN #7 AND PERFORATED FROM 11,020 - 11,000. RIH W/ GUN #8. .: 11/22/95 43 11140 PERFORATE FROM 11,000 - 10,920 FT BKB WITH GUNS #8 - #11WHILE LIFTING WELL WITH 2 MMPD GAS LIFT. WELL IS FLOWING THRU TRICO UNIT. S-27A.PTS BP EXPLORATION DIRECTIONAL SURVEY REPORT .y Repo ,rt CUSTOMER: BPX WELL NAME: S-27A ,- ._o LOCATION · NORTH SLOPE BURROW FIELD · PBUWOA ~, ~, E DATE: 12 NOV 1995 OPERATORS' BLAND MURPHY JOB NUMBER · 5AG064 I L,L.I 'VERTICAL SECTION AZIMUTH ' 149 DEGREES U ~ ~,,~ SURVEY FILE ' 5064 I L,J,J DECLINATION · 29.51 DEGREES (ALL SURVEYS ARE DECLI NATED TO TRUE N ORTH) ORTH) t"V' R.K.B.E.: 64.47' I I WINDOW LOCATION: 10,664' MD GYRO (SUB SEA) TIE IN: STATION #0 INTERPOLATED POINTS: STATION #1 PROJECTED POINT: STATION #18 St. MD Inc Dir Tvd SS Vsec North East Build Turn, Dleg Comment 0 10655' 43 208 8695 3287.8 -4669 -1387 0 0 0 Tie In 1 10664 45.8 207.7 8701.4 3291 -4674.6 -1389.9 31.1 -3.3 31.2 Window Int. 2. 10714 52.6 160.6 8735.1 3320.8 -4710.3 -1391.7 13.6 -94.2 71.6 3 10734 54 175.2 8747.1 3335.8 -4725.9 -1388.4 7 73 58.9 4 10764 57.8 184.1 8764 3357.2 -4750.7 -1388.3 12.7 29.7' 27.6 5 10797 61 184.1 8780.8 3380.4 -4779.1 -1390.3 9.7 0 9.7 6 10827 61.7 177.1 8795.2 3402.8 -4805.4 -1390.6 2.3 -23.3 20.6 7 10857 63.5 172.2 8809 3426.8' -4831.9 -1388.1 6 -16.3 15.7 8 10887 67 171.3 8821.5 3451.9 -4858.8 -1384.2 11.7 -3 12 9 10924 73.9 169.9 8833.9 3484.3 -4893.2 -1378.5 18.6 -3.8 19 10 10947 79.8 169.1 8839.1 3505.3 -4915.2 -1374.4 25.7 -3.5 25.9 11 10992 88.5 161.9 8843.7 3548.2 -4958.5 -1363.2 19.3 -16 25 12 11023 90.2 155.8: 8844.1 3578.7 -4987.4 -1352 5.5 -19.7 20.4 13 11083 87.7 148.4 8845.2 3638.5 -5040.4 -1324 -4.2 -12.3 13 14 11143 87.3 141.3 8847.8 3698.3 -5089.31 -1289.5 -0.7 -11.8 11.8 15 11203 86.5 134.8 8851.1 3757.1 -5133.9 -1249.5 -1.3 -10.8 10.9 16 11243 85.6 132.1 8853.8 3795.5 -5161.3 -1220.5 -2.3 -6.7 7.1 17 11273 86.8 132.8 8855.8: 3824.2 -5181.5 -1198.4 4 2.3 4.6 18 11286 86.8 132.8 8856.5 3836.7 -5190.3 -1188.9 0 0 0 These surveys are true and correct to the best of my knowledge. Bimo Hadiputro DRILE _ _ BP EXPLORATION-S-27A Directional Survey Report CUSTOMER: BPX WELL NAME: S-27A LOCATION : NORTH SLOPE BURROW FIELD : PBUWOA DATE: 12 NOV 1995 OPERATORS : BLAND , MURPHY JOB NUMBER : 5AG064 VERTICAL SECTION AZIMUTH : 274.4 DEGREES SURVEY FILE : 5064 DECLINATION : 29.51 DEGREES (ALL SURVEYS ARE DECLINATED TO TRUE NORTH) R.K.B.E.: 64.47' WINDOW LOCATION: 10,656' MD GYRO (SUB SEA) TIE IN: STATION #0 INTERPOLATED POINTS: NONE PROJECTED POINT: STATION #21 Station MD Inc Az North East SS Depth VS DLS 0 10655 1 10664 2 10679 3 10693 4 10709 5 10714 6 10734 7 10764 8 10797 9 10827 10 10857 11 10887 12 10924 13 10947 14 10992 15 11023 16 11083 17 11143 18 11203 19 11243 20 11273 21 11286 43 0 45 8 48 5 5O 9 52 5 52 6 54 0 57 8 61 0 61 7 63 5 67 0 73 9 79 8 88 5 90 2 87 7 87 3 86 5 85 6 86 8 86 8 208 0 -4669 0 -1387 0 207 7 -4674 6 -1389 9 207 7 -4684 3 -1395 1 207 7 -4693 8 -1400 0 207 7 -4704 9 -1405 8 160 6 -4708 175 2 -4724 184 1 -4749 184 1 -4777 177 1 -4803 172 2 -4830 171 3 -4857 169 9 -4891 169 1 -4913 161 9 -4956 155 8 -4985 148 4 -5038 3 141 3 -5087 8 134 8 -5132 132 1 -5159 132 8 -5179 132 8 -5188 6 -1406 2 -1402 0 -1402 4 -1404 7 -1405 2 -1402 1 z.1398 5 -1392 1 8733 8 8745 7 8762 7 8779 0 8793 5' ''8807 6 8820 8 8832 5 -13.88.8 8837 · 8 -1377 5 8842 7 -1366 4 8842 6 -1338 8843 6 -1303 8846 1 -1263 8 8849 6 -1234 8 8 -1212 7 6 -1203~2 8695.0 3287 8 8701.4 3291 8711.6 3296 8720 7 3302 8730 6 3308 8 3311 7 3327 6 3348 4 3371 8 3393 6 3417 1 3443 5 3475 8 3496 3 3539 7 3569 8 3629 4 3689 7 3748 8852'.4 3786 8854.4 3815 4 8855.1 3827 8 7 18 3 17 8 10 9 739 0 58 3 27 5 9 9 20 9 15 1 12 5 19 4 25 3 25 8 20 7 13 4 11 2 10 7 7 4 0 N/A 0 31 2 0 1 0 7 9 6 7 6 7 0 0 9 0 4 0 8 9 1 6 0 These surveys are true and correct to the best of my knowledge .. ; I o . , C: ~BPhX-27A. WP STATE OF ALASKA A._.,SKA OIL AND GAS CONSERVATION COMM~,....,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well Plugging __ Time extension __ Stimulate Change approved program x Pull tubing __ Variance __ Pedorate .__ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 64.47 feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. 1635'SNL, 4049'WEL, Sec. 35, T12N, R12E At top of productive interval 1264' SNL, 226' WEL, Sec. 3, T11N, R12E At effective depth At total depth 1747' SNL, 5198' WEL, Sec. 2, T11N, R12E Well number S-27A(13-03-11-12) 9. Permit number 95-100 10. APl number 50- 029-22057-01 11. Field/Pool Prudhoe Bay Fie/d/Prudhoe Bay 12. Present well condition summary Total depth: measured 10727 feet true vertical 8745 ss feet Effective depth: measured 10727 feet true vertical 8745 ss feet Casing Length Size Structural .... Conductor 80' 20" Surface 2659' 13 3/8 Intermediate 10605' 9 5/8" Production -- Liner 887' 7" Perforation depth: measured none Plugs (measured) Junk (measured) Cemented 3296 c.f. 2393 c.f. 280 c.f. Measured depth 110 2689 10635 11250 True ve~icaldepth BKB 110 2652 87O8 9181 true vertical Tubing (size, grade, and measured depth) 4 1/2", L-80 12.6# @ 11012'MD Packers and SSSV (type and measured depth) 9 5/8" Baker Packer at 10350' MD 4 1/2" Otis SSSVat 2122' MD 13. A~achments Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation October 7, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,.~~//~~ Title Coi/ed Tubing Engineer FOR COMMISSION USE ONLY Date Oct. 5,1995 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- /-~7 Original Signed By David W. Johnston Approved by order of the Commission /Approval N o~c~,-...//'~-~' ,-~Dp,oved Colby Re,,turn~d .... ! 01/ 717.~'- '"'" Commissioner Date SUBMIT IN ~R~¢LIbATE Form 10-403 Rev 06/15/88 S-27A Proposed Completion KB. ELEV = 56.04' BF. ELEV = 28.36' TREE: WELLHEAD: ACTUATOR: 4" ClW FMC OTIS CMT'd 13 3/8", 68#/ft, I I~ NT-8OCYHE, BTRS 2689' IKOP: 2800' MAX ANGLE: 470/8800' 4 1/2", 12.6#/ft, L-80, TDS NON-IPC TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 4 1/2", 12.6 #/ft, L-80 TAI 9 5/8", 47#/ft, NT-80S, NSCC 110,635' I PERFORATION SUMMARY REF LOG: ATLAS - BHCS - 7-26-90 -SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8" 6 10,648 - 10,698' SQZD/9-6-91 " 6 10,820 - 10,832' SQZD/3-24-91 " 6 10,834 - 10,910' SQZD/9-6-91 " 6 10,910 - 10,922' SQZD/3-24-91 