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Home My WebLink About196-051 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. /9f1 ()~/ Well History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # 0 Diskettes - # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No 0 Mud Logs # - 0 Other # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged IBI Abandoned 0 Suspended 0 WAG 20AAC25.105 20AAC25.110 21. Logs Run: MWD, MLL, DLL, RB, Temp, ZDL, CHT, LWD/FE, GR, CCL, PFC, POL CASING, LINER AND CEMENTING RECORD SETTING OEf>TH Mb'.- SÈ1ÏINC? DI;~TÌf1'\iò:' ffo~É . ' c " ..' , ' Top 'BotTÒM ' lOP;.' BOTToM. /~'Sze'. :; ,;;:::;.~,ÇMNrjN.G REc;ORP Surface 110' Surface 110' 32" 390 sx Arcticset II Surface 2606' Surface 2606' 17-1/2" 1975 sx Fondu, 400 sx Permafrost II Surface 7700' Surface 6847' 12-1/4" 800 sx Class 'G', 300 sx PF 'C' 7547' 11160' 6744' 8940' 8-1/2" 190 sx Class 'G' 11183' 12894' 8951' 8994' 6" Uncemented Slotted Liner , . , ""0 '. ,,' 25. ': A(iIQ,FRÁCTUREi ÇÈM~T ~QU.EEzE, ETC., DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ~ P&A with 80 Bbls Class 'G', 2nd Plug of 37 Bbls II ,ICO ~ Class 'G', 3rd Plug of 36 Bbls Class 'G' 6856' Set EZ Drill Bridge Plug 6829' Set Top of Whipstock PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL-BBL 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2795' NSL, 4830' WEL, SEC. 22, nON, R15E, UM Top of Productive Horizon: 1635' SNL, 4053' WEL, SEC. 27, T10N, R15E, UM Total Depth: 3336' SNL, 3713' WEL, SEC. 27, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 708703 y- 5928144 Zone- ASP4 TPI: x- 709611 y- 5923738 Zone- ASP4 Total Depth: x- 710001 y- 5922047 Zone- ASP4 18. Directional Survey 0 Yes IBI No 22. CASING SIZE 20" 13-3/8" 9-5/8" WT. PER FT. 94# 72# 47# 29# 12.6# GRADE H-40 L-80 L -80/S0095 L-80 L-80 7" 4-1/2" 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): None MD MD TVD 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE"'" OIL-BBL Zero Other 5. Date Comp., Susp., or Aband. 2I7/20O4/f1..., 6. Date Spudded 4/22/1996 7. Date T.D. Reached 04/26/1996 8. KB Elevation (ft): KBE = 69.78' 9. Plug Back Depth (MD+ TVD) 12894 + 8994 10. Total Depth (MD+TVD) 12894 + 8994 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. ' SIZE 3-1/2",9.2#, L-80 TVD GAs-McF WATER-BBL 1b. Well Class: IBI Development 0 Exploratory 0 Stratigraphic Test 0 Service 12. Permit to Drill Number / 196-051/ 304-027 13. API Number / 50- 029-20498-60-00 14. Well Name and Number: PBU 17-04AL 1 ./ 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028334 17. Land Use Permit: GAs-McF WATER-BBL 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 'xueÍNG REC<)RD .. DEPTH SET (MD) 10745' PACKER SET (MO) 10690' ~<t~ 4'" CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~ 0..4 200~ RECEIVED None R8DMS BFL. 0 R , G \ N A L APR 2 9 2004 Alaska Oil & Gas Cons. CommiStion f.9 r-- Anchorage 27. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ ~ 28. GEOLOGIC MARKERS 29. FORMATION TeSTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 11148' 11210' 8935' None Shublik 8962' Shublik 11300' . 8974' RECEIVED APR 2 9 2004 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the fore~is true and correct to the best of my knowledge. Signed sondrà~~Title Technical Assistant Date CJ..+ ~OC} -CYf PBU 17-O4AL 1 196-051 304-027 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Dave Wesley, 564-5153 Permit No. / Approval No. 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). ITEMS: 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, 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 1 0-407 Revised 12/2003 v.\luil\JI-\L r"\ ~ Well: Field: API: Permit: 17-04B Prudhoe Bay Unit 50-029-20498-02-00 204-023 Accept: Spud: Release: Ri~: 02/24/04 03/01/04 03/13/04 Nabors 7ES " ,', ------- PRE-RIG WORK 01/19/04 T/I/O 300/1430/300. MIT OA TO 2000 PSI. PASSED (RIG ST DIAGNOSTICS). (WELL FLOWING) LOADED AND PRESSURED UP OA WI 5.8 BBLS CRUDE. START TEST (300/1430/2000), 1 ST TEST LOST 120 PSI. IN 15 MINS, (300/1430/1880), FAIL. REPRESSURED OA. START 2ND TEST, (300/1430/2000), 1ST 15 MINS LOST 50 PSI IN 15 MINS (300/1430/1950), AND 2ND 15 MINS LOST 10 PSI, (300/1430/1940), FOR A TOTAL OF 60 PSI ON 30 MINS., PASS, BLEED OA, RDMOL FINAL WHP'S 300/1430/450. 02104/04 RAN FLAPPER CHECKER TO SSSV (FLAPPER FULLY OPEN). DRIFTED WI 2.50 CENT, TEL & SAMPLE BAILER. LOC TT @ 10,734' SLM + 11' CORR= 10, 745' MD. DRIFTED TO TOP OF MILLOUT WINDOW @ 11,150' SLM -11,161' CORR MD (NO SAMPLE). 02106/04 MIRU UNIT. LOAD IA WITH 1%KCL AND FP TO 2000'. 02107/04 RIH WITH 2.5" CEMENTING NOZZLE. FLUID PACK WELL WITH 1% KCL. MIXI PUMP 80 BBLS 15.8PPG G CEMENT.SAW WHP OF 300 PSI, OPEN CK, HOLD 150 PSI BACK PRESSURE. PUH TO SAFETY AT 8827'. ESTTOC AT 11100', WOC AND ORDER MORE CEMENT, MIx/PUMP 37 BBLS 15.8PPG G CMT PUH LAYING IN CMT, UNABLE TO OBTAIN 1:1 RETURNS.PARK AT SAFETY 9350', ORDER MORE CEMENT. TEST CMT TO 610 PSI HOLDING 360 PSI. DISPLACE COIL AND BS TO DIESEL. MIX AND PUMP 36 BBLS CLASS G CEMENT AT 15.8 PPG. 02108104 ATTEMPT TO HOLD SQUEEZE PRESSURE OF 250 FOR 1 HOUR. UNABLE TO GET 1:1 RETURNS. DROP BALL AND CHASE WITH XSKCL. CLEAN OUT TO 8000. RETURNS ARE GAS CUT AT THIS POINT. CHASE OUT OF HOLE AT 30%. FREEZE PROTECT WELL TO 2500 WITH 60/40 MEOH. THAW FLOWLINE AND SURFACE LINES. SEARCH FOR AND FIND BALL. 02109/04 RIH WITH 2.5. BS NOZZLE. TAG UP AT 2097'. PARTIALLY PLUG NOZZLE. POH. SURFACE LINES FROZEN. THAW ALL SURFACE LINES AND FREEZE PROTECT. MU I RIH WITH 2.70" DJN. TAG AT 8573 CTMD. PRESSURE TEST TO 2000. INITIAL RAMP TOOK 0.6BBLS TO PRESSURE UP FROM 277 TO 2000. LOST 120 PSI IN 5 MINUTES. CLOSE CHOKE ALONG WITH WING. TOOK 0.1 BBL TO REPRESSURE TO 2000. LOST 31 PSI IN 7 MINUTES. GOOD PLUG. POH CONTINUING TO CIRC MEOH DOWN FLOWLINE. STOP AT 2500 AND POH AT 80% FREEZE PROTECTING TUBING WITH 60/40 MEOH. 02110/04 RDMO. NOTIFY DSO THAT WELL REMAINS SI FOR SIDETRACK. 02113/04 DRIFT TO 10,110 (SLM) W 12.70" CENTRALIZER & SAMPLE BAILER, CEMENT FOUND IN SAMPLE BAILER. 02114/04 CHEMICAL CUT 3.1/2" TUBING AT 7525' MD. CORRELATED TO GLM #3 ON TUBING DETAIL 4/25/96. RIH W/CCUSMALL CHARGE TUBING PUNCHER (20' X 2"). PERF AT 7500' . 7502'. RIH W/CCUSINGLE STRAND STRING SHOT (27' X 1.69"). SHOT AT 7514' - 7526'. RIH WIWEIGHT/JARS/CCU2.625. ANCHOR BODY AND CHC HEAD (28.6' X 2.625"). GOOD INDICATION. DID NOT TAG TO. LEAVE WELL SHUT IN. ~ 17-04B, Sidetrack Pre-Rig Woo Page 2 ~ 02116/04 T/I/O=100/950/200 CIRC-OUT WEll AND CMIT TBG X IA TO 3000 PSI (PASSED). PUMPED 10 BBlS NEAT, 703 BBLS SEA WATER, AND 160 BBlS DIESEL DOWN TBG TAKING RETURNS FROM IA TO FLOWLINE. FREEZE PROTECTED FLOWLINE W/5 BBlS NEAT AND 3 BBlS DIESEL. U-TUBED TBG X IA FOR ONE HOUR. CMIT TBG X IA TO 3000 PSI. PASSED ON 2ND TEST, FIRST 15 MIN LOSSES=40/40 AND SECOND 15 MINUTES LOSSES=20/20 FOR TOTAL OF 60 PSI ON BOTH TBG AND IA IN 30 MINUTES. BLED PRESSURES TO 0 PSI ON TBG AND IA. BLED OA PRESSURE FOR A ADDITIONAL 1/2 HOUR AND IT WOULDN'T DROP BELOW 150 PSI. FINAL WHP=010/150. 