3 3/8" 4 10,932 - 10,990' SQZD/9-6-91 " 6 10,990 - 10,994' SQZD/3-24-91 3 3/8" 6 10,840 - 10,880' Plugged " 4 11,025 - 11,035' SQZD/3-24-91 " 4 11,035 - 11,055' SQZD/9-6-91 " 4 11,055 - 11,074' SQZD/3-24-91 " 6 11r088 - 11~100' SQZD/3-24-91 3 3/8" 6 10,840 - 10,870' Plugged 3 3/8 6 10,648 - 10,698' SQZD 7/25/95 MARKER JOINT 11o,775' 7" OTIS WD PACKER 4 1/2" "X" NIPPLE (OTIS) (3.813" ID ) 4 1/2" "XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" WLEG (PARKER) (3.86" ID) (ELMD) XXN PLUG w/SCALE CAP. TD @ 10,972' , ELMD, ON 10-31-91. PBTD 1.11,190'1 7", 26 #/ft, L-80, TC4S I, I 1,250'1 111.o11'1 TOC (OTIS)(3.813"1D) 2122' GAS LIFT MANDRELS fCAMCO W/1-1/? RK LATCH) N-° MD(BKB) tVDss DEV. 5 3163' 3104' 8° 4 5659' 5142' 45° 3 8089' 6865' 43° 2 10,047' 8263' 43° 1 10,309' 8454' 44° 4 1/2 .... SWS"NIPPLE I 10,338'1 (PARKER) (3.813" ID) BAKER TUBING I 10,349'1 ANCHOR 9 5/8" BAKER PACKER I 10,350'J (SB-3) (3.99" ID) ~ TOP OF TIW 7" LINER 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2" PARKER WLEG 2 7/8" FL4S Liner Top of Liner Cement 110,363' I I 10,423'1 I 10,434'1 ELMDI 10,448'1 SHUBLIK SADLEROCHIT 868855 872755 882355 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Date: Oct. 5, 1995 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johnson, Chairman Well S-27A is scheduled to resume operations on Oct. 7, 1995 after suspending operations on August 29, 1995. The coil drilling operation will be carried out as permitted under #95-100 except that a 2 7/8", L-80, FL4S liner will be cemented in the 3 3/4" open hole rather than the "open hole" completion originally permitted. A diagram of the planned completion is attached along with Form 10- 403. Sincerely, CTU Drilling Engineer CC: Well File Petrotechnical Data Center 0C'i' 09 1995 Gas Cons, Commission 'Anchorage BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johnson, Chairman COUM BP Exploration (Alaska) Inc. 900 East Benson Boulevard .D~o: Oct. 2, 1 Well S-27A is scheduled to resume operations on Oct. 6, 1995 after suspending operations on August 29, 1995. Coil drilling will be carried out as permitted under #95-100 except that a 2 7/8", L-80, FL4S liner will be cemented in the 3 3/4" open hole rather than the "open hole" completion originally permitted. A diagram of the planned completion is attached. Sincerely, Ted Stagg CTU Drilling Engineer CC: Well File Petrotechnical Data Center S-27A Proposed Completion KB. ELEV = 56.04' BF. ELEV = 28.36' TREE: WELLHEAD: ACTUATOR: 4" CIW FMC OTIS CMT'd 13 3/8", 68#/ft, I I NT-8OCYHE, BTRS 2689' ~ IKOP: 2800' MAX ANGLE: 47o/8800' 4 1/2", 12.6#/ft, L-80, TDS NON-IPC TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 4 1/2", 12.6 #/ft, L-80 TAILPIPE 9 5/8", 47#/ft, NT-80S, NSCC [10,635' PERFORATION SUMMARY REF LOG: ATLAS - BHCS - 7-26-90 -SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8" 6 10,648 - 10,698' SQZD/9-6-91 " 6 10,820 - 10,832' SQZD/3-24-91 " 6 10,834 - 10,910' SQZD/9-6-91 " 6 10,910 - 10,922' SQZD/3-24-91 3 3/8" 4 10,932 - 10,990' SQZD/9-6-91 " 6 10,990 - 10,994' SQZD/3-24-91 3 3/8" 6 10,840 - 10,880' Plugged " 4 11,025 - 11,035' SQZD/3-24-91 " 4 11,035 - 11,055' SQZD/9-6-91 " 4 11,055 - 11,074' SQZD/3-24-91 " 6 11,088 - 11~100' SQZD/3-24-91 3 3/8" 6 10,840 - 10,870' Plugged 3 3/8 6 10,648 - 10,698' SQZD 7/25/95 MARKER JOINT I 1 0,775' 7" OTIS WD PACKER 4 1/2" "X" NIPPLE (OTIS) (3.813" ID ) 4 1/2" "XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" WLEG (PARKER) (3.86" ID) (ELMD) XXN PLUG w/SCALE CAP. TD @ 10,972' , ELMD, ON 10-31-91. PBTD I 11,190'1 7", 26 #/ft, L-80, TC4S 111,635'1 111,o11'1 TOC SSSV LANDING NIPPLE (OTIS) (3,813"1D) I 2122' GAS LIFT MANDRELS (C~iMCO w/1-1/2" RK LATCH~ N-° MD(BKB) TVDss DEV. 5 3163' 3104' 8° 4 5659' 5142' 45° 3 8089' 6865' 43° 2 10,047' 8263' 43° 1 10,309' 8454' 44° 4 1/2 .... SWS" NIPPLE~1 10,338'11 (PARKER) (3,813" ID) BAKER TUBING I 10,349'1 ANCHOR 9 5/8" BAKER PACKER I 10,350'1 (SB-3) (3.99" ID) TOP OF TIW 7" LINER 4 1/2" "SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2" "SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2" PARKER WLEG Top 2 7/8" FL4S Liner of Liner Cement 110,363' I I 10,423'1 1 10,434'1 ELMDI 10,448'1 SHUBLIK SADLEROCHIT 868888 872788 882388 BP EXPLORATION SEP 05 A_ta_s~ Di! & Gas Cons. C_ommisslon ,. ~mcliorage~ To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' David Johnston, Chairman Date: Sept. 1, 1 Subject: Well S-27 A Well Permit (95-100) Well S-27A operations have been suspended until approximately Sept. 15, 1995 due to mechanical problems with equipment. Sixty five (65) feet of 3.75" hole was drilled (10662-10727) prior to suspending operations on 8/30/95. A diagram of the current well condition is attached Yours Sincerely, Ted Stagg CTU Drilling Engineer FH cc. Well file Petrotechnical Data Center TREE: 4" CIW WELLHEAD: FMC ACTUATOR: OTIS 13 3/8", 68~/ft, I NT-8OCYHE, BTRS 2689' ~ IKOP: 2800' MAX ANGLE: 47o/8800 4 1/2", 12.6#/ft, L-80, TDS NON-IPC TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 4 1/2", 12.6 #/ft, L-80 TAILPIPE 9 5/8", 47#/ft, N -.os, N OC 110,638'1 PERFORATION SUMMARY REF LOG: ATLAS - BHCS - 7-26-90 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8" 6 10,648- 10,698' SQZD/9-6-91 " 6 10,820 ~ 10,832' SQZD/3-24-91 " 6 10,834- 10,910' SQZD/9-6-91 " 6 10,910- 10,922' SQZD/3-24-91 3 3/8" 4 10,932- 10,990' SQZD/9-6-91 " 6 10,990- 10,994' SQZD/3-24-91 3 3/8" 6 10,840- 10,880' Plugged " 4 11,025 - 11,035' SQZD/3-24-91 " 4 11,035 - 11,055' SQZD/9-6-91 " 4 11,055 - 11,074' SQZD/3-24-91 " 6 11~088- 11~100' SQZD/3-24-91 3 3/8" 6 10,840 - 10,870' Plugged 3 3/8 6 10,648 - 10,698' SQZD 7/25/95 MARKER JOINT I 10,775' S-27A TOC Wel, =tatus as of Aug. 30, 1995. Operations temporarily suspended. KB. ELEV = 56.04' BF. ELEV = 28.36' SSSV LANDING NIPPLE (OTIS)(3.813"ID) I 2122' I GAS LIFT MANDRELS (Cl MCO w/1-1/2" RK LATCH) 'N-° MD(BKB) TVDss DEV. 5 3163' 3104' 8° 4 5659' 5142' 45° 3 8089' 6865' 43° 2 10,047' 8263' 43° 1 10,309' 8454' 44° TOP OF TIW 7" LINER 4 1/2" ",.~W,S" NIPPLE (PARKER) (3.813" ID) 4 1/2" "SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2" PARKER WLEG 4 1/2 .... SWS"NIPPLE I 10,338'1 (PARKER) (3.813" ID) BAKER TUBING 110,349'1 ANCHOR 9 5/8" BAKER PACKER ] 10,350'1 (SB-3) (3.99" ID) 110,363'J i 10,42 '1 1 10,434'J EL.O I 10,448'l 868888 SHUBLIK 872788 882388 7" OTIS WD PACKER 4 1/2 .... X" NIPPLE (OTIS) (3.813" ID ) 4 1/2 .... XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" WLEG (PARKER) (3.86" ID) (ELMD) [ 11.01--"~'~ XXN PLUG w/SCALE CAP. TD @ 10,972', ELMD, ON 10-31-91. PBTD I'~ 1,190'1 7", 26 #/fi, L-80, TC4S J 11,635'1 ',,,.% % % % % SADLEROCHIT BP EXPLORATION To: JUL 1 8 1995 0ii & Gas Cons. Commission Ancho:~ ' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date: July 15, 1995 Attention: David Johnston, Chairman Subject: Well S-27L1 Well Permit (95-100) Well name S-27L1 needs to be changed to well S-27A. Perforations that were originally left open were squeezed off leaving no open perforations in the original wellbore. Yours Sincerely, Brock Williams CTU Drilling Engineer FH cc. Well file Petrotechnical Data Center · ~CONS~ ~LASKA OIL AND GAS RVATION COM~IISSION TONY KNOWLES, GOVERNOH 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 11, 1995 Brock Williams, Coil Tubing Engineer BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit $-27L1(13-03-11-12) BP Exploration (Alaska) Inc Permit No. 95-100 Surf Loc 1633'SNL, 4048'WEL, Sec 35, T12N, R12E, UM Btmhole Loc 1747'SNL, 5198'WEL, Sec 2, T11N, R12E, UM Dear Mr Williams: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permils required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to wilness a tesl of BOPE installed prior to drilling a new hole. Notice may be given ector on the Nodh Slope pager at 659-3607. · David ~Johnston Chairman BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill []llb. Type of well. Exploratoryl-i Stratigraphic Test [] Development Oil[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exp/oration 64,47 feet Prudhoe Bay Fie/cYPrudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchor~ae. Alaska 99519-6612 ADL ~ :z. ~ ~. ~0 ~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 2s.o25) 1633' SNL, 4048' WEL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1264'SNL, 226' WEL, SEC. 3, T11N, R12E S-27L1(13-03-11-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 1747'SNL, 5198' WEL, SEC. 2, T11N, R12E July 15, 1995 $200,000.00 12. Distance to nearest 13. Distance to nearest well ~4. Number of acres in property15. Proposed depth (MD and mVD) property line ADL 28260 @90' feet No close approach feet 2560 11537MD/8906 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 10646 feet Maximum hole angle aa o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 3.75 Open ECEI l g. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary JUN ?-c~ '~cjo~5 Total depth: measured 11250 feet Plugs (measured) true vertical 9181 feet RIP, st,a, Oil & Gas Cons. Commission Effective depth: measured 11190 feet Junk (measured) ^nch0r;../" true vertical 9140 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 110' 20"x30" 138 138 Conductor Surface 2689' 13 3/8" 3296 c.f. 2689 2652 I nte rmed late 10635' 9 5/8" 2393 c.f. 10635 8708 Production -- Lin e r 11250' 7" 280 c.f. 11250-11635 9145-9408 Perforation depth: measured 10648'-10698', 10840'-70', 10870'-80', Sqzd{10820'-11100' (twelve intervals)} true vertical 8689'-8726'~8829'-8851'~8851'-8858'~ Sqzd{8815'-9014'(twelve intervals)} 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the fo~'egoir~g is true and correct to the best of my knowledge Signed~~~~~ Title CoilTubingEngineer Date ~_//~'7/~.v4' Commission Use Only Permit Number JAPI number IApproval date ISee cover letter ,3',5'-,/,c:'~ I5°- oz?""