02120/04 SET HOLD OPEN SLV @ 2192 SLM, BLED T-IAlOA TO 0 PSI. ~ ~ Page 1 .. BP EXPLORA TlqN Op~rations Summary R~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-04 17-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Date From - Tò ' Hours. Task CÓdEr NPT Pha$e " .. ,> 2/21/2004 00:00 - 06:00 6.00 MOB N PRE 06:00 - 11 :30 5.50 MOB N PRE 11:30-12:30 1.00 MOB P PRE 12:30 - 18:30 6.00 MOB P PRE 18:30 - 19:00 0.50 MOB P PRE 19:00 - 00:00 5.00 MOB N RREP PRE 2/22/2004 00:00 - 05:00 5.00 MOB N RREP PRE 05:00 - 12:00 7.00 MOB N RREP PRE 12:00 - 22:30 10.50 MOB N RREP PRE 22:30 - 00:00 1.50 MOB N RREP PRE 00:00 - 20:00 20.00 MOB N RREP PRE 20:00 - 22:30 2.50 MOB P PRE 22:30 - 00:00 1.50 MOB P PRE 00:00 - 02:00 2.00 MOB P PRE 02:00 - 04:30 2.50 WHSUB P DECOMP 2/23/2004 2/24/2004 04:30 - 05:30 05:30 - 08:30 08:30 - 13:00 1.00 WHSUB P 3.00 WHSUB N 4.50 WHSUB P DECOMP WAIT DECOMP DECOMP 13:00 - 13:30 0.50 WHSUB P DECOMP 13:30 - 16:30 3.00 WHSUB P DECOMP Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 , Description of Operations Waiting on the Wells Group to release DS 17-04 to drilling. VECO removed the well house & flow line. Well tumed over to Drilling @ 06:00 Hrs. Perfonn general rig maintenance & rig down as much as posible while waiting on VECO. Tool Service shot grade on pad & leveled same. Disconnect Pit Module from Sub Base. Move Pits ahead 5' to Clear Sub. Prepared to Move Rig. Move Sub off DS 17-07. Drive rig to other side of Pad. Set matting boards & spread Herculite over area. Start backing Sub Base into position & line up with the DS 17-04 well. At +/- 18:45 hrs the rig was about 30' from being in position over the well when the hydraulic lift cylinder rod (Forward drivers side) broke off at the base plate that is attached to the Main Drive Axle Assembly. No one was injuried & there was no environmental damage. Note: After perfonning inspection on the Drive Axle Assembly there was minimum damage to the surrounding rig equipment. Nabors consulting with their Anchorage office & the manufacture of the Drive Axle "Columbia Corp" on most expedient course of action to take in repairing the rig. The plan is to reposition the Drive Axle to the lift cylinder in their original position & weld the cylinder rod to the base plate. Then move the rig over the well. Spot same & rig up for drilling operations. While the well is being drilled Nabors will replace the Drive Axle Assembly. Currently the Rig Welder is grinding the damaged part on the cylinder rod & base plate in preparation for welding. Repair Rig. Welder grinding the damaged part on the cylinder rod & base plate in preparation for welding. Rig up chain hoist & related equipment to help reposition Drive Axle under hydraulic lift cylinder. Align Drive Axle to lift cylinder. Start welding front DS lift cylinder to Drive Axle base plate. Repair Rig by welding front DS lift cylinder to Drive Axle base plate. After welding let cool to the touch. Back Sub over Well 17-04. Spot Sub. Center and level Rig. Spot Pit Complex & level same. Hook up all lines between sub & pit complex. Prepared to take on seawater. Move & spot camp. ACCEPT RIG @ 02:00 HRS 2/24/2004. Take on Seawater. RIU Lines to Tree Flowline valve and 3-112" x 9-5/8" Annulus to Choke Manifold in Preparation to displace diesel from wellbore. Checked 3-1/2" Tubing x 95/8" Annulus - static. RlU DSM Lubricator & pull BPV. RID Lubricator. Load of Seawater Halted by Security at Sag Bridge. PJSM. Pressure test Lines to 3500 psi. Pump 28 Bbls Seawater down IA @ 3 BPM & 350 psi to clear Diesel from Tubing. Switch & Pump seawater down tubig to Clear Diesel from IA. Displace wellbore fluid to tubig Cut @ 7525'. With heated Seawater @ 4 BPM I 520 psi. Shut down Pumps & observe well. Out of balance. U - Tube for 20 minutes - Still not balanced fluid. Pump Seawater around to Clean Out wellbore, Tubing & balance. Pump @ 4 BPM I 520 psi. Printed: 3/1512004 10:15:17 AM ~ ~ Page 2 ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/24/2004 2/25/2004 2/26/2004 17-04 17-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES From - To Hours Task Code NPT Phase 16:30 - 17:30 1.00 WHSUB P DECOMP 17:30 - 19:30 2.00 WHSUB P DECOMP 19:30 - 00:00 4.50 BOPSUF P DECOMP 00:00 - 07:00 7.00 BOPSUF P DECOMP 07:00 - 09:30 2.50 BOPSUF P DECOMP 09:30 - 10:00 0.50 FISH P DECOMP 10:00 - 16:00 6.00 FISH N DFAL DECOMP 16:00 - 17:30 17:30 - 21:30 1.50 FISH 4.00 FISH N N DFAL DECOMP DFAL DECOMP 21:30 - 00:00 DFAL DECOMP 2.50 FISH N 00:00 - 02:00 N DFAL DECOMP 2.00 FISH 02:00 - 05:00 3.00 FISH N DFAL DECOMP 05:00 - 06:00 1.00 FISH N DFAL DECOMP 06:00 - 16:00 10.00 FISH N DFAL DECOMP 16:00 - 23:00 7.00 FISH N DFAL DECOMP Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 Description of Operations Set BPV & Test from Below to 1000 psi. N/D Tree & Adapter Flange. Inspect Hanger & threads. Integral hanger & Good Threads. N/U 135/8" BOP & Assc. Equipment. Set Blanking Plug into BPV. Fill stack & RlU To Test. Test Bind rams to to 250 psi. Low & 3500 psi. High. Pull Blanking Plug & run Test Jt. Test Remainder of BOPE to Same 250 psi Low & 3500 psi High. RlU DSM Lubricator. Pull BPV. RID DSM. P/U 5 1/2" Landing Jt., Screw into Hanger. B.OLD.S. Pull Hanger off seat wI 95K. Pull up to 190K. Tubing not Parted. Work pipe in attempt to pull free. No Success. Change out to long bails in preparation for SWS E-Line wI Chemical Cut. PJSM wI SWS. RlU E-Line. RIH wI String Shot. Correlate wI CCL. Pull 150K on Tubing string & Shoot String Shot - 7,506' to 7,520' No Surface indication of Shot. Release tension on Tubing. POH & UD String Shot ( Had Fired). MIU 2 1/8" Extended Reach Chemical Cutter. RIH, Correlate to Tubing Collar and Set Cutter @ 7,514'. Pull 150K Tension on Tubing & Fire Chemical Cutter. Observed 5K loss of Weight on Tubing. Work pipe up to 190K. Pipe not Free. Land tubing & POH wI Chemical Cutter. POH wI Chemical Cutter & UD Same. Chemical Cutter came out with SSSV Sleeve Attached. RID SWS - leave Sheaves up for run wI Jet Cutter after Slick Line. Work Tubing while waiting on Slick Line Unit. Attempted to work 2600 fUlbs Torque down to cut. Pulled up to 2ooK. No Success. PJSM with HES Slick Line Crew. RlU Slick line to safe Out Camco SSSV Flapper. Make Following Runs: 1. Flapper checker - Flapper Closed 2. Z-5 Lock-out Tool - Spang off Tool 3. 2.7" Blind Box - Beat down for 45 minutes. 4. 3" JDC WI Z-5 Core - Latch & Pull Z-5 Tool 5. Flapper Checker - Flapper still closed. Decided to make one more attempt to lock out SSSV Flapper with additional weight bars to beat down. Doug Varble, Wells Group Wire Line Supv., on Site supervising HES Slick Line Crew. Make the following runs: 1. Z-S Lock-out Tool- Spang off Tool 2.2.7" Blind Box with added wt. bars - Beat down for 90 minutes. 3. 