=-~o,-5'-~"~ ? I ~"/'/'"~'..I~"' Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures ~ Yes [] No D~rectional survey requ~rea [] Yes [] No Required working pressure for BOPE []2M; 1-13M; ~5M; I-I10M; I-'115M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner me commission Date "~ "'/'/-"~ Form 10-401 Rev. 12-1-85 Submit in triplicate BPX S-27 Sidetrack Summary of Operations: S-27 is currently shut-in due to high GOR. The well is being sidetracked to achieve lower GOR production. This sidetrack will be conducted in two phases with an operation shut-down of 1-2 weeks in between Phase 1 and Phase 2. Phase 1: Cut Window: Planned for July 15 thru July 19. - The existing Ivishak perforations will be isolated with a cement plug. - A whipstock will be set on ELine at the top of the Sag at 10646' MD. - Utilizing a conventional coil tubing unit, a window will be cut in the 7" and 10 ft of formation will be drilled. - Coil unit will then be rigged down and 1-2 weeks will elapse before resumption of operations. Phase 2: Drill Directional Hole: Planned for July 25 thru August 2. - Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan to planned TD of 11,537' MD (8,842' TVDss). Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.6 - 9.0 ppg) or Seawater (8.6 ppg) Casing Program: - Completion will be open hole. 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: 10,646' MD (8,688' 'i-VD ss) - TD: 11,537' MD (8,842' TVD ss) - Magnetic and inclination surveys will be taken every 25 ft. No gyro will be run. Logging - A gamma-my Icg will be run over all of the open hole section. A GR/Induction Icg will be conveyed on CTE prior to putting well on production. TREE: 4" CIW WELLHEAD: FMC ACTUATOR: OTIS 13 3/8", 68#/ft, NT-80CYHE, BTRS IKOP: 2800' MAX ANGLE: 47°/8800' CMT'd 4 1/2", 12.6#/ft, L-80, TDS NON-IPC TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 4 1/2", 12.6 #/ft, L-80 9 5/8", 47#/ft, NT-8OS, NSCC I10,635' ',',',iii',~',i~iiiiii!iiiREF LOG: ATLAS - BHCS - 7-26-90 ~'.'.:~£~:~:~:~:~: ............................................................................................... ~- ::::~: ::~::::~:~:~:~:~ SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8" 6 10,648 - 10,698' SQZD/9-6-91 q; " 6 10,820- 10,832' SQZD/3-24-91 " 6 10,834- 10,910' SQZD/9-6-91 " 6 10,910- 10,922' SQZD/3-24-91 3 3/8" 4 10,932 - 10,990' SQZD/9-6-91 " 6 10,990- 10,994' SQZD/3-24o91 3 3/8"i 6 10,840- 10,880' OPEN/Il-2-91 " 4 11,025 - 11,035' SQZD/3-24-91 " 4 11,035 - 11,055' SQZD/9-6-91 " 4 11,055 - 11,074' SQZD/3-24-91 " 6 11~088 - 11 ~100' SQZD/3-24-91 3 3/8" 6 10,840 - 10,870' REPERF 9-22-92 3 3/8 6 10,648 - 10,698' REPERF 8-20-93 MARKER JOINT I 10,775' 7" OTIS WD PACKER 4 1/2 .... X" NIPPLE (OTIS) (3.813" ID) 4 1/2 .... XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" WLEG (PARKER) (3.86" ID) (ELMD) I 11,011 '1 XXN PLUG w/SCALE CAP. TD @ 10,972', ELMD, ON 10-31-91. PBTD ] 11,190'1 7", 26 #/ft, L-80, TC4S ] 11,635'l S-27 KB. ELEV = 56.04' BF. ELEV = 28.36' SSSV LANDING NIPPLE I 2122' I (OTIS) (3.813"1D) GAS LIFT MANDRELS (CI MCO w/1-1/? RK LATCH~ N° MD(BKB) TVDss DEV. 5 3163' 3104' 8° 4 5659' 5142' 45° 3 8089' 6865' 43° 2 10,047' 8263' 43° 1 10,309' 8454' 44° (SB-3) (3.99" ID) TOP OF TIW 7" LINER 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2" PARKER WLEG 41/2 SWS"NIPPLE .... I J (PARKER) (3.813" ID) 10,338' BAKER TUB~NG I 10,349'1 ANCHOR 9 5/8" BAKER PACKER 110,350'J 1 o,363'1 1 10,423'l 1 10,434'I ELMDI 10,448'1 SHUBLIK SADLEROCHIT % JUN 29 i995 Alaska 0il & Gas Cons, Commission Anchor,: ~-- TREE: 4" OIW WELLHEAD: FMO ACTUATOR: OTIS I,3 3/8", NT-aOCYHE, BTRS CMT'd KOP: 2800; MAX ANGLE: 4 I/2", 12.6#/ft, L-80, TD$ NON-IPC TUBING TUBING lB: CAPACITY: 0.0152 BBL./FT NT-80S, N$CC ~R~.F.. LOQ: ATLAS- BHCS- 7,-~~ SIZE SPF IN~RVAL .... : 6 ~0,~0- 10~32= 8QZD/~-2~t 6 ~0,~- 10,910' , 6 10,910- 10,82~' 3 ~" 4 10,932 - 10,~' " 6 10,9~ - 10R94' ', ~0ZD/~24-91 3 ~" 6 tO~- 10,~" PIusged ~ 6 ~ t ,oaa - 1 ~ ~ 00' SQZD/~24-91 MARKER JOINT ?'OTIS WD PACKER 4, 1/2" "X" NIPPLI~ (OTIS) (~.el~" ID ) 4 1/2" "XN" NIPPLE (OTIS) ( ~. 1/~:' WLEG (PARKER) (S.86" ID) (ELMD) ~N P~UG w/SCALE C~. T~ e 10,973', E~D, ON 10-31-~1. ~,,, ~ ~/~, L-~o, Tc~s ! 11,635'1 S-27L1 KB. ELEV -- $6,04' BF. ELEV -- SSSV LANDING NIPPLE (OTIS)(~,813"1D) tC~MCO wi1-1~' RK L.ATCH~ N,i ND(BI<B) TVDss I DEv. B 3163' 31~' 8~ 4 5659' 51~' ~o 3 80Bg' 6865' 43~ ~ 10,~7' 82~' 4~ 1 1 O, ~9' a4~' ~ ...... 4 ~/a" "sws" N~PL= i 10.33a'1 (PARKER) (3.815" ID) BAKER TUB]N(-3 I 10,349'1 ANCHOR 9 5/8" BAKER PACKER ~ TOP OF TIW 7" LINER 4 1/2 .... SWS' NIPPLE (PARKER) (3.815" ID) 4 1/2" "SW$" NIPPLE (PARKER) (~.B13" ID) 4 t/2" PARKER WLE(3 i 10~423'1 8HUBLIK SADLEROCIfllT 87L~Tss 8823ss 8,500 8,550 8,600 8,650 8,700 v 03 8,750 8,800 ~-'~- 8,850 ['T'i 8,900 8,950 S-27A 450O 4750 Vertical Section 5000 Departure (Feet) 5250 5500 5750 60O0 TSHU @ K.O.= 43 deg DL 1= 22.3 Incl Crv1= 88 deg DL 2= 0.0 deg/100 Incl Crv 2= 88 deg Target Depth ~I'SAD Marker Depths TSHU I TSAD I Target I Kick Off I Deprtr @ KO 8,6881ft SS 8,7271ft SS 8,8231ft SS 8,8381ft SS 8,688 ft SS 10,646 ft MD 4,879 ft IMD KO Pt MD New Hole Total MD TD (SS) 10,646I 8911 11,537I 8,8421 Build Rt deg/100 MD (ft) -13.3 3z[6 0.0 1 0.0 550 Curve 1 Curve 2 Curve 3 Drawn: Plan Name: 5/17/95 12:52 Case I 15' TVD below Ft West Of Sfc Location S-27A Plan View -2,000 -1,500 -1,000 Original Wellbore -500 New Hole Target Polygon Ft South Of Sfc Location -4,250 -4,500 - -4,750 - -5,000 - -5,250 - -5,500 -5,750 -6,000 - IWell Name S-27A I CLOSURE Distance 5,512 ft Az 1 91 decj . NEW HOLE E/W (X) N/S (Y) Kick Off -1,384 -4,663 Top Sad -1,372 -4,931 State Plane 618,021 5,974,925 TD -1,056 -5,410 State Plane 618,337 5,974,446 Surface Loc 619,393 5,979,856 TSAD Step Out 1 68[ I MD of TSAD -> TD 574I Net Sand 0.85 488 Az Chg (de!I/100) MD (ft) ~.18.