3" JOC WI Z-5 Core - Latch & Pull Z-5 Tool 4. Flapper Checker -Indicates Flapper Open. 5.2.80 Drift - went through SSSV @ 2219 RIH to 2260' POH- Successfully Locked out SSSV Flapper Valve. RID HES Slick Line. Printed: 3/1512004 10:15:17 AM /"'.. ~ BP EXPLORATION Operations Summary Report Page 3 ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-04 17-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 Date FrolÌ1- To' 'Hours Task Code NPT ,Phase, Qescription of Operations 2/2612004 16:00 - 23:00 7.00 FISH N DFAL DECOMP 23:00 - 00:00 1.00 FISH N DFAL DECOMP PJSM wI SWS Crew on 2.6S" Jet Cutter Run. RIU to run Jet Cutter. 2/27/2004 00:00 - 02:00 2.00 FISH N DFAL DECOMP RIH w/2.6S" Jet Cutter. Correlate collars & position Cutter @ 7500' 02:00 - 02:30 0.50 FISH N DFAL DECOMP Latch onto Landing jt & P/U wI 150K on Weight Indicator Fire Jet Cutter - No Indication on String Wt. - Pull up to 2ooK - Tubing not Free. 02:30 - 03:30 1.00 FISH N DFAl DECOMP POH wI Jet Cutter. Confirm jet Cutter has Fired. UD Tools. 03:30 - 06:30 3.00 FISH N DFAl DECOMP Screw in with Top Drive & Circulate down tubing. Stage up to 250 GPM @ 575 psi. - Packed Off. shut down pumps, pressure bled off. Regained cirulation & staged up to 480 GPM @ 1970 psi. Continue working pipe with no success - tubing not free. Contaminated Cement (10.5 Ph.) to Surface on Bottoms Up. Pack -off was due to position of 13 3/S" OD Tubing Hanger in 13 5/8" ID BOP Stack. 06:30 - OS:OO 1.50 FISH N DFAL DECOMP PJSM wI SWS. MIU & RIH wI Free Point Tool. 08:00-11:00 3.00 FISH N DFAl DECOMP Free Point Tool failed. POH. Found Moisture in E-Line. Cut Line & Re-Head. 11:00-14:30 3.50 FISH N DFAL DECOMP RIH wI Free Point Tool and take Stretch Readings at various depths. 100 % Stuck @ 7221'. 93% Free @ 7004' 14:30 - 18:30 4.00 FISH N DFAL DECOMP MIU 2.68" Jet Cutter & RIH. Correlate & position cutter @ 6950'. Attempt to Fire Cutter. No Success - Misfire. POH 18:30 - 21:30 3.00 FISH N DFAl DECOMP Run diagnostic checks. Found Electrical Short in CCL. Repaired Same & RIH. Postion tool @ 6,950' latch on to landing Jt & pull 150K tension. Fire tool. Surface indication of success. lost 30K. Pulled up 10 Ft wI 20 to 30K drag. POH wI Cutter - Tool fired. 21:30 - 23:00 1.50 FISH P DECOMP Pull Hanger above Rotary. Drag 10 to 20K. Circulate, staging up to 480 GPM @ 1300 psi. Considerable amount of Contaminated Cement over Shakers. Work pipe - Completely Free 23:00 - 00:00 1.00 FISH P DECOMP RlU Tongs & control line spooler. UD Landing Jt. & Hanger. 2/28/2004 00:00 - 01:00 1.00 PULL P DECOMP Blow down Top Drive cIa to Short Bails. 01:00-11:00 10.00 PULL P DECOMP POH w/3 1/2", 9.2#, l-80, TDS Tubing Completion String, UD 220 Jts + 20' Cut-off, Jewelry & Spool Control Line. All Tubing & Jewelry N.O.R.M. Tested. Item Radioactvity = 0 to 3 uREM I hr. Tubing Hanger = 1 to 3 uRem I hr. 11:00-11:30 0.50 PUll P DECOMP RID Tubing Equipment & Clear Rig Roor. 11:30 - 12:00 0.50 CLEAN P DECOMP MIU Wear Bushing on Running Tool & Install Same. 12:00 - 14:30 2.50 CLEAN P DECOMP load rig floor wI cIa BHA. MIU Same + 9 DC's & 20 Jts, 5" HWDP. RIH. 14:30 - 17:00 2.50 CLEAN P DECOMP P/U & RIH wI 75 Jts, 5" DP from Shed. 17:00 - 19:00 2.00 CLEAN P DECOMP Continue RIH with Stands of 5" DP from Derrick. Take Weight @ 6,612'. 19:00 - 20:00 1.00 CLEAN P DECOMP Wash & Ream from 6,612' to Tubing Stub @ 6,955' (DP Measurement) 500 GPM @ 860 psi & 80 RPM. Reaming through numerous stringers taking up to 10K. 20:00.21:30 1.50 CLEAN P DECOMP Circulate 50 Bbl. Hi - Vis Sweep, Considerable amount of Cement over Shakers throughout Circulation. Rotating @ 110 RPM - 550 GPM @ 980 psi. Casing Clean. Pump Slug. Printed' 311512004 10'15:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ,,-..... "" Page 4" BP EXPLORATION Operations Summary Report 17-04 17-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES From - To Hours Phase 2/28/2004 21 :30 - 22:15 22:15 - 00:00 2/29/2004 00:00 - 03:00 03:00 - 04:30 04:30 - 10:00 10:00 - 11:00 11:00 - 13:00 13:00 - 17:00 17:00 - 17:30 17:30 - 18:45 18:45 - 21:45 21 :45 - 22:45 22:45 - 23:45 3/1/2004 23:45 - 00:00 00:00 - 03:30 03:30 - 06:00 06:00 . 07:30 07:30 - 08:30 08:30 - 10:30 10:30 - 14:30 14:30 - 15:30 15:30-16:30 lti:30 - 00:00 Task Code NPT 0.75 CLEAN P 1.75 CLEAN N DECOMP RREP DECOMP 3.00 CLEAN P 1.50 CLEAN P 5.50 DHB P DECOMP DECOMP DECOMP 1.00 DHB P DECOMP 2.00 STWHIP P 4.00 STWHIP P 0.50 STWHIP P 1.25 STWHIP P WEXIT WEXIT WEXIT WEXIT 3.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 0.25 STWHIP P 3.50 STWHIP P 2.50 STWHIP P 1.50 BOPSUF P WEXIT WEXIT WEXIT WEXIT 1.00 STWHIP P 2.00 STWHIP P WEXIT WEXIT 4.00 STWHIP P WEXIT 1.00 STWHIP P 1.00 STWHIP P WEXIT WEXIT 7.50 DHILL INr1 P Start: 2/24/2004 Rig Release: 3/13/2004 Rig Number: Spud Date: 8/28/1980 End: 3/13/2004 Description of Operations POH Standing back 5' DP. Iron Roughneck Failed. Repair Iron Roughneck. Gland packing on Clamp Cylinder loose - Tighten Same. POH Standing back 5' DP. Stand back 5' HWDP & DC's. UD Mills. PJSM wI SWS,HES & Crew. R/U SWS. M/U SWS CCL & HES EZ-DRILL Bridge Plug. RIH, Correlate wI GR & Set EZ DRILL BP @ 6,856'. R/U & Test 9 5/8' Casing to 3500 psi. Hold & Chart for 30 Minutes. RID P/U & M/U Whipstock BHA. RIH wI Whipstock BHA on 5' DP to 6815' Orient to 81 Degrees & Set Whipstock. Displace seawater with 9.7 ppg LSND Mud. 480 GPM @ 1800 psi. Cut Window in 9 5/8' Casing from 6,829' to 6,845'. Mill additional Hole for FIT to 6,858'. 480 GPM @ 1850 psi. Pump Hi Vis Sweeps as needed. Work Assembly through Window while circulating final Hi Vis Sweep. Recovered 256 Ibs of Metal Cuttings. Perform FIT. Mud Weight = 9.7 ppg. MD = 6829' TVD = 6267' Surface Pressure = 926 psi. FIT = 12.54 EMW RID from FIT & Pump Slug POH Standing Back 5' DP. UDWhipstock BHA: DC's, Mills & MWD. Pull Wear Bushing, M/U Jetting Tool on Stand of 5' DP. Function & Clean Out BOP. Install Wear bushing. Service Top Drive, Blocks & Crown. Held PJSM. M I U 8-1/2' Directional BHA: 8-1/2' Smith MGR75HPX PDC Bit Ser# JP3797 dressed w/7 x 13 Jets - 6-3/4' 5.0 Stg XP Mud Motor wI 1.15 deg Bend - 8' Stabilizer- CDR Assembly - MWD Assembly - 8-1/2' Stabilizer - 3 x 6-3/4' Flex Collars - XO - Jars - 20 Jts 5' HWDP . 8 1/2' Ghost Reamer - XO. Total BHA Length: 819.87'. Oriented Motor to MWD. Pulsed Tested MWD, OK. RIH, Picking Up & Rabbiting, 99 Jts of 4' DP from Shed. Change Out Elevators & Slips for 5' DP. RIH wI 5' DP from Derrick to 6,618'. M / U Top Drive, Established Parameters: String Weight Up 155,000#, String Weight Down 140,000#, Pump Rate 560 gpm, 1550 psi, ECD 10.4 ppg. Oriented Tools 80 Degrees, Shut Down Pumps, RIH Through Window. Re-Engaged Pumps, Washed Down as Precaution from 6,848' to 6,858'. Pump Rate 500 gpm, 1,420 psi. Drilled 8.1/2' Directional Hole by Rotating and Sliding fro 6,858' to 7,289'. WOB Sliding 12,000# - B Rotating 10,000#' 18, 0, Motor RPM 157, Torque 0 ,Oft / Ibs - On Bottom 7,000 ft Ilbs, pRate 570 gpm, SPP Off Bottom 1,980 psi, On Bottom 2,275 psi. String Weight Up 155,000#, String Weight Down 140,000#, String Weight Rotating 145,000#. Calculated ECD 10.42 ppg PWD ECD 10.65 ppg. Pumping 30 bbl Hi-Vis Printed: 3/1512004 10:15'17 AM " WGA- 'I ¿ '1/1-00<1 f STATE OF ALASKA (' 07=3 (/2-C¡;/~ ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: 181 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter Casing 0 Repair Well 181 Plug Perforations 0 Stimulate 0 Time Extension - 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 1m Development 0 Exploratory 196-051./ 3. Address: 0 Stratigraphic Test 0 Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20498-60-00 7. KB Elevation (ft): KBE = 69 78' 9. Well Name and Number: / . PBU 17-04AL 1 ~ 8. Property Designation: 10. Field / Pool(s): ADL 028334 Prudhoe Bay Field / Prudhoe Bay Pool 11. """ ',,",": "'"',, ,', e~çSENTWEI-LC;ONDITIQN$l,JMM,A.BY,'; '"',, ""'.,",', ',,",,' '" Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12894 8994 12894 8994 None None Casing '",',",'"',..',.','",, LeÒQth, , """""""."""," ~i"'ð .","" <, I<,>u~,< "",,' I: ,,' ",':,',"or\lt'\"""'i)'iii,,' :", "O~¡à~,i.,.',:.'."',,',.:: , CÞI18n!::/:>',' i """"','.'""., Structural CUIIUULLL r 110' 20" 110' 110' 1530 520 Surface 2606' 13-3/8" 2606' 2606' 5380 2670 L,~ . ,~ 7745' 9-5/8" 7745' 6878' 6870 4750 Production Liner 3764' 7" 7547' - 11160' 6744' - 8940' Liner 1711' 4-1/2" 11183' - 12894' 8951'- 8994' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 11202' - 12871' 8959' - 8993' 3-1/2",9.2# L-80 10745' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer; 3-1/2" Cameo TRDP-1A' Packers and SSSV MD (ft): 10690' TRSV 2210' 12. Attachments: 13. Well Class after proposed work: 1m Des~ription Su~mary of Proposal 0 BOP Sketch 0 Exploratory 1m Development 0 Service 0 Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 5, 2004 0 Oil 0 Gas 0 Plugged 1m Abandoned 16. Verbal Approval: Date: 0 WAG 0 GINJ 0 WINJ 0 WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name Bill Isaacson Title Senior Drilling Engineer Prepared By Name/Number: Signature l-.....L.. ."''' Phone 564-5521 Date L I l.11 0"" Terrie Hubble, 564-4628 1«; ."", ,ii. ""',,, ,,' ""', """ "ii':"">" ':" , i,.'"t""/"";""i' :,i,' '" '""",, ,."""",,' ,",' ,'i ",".': ","',' ", ',' " ¡.., .', ',,:'i, " :. ,}, ,,' ,. , , ,,':' :,' ""'?""",,: """,'", ,"" ,"" ':"",/ i ,::,,"', ,..'i:, ",: ','i' ", ",..,"", " " ' "'..:,', '" I Sundry Number: ~o '-/- ð.;:> 7 Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance R E C E '\/E [) Other:oTe.<;t ~O PE .1' Ç-OD y?~c:', JAN 282004 l6jl r --' Alaska Oil 81 Gas Cons. Cornm¡t~~¡on Subsequ nt form qui e 10- D 1 Anchorage Approveo '"' /;~~(;~~E[; fEB {i 2 2~g~MISSIONER ~~~~g~~~~ION Date ~ ~O / t4- Form 10"4~ViS~ "- 0 RIG I N A L _LiI"I. FÔb~r¿n 2"~cate ( ~t bp <:> To: Winton Aubert - AOGCC Date: January 22,2004 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling / Subject: 17 -04A & AL 1 Application for Sundry Approval - P&A for Sidetrack Operations Reference: API # 50-029-20596-00 Approval is requested for the proposed P&A of PBU well 17 -04A & AL 1. DS 17-04 was originally completed in October, 1980 as a Sag producer, but did not flow. It was SI until March, 1988 when a RWO to pull what was thought to be collapsed tubing was done, but found no collapsed tubing. The well was re- completed in Z4, but production rates were still less than 100 BOPD at 95% WC. The well remained 81 because an asphaltene emulsion was suspected of causing upsets in process equipment. The well was sidetracked in March 1996 with a 1500' horizontal section drilled in Z4, and a 1700' lateral drilled into the Sag River. An isolation packer was set between the two so that contributions from each lateral could be determined. Initial production averaged about 380 bOpd, with a total fluid production of 1200 bId. Tests before and after a plug set in the isolation packer showed no difference in rates indicating communication between Sag and Z4. Geochemical analysis suggested the Sag River was not contributing any production. Logs in the Ivishak section showed high water saturations through most of the upper section until the wellbore dipped into the HOT at about -9000' SS. Current production is about 100 BOPD, and 500 BWPD. Cumulative production is 555 MBO. The 17 -04B sidetrack is scheduled for Nabors rig 7ES. Current estimates have it beginning around February 21, 2004, following the completion of the 17-07 A sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. SCODe Notify the field AOGCC representative with intent to plug and abandon Pre-Ria Ooerations: 1. RIH with Coil Tubing. Plug & abandon, with 15.8ppg class 'G' cement, both the 17-04A and 17-04AL 1 well bores. Place cement by reciprocating coil above the Sag River lateral window and bull-heading cement from that point. Continue pumping until pressure bumps to -1,OOOpsi. Pump sufficient cement to fill both the A and AL 1 well bores, plus squeeze approximately 1 Obbls, an~"ye the cement top up in the tubing tail at -10,650'md. The estimated volume of cement required i 80 Is. 2. RIU slick-line. Drift the 3 %" tubing to confirm top of cement, following P&A. só, to confirm the tubing is clear to the required cut depth of -7,525' md. 3. Fluid-pack the 3 %" tubing and 9 5/8" x 3 %" annulus to surface. Test to 3,000 psi. 4. RIU E-line. RIH with the appropriate chemical cutter and cut the 3 %", 9.2#, L-80 tubing at -7,525' md. 5. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. LiJ6' Test, the 9' 5/8" pack-off and tubing hanger seals to 5.000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 7. Bleed casing and annulus pressures to zero. 8. Set a BPV. Secure the well. Level the pad as necessary. 'r~ s 10- L/"5 "1?fyo..(~ (. 17 -04A & AL 1 Application for Sundry , ( ( Ria ODerations: 1. Mil RU Nabors rig 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Set BPV. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. 4. RlU. PuIl3~" tubing from the cut at -7,525' MD and above. 5. RlU E-line. M/U 8.5" gauge ring I junk basket I CCL. RIH and tag tubing stump at -7,525'. POOH. 6. RIH with HES EZSVon E-line. Set bridge plug at -7,470', and as required to avoid cutting a casing collar while milling the window. POOH. RID E-line. 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record test. 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 9.7ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9 5/8" casing at :f: 7,450' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5ppg EMW. POOH. 12. M/U 8 %" Dir/GRlPWD assembly. RIH, kick off and drill the 8 1/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 14. M/U 6 1/8" Dir/GRlRes/AIM assembly. RIH to the landing collar. 15. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.5ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 10.0ppg EMW. Drill ahead to TD per directional proposal. 