(~ 3~(~ 0.0 1 0.0 55O Curve 1 Curve 2 Curve 3 Drawn: 5/17/95 12:52 Plan Name: Case 1 15' TVD below Ti CTDM:2.3.2A IOoil Tubing BOPEI I Pump-In SubI Blind/Shear Blind/Shear Pipe Rams Slip Rams IT~J~ ! BOP Stack Type A To be used for drilling with mud I Spacer Spools I(as needed for Height) To Choke Manifold Mud Cross I Hydraulic Actuated ValveI Manual Valve I Manual Swab Valve/ IManual Valve ~1 Existing Flowline I I Hydraulic Act uat ed Valve I Manual Mast er Valve I Manual Wing Valve RECEIVED JUN 2 9 1995 Als. ska 0il & Gas Cons. Commission Lift Gas In I I(if applicable)J FLUID FLO'~"~CHEMATIC (with Type 'A' BOP) CTDM;1.2.25V0 Seaw~ ter MeOH Green Tank (Dived) Charge Pump Dead Crude (vac trucks) ITank Farm Charge Pumps Cosasco Valve Choke Manifold icro motion Cuttings~ MI Van 3 Squeeze Manifold CTU BJ Pumper Normal flow Gas Divert Fluid transfer from tank farm/upright tanks to B J/MI Manually operated valve ICTDM:1.2.23v!~ Site PlanTD ~ SEAWATER GREEN (DIVERT) TANK em CHARGE PUMP HEATERI TOWER WIND SOCK S I, DIV I AND DIV II ~ BLEED TRAILER e O X E LAB ISss eee E 0 0[+, CHOKE MANIFOLD el IIFLASS I' DIM Il TANK I xl~lx* ~ +,+ FARM · CLASS I, DIV I* SQZ MANIFOLD GENERATOFe~ ~+ E+AI CLASS I, DIV I' ® MI VAN 3 · sI· FIRST AID STATIONS BJ PUMPER EMERGENCY ESCAPE PACKS SCOTT AIR PACKS PRESSURIZED N2 BOTTLES OTHER FIRE HAZARDS - PAINT, LUBRICANTS, RAGS, CHEMICALS .... HALON DUMP/STORAGE EYE WASH STATION FUEL STORAGE H2S SENSORS OR WARNING LIGHTS H2S/LEL SENSORS OR WARNING LIGHTS GLYCOL STORAGE ESD FIRE EXTINGUISHERS ~ WELL (Safed Out) 50' CENTERS TOOL TRAILER/ K ROOM ~;~ GENERATOR ~,~'~N~ BOOM ~ e TRUCK '~PROX 120' P( HEATERe~ SCS PLANT GENERATO~'~ WELLS SHOWN ON MAN LIFT WIND SPEED SOHIO TRAILER DIRECTIONAL DRILLERS OPS CAB WELL PERMIT CHECKLIST PROGRAM: exp [] dev [] redrll~ serv [] ADMINISTRATION ENGINEERING APPR DATE 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from ~ther wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... N Surface casing protects all known USDWs ........ N CMT vol adequate to circulate on conductor & surf cSg. N CMT vol adequate, to tie-in long string to surf csg . . N CMT will cover all known, productive horizons ...... N Casing designs adequate for C, T, B & permafrost .... N Adequate tankage or reserve pit ............. N If a re-drill, has a 10-403 for abndnmnt been approved..-~"-N Adequate wellbore separation proposed .......... ~ N If diverter required, is it adequate .......... Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate .................... '(~) N BOPE press rating adequate; test to ~'O~D0 psig. Y N Choke manifold complies w/API RP-53 (May 84) ...... Work will occur without operation shutdown ....... Is presence of H2S gas probable ............ O N "It- I' - GEOLOGY 30. 31. 32. 33. 34. Permit can be issued w/o hydrogen sulfide measures Data presented on potential overpressure zones ..... Seismic analysis 9f shallow gas zones .......... Seabed condition survey (if off-shore) ....... Contact name/phone for weekly progress reports . . [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: TAB Comments/Instructions: Z o HOW~o - A:~ORMS~cheklist rev 0~94