19. Circulate well bore clean, short trip to shoe, circulate. POOH. 20. Run a 4 ~", 12.6#, L-80 slotted production liner. POOH. 21. RlU and run a 4 1/2", 12.6#, 13Cr-80 tubing completion, stinging into the 4 1/2" liner tie back sleeve. 22. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 23. Set a BPV. 24. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 25. Freeze protect the well to -2,200'. Secure the well. 26. Rig down and move off. Post-Ria ODerations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 1. Install well house and instrumentation. Estimated Pre-rig Start Date: 02105/04 Estimated Spud Date: 02/21/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 17 -04A & AL 1 Application for Sundry J TREE': 5-1/16" CNV" I WELLHEAD = . FMC ( J SAFETY NOTES: WELL ANGLE> 70 deg @ ACTUATOR = AXELSON 17 -04A & AL 1 11350'&>90deg@11648'. KB. ELEV = 69.78' BF. ELEV = NA KOP = 4250' -i 5-1/2" X 3-1/2" XO, ID = 2.992" I Max Angle = 91 @ 11711' -13-1/2" CAMCO TRDP-1A TRSV, ID = 2.812" I Datum MO = 11003' Datum lVO = 8800' SS GAS LIFT MANDRB.S ST MO lVO OEV lYPE VLV LTCH PORT DATE 113-5/8" CSG, 72#, L-80, ID = 12.347" I 1 3405 3405 1 MMG DOME RK 16 05/17/96 2 4693 4675 17 MMG OV RK 0 05/17/96 3 6271 5905 50 MMG DOME RK 16 05/17/96 4 7765 6892 48 MMG OV RK 0 05/17/96 5 9198 7806 56 MMG OV RK 0 05/01196 6 10112 8396 53 MMG SO RK 24 05/17/96 --t 9-5/8" X 7" BKR ZXP PKR, 10 = 6.310" 1 I 9-5/8" CSG, 47#, L-80, 10 = 8.681"1-i 7700' r- -I 9-5/8" X 7" BKR HMC HGR, ID = 6.200" I Minimum ID = 2.750" @ 11187' 3-1/2" HES XN NIPPLE 13-1/2" TBG, 9.2#, L-80, .0087 bpf, 10 = 2.992" 1 10744' 3-1/2" HES X NIP, 10 = 2.813" I 3-1/2" WLEG, 10 = 2.992" I 7" LNRMILLOUTWINDOW, 11161'-11172' (17-04AL1) *TOL 10' OUT OF WINDOW. * OÆN HOLE TO 11183'. PERFORA TION SUMMARY RB= LOG: BHes ON 09/30/80 I ANGLEATTOPÆRF: 63 @ 11202' Note: Refer to A-oduction DB for historical perf data .... .... , SIZE SPF INTERV AL Opn/Sqz OA TE .... , .... 4-1/2" SL TO 11202 - 12871 0 05/01/96 ~"" 4-1/2" SL TO 11399 - 11927 0 05/01/96 '''''''''''''''''''''''''' 4-1/2" SLTO 11929-12814 0 05/01/96 """"'.... ""...., .... .... ........ ""'.... I BTM OF 4 1/2" SL TO LNRI .... .... .... 14 1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1 -I 7" X 4-1/2" BKR ML PKR, ID = 2.937" I -I 3-1/2" HES XN NIP, 10 = 2.750" I 3-1/2"TTP,9.20#,L-80,.0087bpf, 10=2.992" I 11194' -1 I 3-1/2" WLEG, 10 = 2.992" -I 7" X 4-1/2" TIW SS HORIZ. PKR, 10 = 3.918" I 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" I -I BTM OF 4 1/2" SL TO LNF 1 TOP OF 4 1/2" SLOTTED LNR, 10 = 3.958" l-i 11399' I 14 1/2" SLOTTED LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" I OA TE REV BY COMMEf\ITS OA TE REV BY COMMENTS PRUDHOE BAY UNIT 10/13/80 ORIGINAL COMA-ErION 01/09/02 GCJKAK SLOTTED LNR CORRECTION WELL: 17-04A / AL 1 03/19/88 RWO 01/16/04 dew Slotted liner correction PERMIT No: 196-0500 & 196-0510 05/01/96 RIG SIDETRACK API No: 50-029-20498-01 02/27/01 SIS-LG FINAL 2795' FSL & 4830' F8., Sec. 22, TION, R15E 11/09/01 CH'tlh CORRECTIONS BP Exploration (Alaska) .J ~ = 5-1/16" ewv I í: W8..LHEAD= FMC 17 4A & AL1 Pre RI"' 9 SAFETYNOTES:W8..LANGLE>70deg@ ACTUATOR = AX8..S0N - 11350' & > 90 deg @ 11648'. KB. 8..EV = 69.78' BF. B.EV = NA -15-1/2" X 3-112" XO. 10 = 2.992" I KOP = 4250' Max Angle = 91 @ 11711' -i 3-1/2" CAMCO TRDP-1 A TRSV, ID = 2.812" I Datum MD = 11003' GAS LIFT MANDRELS Datum lVD = 8800' SS 5T MD lV D DEV 1Y Æ VL V L TCH PORT DA TE 1 3405 3405 1 ~ OOME RK 16 05/17/96 113-5/8" CSG, 72#, L-80, 10 = 12.347" I" 2606' 1 2 4693 4675 17 ~ DV RK 0 05/17/96 3 6271 5905 50 M\1G OOME RK 16 05/17/96 4 7765 6892 48 M\1G DV RK 0 05/17/96 I Pre rig E-line chemical cut l-i -7,525' I 5 9198 7806 56 MMG DV RK 0 05/01/96 6 10112 8396 53 M\1G SO RK 24 05/17/96 -i 9-5/8" X 7" BKR ZXP PKR, ID = 6.310" 1 9-5/8" CSG, 47#, L-80, ID = 8.681"1-i 7700' r- -i I 9-5/8" X 7" BKR HMC HGR, ID = 6.200" Minimum ID = 2.750" @ 11187' 3-1/2" HES XN NIPPLE 7" X 4-1/2" BKR 5-3 PKR. 10 = 3.875" I 1 Pre rig coiled tubing cement P&A l-i -10,650' 1 13-112" TBG, 9.2#, L-80, .0087 bpf. ID = 2.992" I 10744' 3-1/2" HES X NIP, ID = 2.813" I 3-1/2" WLEG, Ð = 2.992" 1 PERFORA TION SUMMARY REF LOG: BHCS ON 09/30/80 1 ANGLE AT TOP PERF: 63 @ 11202' Note: Refer to A'oduction DB for historical perf data SIZE SPF MERVAL Opn/Sqz DATE 4-1/2" SLTD 11202 - 12871 0 05/01/96 4-1/2" SL TD 11399 - 11927 0 05/01/96 4-1/2" SL TD 11929 - 12814 0 05/01/96 .. .. ~. . .. " ,:~j" ..¡. .'"' '~." 1 BTM OF 4 1/2" SL TD LNR . 'f" ;,< ~. 141/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" I . .~~ ~;4 . -i 7" X 4-1/2" BKR ML PKR, 10 = 2.937" 1 -i 3-1/2" HES XN NIP, 10 = 2.750" 1 13-112" TIP, 9.20#, L-80, .0087 bpf, 10 = 2.992" I 11194' ., I 3-1/2" WLEG, 10 = 2.992" -i 7" X 4-1/2" TWV SS HORIZ. PKR, 10 = 3.918" 1 I 7" LNR, 26#, L-80, .0383 bpf. 10 = 6.276" 1 BTM OF 4 1/2" SL TO LNR ' TOP OF 41/2" SLOTTED LNR, ID = 3.958" l-f 11399' 1 141/2" SLOTTED LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I OA TE REV BY COMMENTS OA TE REV BY COMMENTS PRUDHOE BA Y UNrr 10/13/80 ORIGINAL COMPLETION 01109/02 GCJKAK SLOTTED LNR CORRECTION W8..L: 17-04A / AL1 03/19/88 RoNO 01/21/04 D8N A"oposed A'e rig work PERMIT" No: 196-0500 & 196-0510 05/01/96 RIG SIDETRACK API No: 50-029-20498-01 02/27/01 SIS-LG FNAL 2795' FSL & 4830' F8.., Sec. 22, TION, R15E 11/09/01 CHItlh CORRECTIONS BP Exploration (Alaska) PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/13/98 RUN DATE RECVD 96-051 DIR SURV 96-051 GR/CCL 96-051 NGP ~ 96-051 NGP/ROP MD 96-051 7598 RRY- 17 - 04AL1 8668-8994 !~'10560-12893 ~4,13-15 SPERRY GR/RES 05/09/96 1 05/13/96 FINAL 11/20/96 FINAL 11/20/96 01/29/97 10-407 COMPLETION DATE ~'/ f /~/ DAILY WELL OPS R 3/ Iq/9~/ TO J~/{ /~/ Are dry ditch samples required? yes ~___~And received? Was the well cored? yes l~Analysis & description received? WellAre wellis inteStScompliancerequired?~es ~:.Received? ye~~. Initial COMMENTS WELL LOG TRANSMITFAL To: State of Alaska January 23, 1997 Alaska Oil and Gas Conservation Comm. Attn: Lori Taylor ._ '~' C9 /,~, Anchorage, Alaska 99501 MWD Formation Evaluation Tapes - DS 17-04A, 17-04A PB 1 & 17-04AL 1 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ylm Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3 LDWG formatted magnetic tapes with LIS listing. APItf: 50-029-20498-01, 50-029-20498-70 & 50-029-20498-60 respectively. 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company ri F:! I Cl_l rO G S E F:t ~./I I-- I:: S WELL LOG TRANSMITTAL To: State of Alaska November 18, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 17-04A, 17-04A PB1, & 17-04AL1 AK-MM-960313 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 17-04A: ~(~- ©GOb 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-20498-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20498-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia DS 17-04A PBI: ~ ' C),~ C) 2" x 5" MD Gamma Ray Logs: 50-029-20498-70 2"x 5" TVD Gamma Ray Logs: 50-029-20498-70 DS 17-04AL1- 2" x 5" MD Gamma Ray Logs: 50-029-20498-60 2"x 5" TVD Gamma Ray Logs: 50-029-20498-60 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ' ' ALASr,.A OIL AND GAS CONSERVATION t.,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-51 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20498-60 4. Location of well at surface ~ ....................... 9. Unit or Lease Name 2795' NSL, 4830' WEL, SEC. 22, T10N, R15E~; ¢~'~','~.~-.~'.'!:;? i I~I Prudhoe Bay Unit At to,p, of productive intervali ~~z~,~.~._ ~~ ;-'~', ~;:'- } 10. Well Number 1641 SNL, 4042' WEL, SEC. 27, T10N, R15E , 17-04AL1 At total depth ;.~.~_:...-.?.'-'~,~?~',~ :' !i ~,~'~'~;;;)/~-~/-~!_., 11. Field and Pool 3335' SNL, 3700' WEL, SEC. 27, T10N, R15E Prudhoe Bay Field / Prudhoe Bay 15. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 69.78I ADL 028334 12. Date Spudded04/22/96 !13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re ' 16' N°' °f C°mpleti°ns04/26/96 05/01/96 N/A MSLI One 17. Total Depth (MD+~TV, D)! 18. Plug Back Depth (MD.+,TVD)I19. Directional Survey 20. Depth where SSSV set~21. Thickness of Permafrosl 12894 8995 F-r1 12894 8995 FT~ []Yes []No 2210' MD! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, MLL, DLL, RE, Temp, ZDL, CHT, LWD/FE, GR, CCL, PFC, PCb 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-FING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FI'OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 32" 390 sx Arctic Set II 13-3/8" 72# L-80 Surface 2606' 17-1/2" 1975 sx Fondu, 400 sx Permafrost II 9-5/8" 47# L-80/S0095 Surface 7745' 12-1/4" 800 sx Class 'G' 7" 29# L-80 7547' 11160' 8-1/2" 190 sx Class 'G' 4-1/2" 12.6# L-80 11183' 12894' 6" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" Slotted Liner 3-1/2" 10745' 10690' M D TVD M D TVD 11202' - 12871' 8958' - 8994' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) May 4, 1996 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-EEL I GAs-MCF WATER-EEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED I~ OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORiGiNAL RECEIVED JUN 0 3 1995 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mm,,ers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 11156' 8938' Shublik 11212' 8962' S hublik 11438' 8967' 31. List of Attachments Summary of Daily Drilling Reports, Surveys ~.32. I hereby certify that the foregoing is true and correct to the best of my knowledge Tern/Jordan Title Senior Drilling Engineer Date 5'/g~/~}q, 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'. RECEIVED JUN 0 3 1996 Form 10-407 Rev. 07-01-80 Alaska 011 & Gas Cons. Cornm~s$1oD Anchorage SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WelIName: 17-04A RigName: Nabors 2ES AFE: 4J0319 17-04AL1 Accept Date: 03/1 9/96 Spud Date: 03/27/96 Release Date: 05/01/96 Mar 19 1996 (1) Rig moved 100 %. Rigged up Drillfloor / Derrick. Mar 20 1996 (2) Held safety meeting. Rigged up High pressure lines. Rigged up Lubricator. Removed Hanger plug. Held safety meeting. Held drill (Fire). Removed Hanger plug. Freeze protect well - 120 bbl of Diesel. Removed Xmas tree. Rigged up BOP stack. Tested BOP stack. Held safety meeting. Held drill (Fire). Tested BOP stack. Installed Accessories. Tested BOP stack. Repaired Top ram. Mar 21 1996 (3) Tested BOP stack. Removed Tubing hanger. Circulated at 10250 ft. Laid down Tubing of 11250 ft. Held safety meeting. Laid down Tubing of 11250 ft. Rigged up Kelly. Laid down Tubing of 11250 ft. Held safety meeting. Rigged down Tubing handling equipment. Tested Blind ram. Installed Wear bushing. Rigged up subsurface equipment - Cement retainer. Ran Drillpipe to 8245 ft (4.5 in OD). Mar 22 1996 (4) Ran Drillpipe to 8245 ft (4.5 in OD). Set packer at 8245 ft with 0 psi. Tested Cement retainer- Via annulus and string. Circulated at 8245 ft. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Made up BHA no. 2. R.I.H. to 8011 ft. Milled Casing at 8011 ft. Held safety meeting. Milled Casing at 8046 ft. Mar 23 1996 (5) Milled Casing at 8061 ft. Circulated at 8061 ft. Pulled out of hole to 682 ft. Held safety meeting. Pulled BHA. Ran Drillpipe in stands to 7966 ft. Washed to 8161 ft. Circulated at 8161 ft. Held safety meeting. Tested High pressure lines. Mixed and pumped slurry- 38 bbl. Displaced slurry - 133 bbl. Pulled Drillpipe in stands to 7026 ft. Held 1000 psi pressure on 7.5 bbl squeezed cement. Held safety meeting. Serviced Block line. Pulled Drillpipe in stands to 0 ft. Removed Wear bushing. Tested All functions. RECEIVED JUN 0 ~ t996 Alaska 0tl & Gas [;OHS. t;ommtssion Anchorage Operations Summary for: 17-04A & 17-04AL1 Mar 24 1996 (6) Tested All functions. Rigged down High pressure lines. Installed Wear bushing. Made up BHA no. 3. Held safety meeting. R.I.H. to 7922 ft. Held drill (Kick (well kill)). Backreamed to 8000 ft. Circulated at 8000 ft. Tested Casing - Via string. Pulled out of hole to 834 ft. Held safety meeting. Pulled BHA. Ran Drillpipe in stands to 7966 ft. Batch mixed slurry - 45 bbl. Held safety meeting. Mixed and pumped slurry - 45 bbl. Mar 25 1996 (7) Pulled Drillpipe in stands to 6745 ft. Circulated at 6745 ft. Held 1000 psi pressure on 17.5 bbl squeezed cement. Pulled Drillpipe in stands to 0 ft. Held safety meeting. Made up BHA no. 4 . R.I.H. to 7676 ft. Drilled cement to 7751 ft. Circulated at 7751 ft. Tested Casing - Via string. Drilled cement to 7900 ft. Circulated at 7900 ft. Pulled out of hole to 7427 ft. Held safety meeting. Serviced Block line. Pulled out of hole to 673 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 7700 ft. Mar 26 1996 (8) R.I.H. to 7700 ft. Milled Casing at 7745 ft. Circulated at 7745 ft. Pulled out of hole to 678 ft. Pulled BHA. Pulled Drillpipe in stands to 1000 ft. Held safety meeting. Ran Drillpipe in stands to 7845 ft. Washed to 7845 ft. Mar 27 1996 (9) Pulled Drillpipe in stands to 6435 ft. Held 1100 psi pressure on 7.4 bbl squeezed cement. Pulled Drillpipe in stands to 0 ft. Serviced BOP stack. Held safety meeting. Made up BHA no. 6 . R.I.H. to 6403 ft. Serviced Block line. R.I.H. to 7648 ft. Drilled cement to 7722 ft. Held safety meeting. Drilled cement to 7734 ft. Drilled to 7788 ft. Mar 28 1996 (10) Drilled to 8196 ft. Held safety meeting. Circulated at 8196 ft. Pulled out of hole to 7000 ft. Held safety meeting. Pulled out of hole to 835 ft. Pulled BHA. Made up BHA no. 7. R.I.H. to 4000 ft. ~-'- ' Mar 29 1996 (11) R.I.H. to 8196 ft. Took MWD survey at 8171 ft. Drilled to 8759 ft. Held safety meeting. Circulated at 8759 ft. Pulled out of hole to 7700 ft. Repaired Shaker discharge line. R.I.H. to 8759 ft. Drilled to 8840 ft. Mar 30 1996 (12) Drilled to 9180 ft. Held safety meeting. Drilled to 9747 ft. Circulated at 9747 ft. Held safety meeting. Drilled to 9908 ft. Page Operations Summary for: 17-04A & 17-04AL1 Mar 31 1996 (13) Drilled to 10195 ft. Held safety meeting. Drilled to 10559 ft. Circulated at 10559 ft. Flow check, Pulled out of hole to 844 ft. Held safety meeting. Made up BHA no. 8. R.I.H. to 7660 ft. Serviced Block line. Apr I 1996 (14) R.I.H. to 10472 ft. Reamed to 10559 ft. Drilled to 10624 ft. Held safety meeting. Drilled to 10862 ft. Held safety meeting. Drilled to 10975 ft. Apr 2 1996 (15)- Drilled to 11093 ft. Held safety meeting. Drilled to 11231 ft. Circulated at 11231 ft. Flow check. Pulled out of hole to 9786 ft. Flow check. R.I.H. to 11164 ft. Reamed to 11231 ft. Held safety meeting. Circulated at 11231 ft. Flow check. Pulled out of hole to 9000 ft. Apr 3 1996 (16) Pulled out of hole to 7000 ft. Serviced Block line. Pulled out of hole to 4000 ft. Held safety meeting. Pulled out of hole to 845 ft. Pulled BHA. Removed Wear bushing. Tested All functions. Installed Wear bushing. Made up BHA no. 9. Held safety meeting. Made up BHA no. 9. R.I.H. to 3978 ft. Repaired Draw works. R.I.H. to 4500 ft. Apr 4 1996 (17) R.I.H. to 10774 ft. Reamed to 10889 ft. Repaired Draw works. Held safety meeting. Reamed to 11231 ft. Drilled to 11280 ft. Held safety meeting. Drilled to 11298 ft. Circulated at 11298 ft. Pulled out of h°le to 7900 ft. Apr 5 1996 (18) Pulled out of hole to 201 ft. Pulled BHA. Made up BHA no. 10 . Held safety meeting. Made up BHA no. 10. R.I.H. to 7700 ft. Serviced Block line. R.I.H. to 8149 ft. R.I.H. to 11140 ft. R.I.H. to 11298 ft. Circulated at 11298 ft. Pulled out of hole to 9873 ft. Held safety meeting. Pulled out of hole to 208 ft. Pulled BHA. Made up BHA no. 11 . Apr 6 1996 (19) R.I.H. to 11117 ft. -Reamed to 11298 ft. Drilled to 11358 ft. Held safety meeting. ' Pulled out of hole to 208 ft. Pulled BHA. Page 3 RECEIVED JUN 0 ~ 1996 Alaska 0il & Gas Cons. Commission Anchorage Operations Summary for: 17-04A & 17-04AL1 Apr 7 1996 (20) Pulled BHA. Made up BHA no. 12. Pumped out of hole to 3977 ft. Held safety meeting. R.I.H. to 7603 ft. Serviced Block line. Held safety meeting. R.I.H. to 11150 ft.. Washed to 11358 ft. Drilled to 11451 ft. Circulated at 11451 ft. Pulled out of hole to 11122 ft. Pulled out of hole to 9000 ft. Held safety meeting. Pulled out of hole to 199 ft. Pulled BHA. Made up BHA no. 13. Apr 8 1996 (21) Made up BHA no. 13. R.I.H. to 11160 ft. Washed to 11261 ft. Held safety meeting. Washed to 11451 ft. Drilled to 11561 ft. Circulated at 11561 ft. Pulled out of hole to 10550 ft. R.I.H. to 11561 ft. Circulated at 11561 ft. Pulled out of hole to 4000 ft. Held safety meeting. Pulled out of hole to 196 ft. Pulled BHA. Rigged up subsurface equipment - Formation logs. Ran Drillpipe to 2000 ft (5 in OD). Apr 9 1996 (22) Ran Drillpipe to 10522 ft (5 in OD). Rigged up subsurface equipment- Formation logs._ Ran Drillpipe in stands to 11525 ft. Ran electric logs. Pulled Drillpipe in stands to 0 ft. Rigged up subsurface equipment- Formation logs. Made up BHA no. 14. Held safety meeting. R.I.H. to 11100 ft. Apr 10 1996 (23) Reamed to 11264 ft. Held safety meeting. Reamed to 11549 ft. Circulated at 11549 ft, Pulled out of hole to 7650 ft. Serviced Block line. Pulled out of hole to 231 ft. Held safety meeting, Pulled BHA. Rigged up Casing handling equipment. Ran Casing to 1500 ft (7 in OD). Apr 11 1996 (24) Ran Casing to 3787 ft (7 in OD). Circulated at 3787 ft. Ran Drillpipe in stands to 5687 ft. Held safety meeting. Ran Casing in stands to 7693 ft. Circulated at 7693 ft. Ran Cas~'g' in stands to 1131-1 ft. Circulated at 11311 ft. Mixed and pumped slurry - 40.5 bbl. Reverse circulated at 7548 ft. Held safety meeting. Retrieved Drillpipe landing string. Set Retrievable packer at 30 ft with 0 psi. Removed Casing spool. Installed Casing spool, Apr 12 1996 (25) Installed Casing spool. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Retrieved Wear bushing. Tested BOP stack, Installed Wear bushing. Ran Drillpipe in stands to 3325 ft. Held safety meeting. Ran Drillpipe in stands to 4560 ft. Laid down 4560 ft of Drillpipe. Made up BHA no. 15 . Singled in drill pipe to 1130 ft. Page 4 Operations Summary for: 17-04A & 17-04AL1 Apr 13 1996 (26) Singled in drill pipe to 5540 ft. R.I.H. to 7532 ft. Held safety meeting. R.I.H. to 11140 ft. Tested Casing. Held drill (Kick (well kill)). Drilled cement to 11311 ft. Washed to 11451 ft. Circulated at 11451 ft. Pulled out of hole to 7000 ft. Held safety meeting. Pulled out of hole to 404 ft. Pulled BHA. Ran Drillpipe in stands to 6000 ft. Serviced Block line. Apr 14 1996 (27) Ran Drillpipe in stands to 11451 ft. Circulated at 11451 ft. Mixed and pumped slurry - 21 bbl. Pulled Drillpipe in stands to 10786 ft. Circulated at 10786 ft. Held safety meeting. Pulled Drillpipe in stands to 5536 ft. Pulled Drillpipe in stands to 0 ft. Held safety meeting. Serviced Draw works. Made up BHA no. 16 . R.I.H. to 7000 ft. Held safety meeting. R.I.H. to 11020 ft. Drilled cement to 11316 ft. Apr 15 1996 (28) Circulated at 11316 ft. Pulled out of hole to 6449 ft. Held safety meeting. Circulated at 6449 ft. Pulled out of hole to 5536 ft. Pulled BHA. Made up BHA no. 17 · R.I.H. to 5500 ft. Serviced Block line. R.I.H. to 9500 ft. Held safety meeting. R.I.H. to 11316 ft. Drilled to 11340 ft. Apr 16 1996 (29) Drilled to 11417 ft. Circulated at 11417 ft. Held safety meeting. Circulated at 11417 ft. Pulled out of hole to 5317 ft. Pulled out of hole to 186 ft. Pulled BHA. Made up BHA no. 18 . R.I.H. to 5317 ft. R.I.H. to 11377 ft. Washed to 11417 ft. Held safety meeting. Drilled to 11546 ft. Apr 17 1996' (30) Drilled Drilled to 11745 ft. Held safety meeting. Drilled to 12122 ft. Held safety meeting. to 12234 ft. Circulated at 12234 ft. Pulled out of hole to 9000 ft. Apr 18 1996 (31) Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 19 . Held safety meeting. Made up BHA no. 19. R.I.H. to 7000 ft. Serviced Block line· R.I.H. to 12133 ft. Reamed to 12234 ft. Drilled to 12748 ft. Apr 19 1996 (32) Drilled to 12816 ft. Circulated at 12816 ft. Pulled out of hole to 11311 ft. R.I.H. to 12816 ft. Circulated at 12816 ft. Logged hole with LWD: Formation evaluation (FE) from 12816 ft to 11407 ft. Pulled out of hole to 200 ft. Pulled BHA. Rigged up Casing handling equipment. Ran Casing to 1529 ft (4.5 in OD). Rigged dov~ D handling equipment. Ran Casing on landing string to 2500 ft. EL, E I-V JUN 0 5 1996 Page 5 Alaska Oil & Gas Cons CoInm~ssmn Anchorage Operations Summary for: 17-04A & 17-04AL1 Apr 20 1996 (1) Ran Casing on landing string to 5000 ft. Serviced Electromagnetic brake. Ran Casing in stands to 12816 ft. Set Production packer at 11287 ft with 3000 psi. Circulated at 11280 ft. Retrieved Drillpipe landing string. Tested Well control. Held safety meeting. Rigged up subsurface equipment- Permanent packer. Apr 21 1996 (2 ) Rigged up subsurface equipment- Permanent packer. Set downhole equipment (wireline). Rigged down Logging/braided cable equipment. Made up BHA no. 1 . R.I.H. to 11176 ft. Milled Casing at 11160 ft. Circulated at 11178 ft. Pulled out of hole to 10000 ft. Apr 22 1996 (3 ) Pulled out of hole to 7000 ft. Serviced Block line. Pulled out of hole to 500 ft. Pulled BHA. Made up BHA no. 2. R.I.H. to 11160 ft. Milled Other subsurface equipment at 11178 ft. Circulated at 11178 ft. Pulled out of hole to 500 ft. Pulled BHA. Made up BHA_no. 3. R.I.H. to 7200 ft. Serviced Block line. R.I.H. to 10000 ft. Apr 23 1996 (4) R.I.H. to 11135 ft. Drilled to 11248 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 4. R.I.H. to 11135 ft. Drilled to 11175 ft. Apr 24 1996 (5 ) Drilled to 11285 ft. Circulated at 11285 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA n©. 5. R.I.H. to 10500 ft. Apr 25 1996 (6) R.I.H. to 11284 ft. Drilled to 12132 ft. Pulled out of hole to 3000 ft. Apr 26 1996 (7) Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 6 . R.I.H. to 7000 ft. Serviced Block line. R.I.H. to 12012 ft. Drilled to 12132 ft. Drilled to 12390 ft. Apr 27 f1996 (8) Drilled to 12894 ft. Circulated at 12894 ft. Pulled out of hole to 11151 ft. R.I.H. to 12894 ft. Circulated at 12894 ft. Pulled out of hole to 200 ft. Pulled BHA. Rigged up Casing handling equipment. Page 6 Operations Summary for: 17-04A & 17-04AL1 Apr 28 1996 (9) Rigged up Casing handling equipment. Ran Casing to 2000 ft (4.5 in OD). Rigged down Casing handling equipment. Ran Casing on landing string to 12894 ft. Circulated at 11182 ft. Retrieved Drillpipe landing string. Ran Drillpipe in stands to 11182 ft. Retrieved Drillpipe landing string. Serviced Block line. Retrieved Drillpipe landing string. Tested Well control. Apr 29 1996 (10) Made up BHA no. 7. R.I.H. to 11150 ft. Fished at 11157 ft. Pulled out of hole to 300 ft. Laid down fish. Pulled BHA. R.I.H. to 11150 ft. Circulated at 11150 ft. Laid down 1800 ft of 5 in OD drill pipe. Apr 30 1996 (11) Laid down 7400 ft of 5 in OD drill pipe. Serviced Block line. Laid down 3700 ft of 3.5 in OD drill pipe. Rigged up Tubing handling equipment. Ran Tubing to 10745 ft (3.5 in OD). Installed Tubing hanger. May I 1996 (12) Tested Single control line. Circulated at 10745 ft. Set Permanent packer at 10690 ft with 4000 psi. Rigged down BOP stack. Installed Xmas tree. Removed Accessories. Tested All tree valves. Tested Tubing - Via annulus. Circulated at 3400 ft. Rigged down High pressure lines. Rig moved 5 %. Page 7 SPF 'f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/17 - 04AL1 q NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 042696 MWD SURVEY JOB NUMBER: AK-MW-60047 KELLY BUSHING ELEV. = 69.78 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11147.66 8934.42 8864.64 11166.00 8942.86 8873.08 11185.14 8951.78 8882.00 11216.03 8963.92 8894.14 11247.98 8971.44 8901.66 62 47 S 12.90 E .00 442 62 24 S 13.80 E 4.82 444 62 1 S 14.65 E 4.40 446 71 38 S 15.80 E 31.30 448 81 5 S 16.94 E 29.78 451 9.04S 786.28E 4.88S 790.04E 1.30S 794.20E 8.66S 801.66E 8.42S 810.41E 4489.00 4505.28 4522.21 4550.57 4581.55 11277.73 8973.90 8904.12 11309.80 8973.51 8903.73 11341.37 8972.16 8902.38 11373.52 8970.46 8900.68 11405.04 8968.89 8899.11 89 25 S 17.80 E 28.15 454 91 58 S 14.60 E 12.76 457 92 57 S 12.50 E 7.35 460 93 4 S 12.80 E .99 463 92 40 S 12.30 E 2.03 467 6.69S 819.25E 7.48S 828.20E 8.13S 835.58E 9.46S 842.61E 0.19S 849.46E 4611.12 4643.15 4674.68 4706.78 4738.25 11436.84 8967.34 8897.56 11468.88 8965.76 8895.98 11501.19 8964.64 8894.86 11532.97 8964.45 8894.67 11564.74 8964.79 8895.01 92 53 S 12.60 E 1.17 470 92 46 S 12.00 E 1.91 473 91 11 S 13.00 E 5.76 476 89 28 S 12.90 E 5.42 479 89 17 S 13.50 E 1.98 482 1.20S 856.30E 2.47S 863.12E 3.99S 870.11E 4.96S 877.23E 5.89S 884.48E 4770.01 4802.00 4834.28 4866.05 4897.82 11596.69 8965.23 8895.45 11628.57 8965.75 8895.97 11660.41 8966.31 8896.53 11691.02 8966.87 8897.09 11723.21 8967.47 8897.69 89 8 S 13.60 E .56 485 88 59 S 13.40 E .78 488 88 59 S 14.10 E 2.20 491 88 55 S 12.80 E 4.25 494 88 56 S 13.20 E 1.25 497 6.94S 891.97E 7.94S 899.41E 8 . 86S 906 . 98E 8.62S 914.09E 9.98S 921.33E 4929.76 4961.64 4993.47 5024.07 5056.26 11753.82 8968.02 8898.24 11785.92 8968.29 8898.51 11816.47 8968.24 8898.46 11848.00 8968.23 8898.45 11879.71 8968.30 8898.52 88 58 S 13.60 E 1.31 500 90 3 S 13.00 E 3.85 504 90 9 S 13.40 E 1.34 507 89 52 S 13.50 E .91 510 89 52 S 13.50 E .00 513 9.76S 928.43E 0.99S 935.81E 0.73S 942.79E 1.40S 950.12E 2.23S 957.52E 5086.86 5118.96 5149.50 5181.03 5212.74 11910.02 8968.42 8898.64 11941.49 8968.57 8898.79 11973.56 8968.79 8899.01 12004.49 8969.08 8899.30 12035.43 8969.37 8899.59 89 39 S 13.10 E 1.51 516 89 46 S 13.20 E .49 519 89 25 S 13.70 E 1.92 522 89 30 S 13.70 E .29 525 89 25 S 13.60 E .43 528 1.73S 964.50E 2.37S 971.66E 3.56S 979.11E 3.61S 986.44E 3.68S 993.74E 5243.05 5274.52 5306.59 5337.52 5368.46 12069.62 8970.13 8900.34 12102.37 8971.86 8902.08 12134.15 8974.74 8904.96 12164.59 8977.03 8907.25 12195.89 8977.13 8907.34 88 3 S 12.90 E 4.47 85 52 S 9.60 E 12.06 83 41 S 8.30 E 7.98 87 41 S 7.10 E 13.68 91 56 S 9.60 E 15.78 5316.95S 1001.57E 5349.01S 1007.95E 5380.27S 1012.88E 5410.34S 1016.94E 5441.30S 1021.49E 5402.63 5435.30 5466.83 5497.01 5528.16 SPF Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/17-04AL1 500292049860 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 042696 MWD SURVEY JOB NUMBER: AK-MW-60047 KELLY BUSHING ELEV. = 69.78 OPER3kTOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 12227.17 8975.87 8906.09 92 38 S 7.00 E 8.59 12258.41 8975.09 8905.31 90 13 S 7.50 E 7.91 12287.13 8974.95 8905.17 90 20 S 8.00 E 1.79 12317.30 8974.77 8904.99 90 22 S 8.90 E 2.98 12349.05 8974.93 8905.15 89 1 S 7.20 E 6.84 5472.23S 1026.00E 5559.27 5503.20S 1029.94E 5590.29 5531.66S 1033.81E 5618.85 5561.50S 1038.24E 5648.89 5592.93S 1042.69E 5680.48 12380.43 8975.72 8905.94 88 7 S 9.30 E 7.28 12411.70 8976.84 8907..06 87 45 S 9.50 E 1.32 12442.71 8978.06 8908.28 87 43 S 9.80 E .98 12474.45 8979.37 8909.59 87 33 S 9.10 E 2.26 12506.36 8980.74 8910.96 87 30 S 9.50 E 1.26 5623.97S 1047.19E 5711.70 5654.80S 1052.29E 5742.86 5685.35S 1057.49E 5773.77 5716.63S 1062.70E 5805.39 5748.09S 1067.85E 5837.17 12537.48 8982.10 8912.32 87 30 S 9.10 E 1.29 12570.65 8983.43 8913.65 87 54 S 9.10 E 1.21 12601.75 8984.44 8914.66 88 22 S 8.80 E 1.79 12632.49 8985.33 8915.55 88 18 S 9.20 E 1.32 12663.78 8986.27 8916.49 88 14 S 9.50 E .98 5778.77S 1072.87E 5868.17 5811.50S 1078.11E 5901.20 5842.20S 1082.95E 5932.18 5872.55S 1087.76E 5962.80 5903.41S 1092.84E 5993.98 12694.21 8987.21 8917.42 88 15 S 9.20 E .99 12725.55 8988.15 8918.37 88 16 S 10.30 E 3.51 12757.40 8989.14 8919.36 88 9 S 8.40 E 5.97 12788.89 8990.24 8920.46 87 50 S 8.70 E 1.37 12820.69 8991.43 8921.65 87 50 S 7.60 E 3.46 5933.42S 1097.78E 6024.31 5964.29S 1103.08E 6055.56 5995.70S 1108.25E 6087.29 6026.82S 1112.93E 6118.63 6058.28S 1117.44E 6150.26 12852.28 8992.68 8922.90 87 37 S 10.10 E 7.94 12894.00 8994.51 8924.73 87 20 S 10.40 E 1.00 6089.46S 1122.29E 6181.70 6130.47S 1129.71E 6223.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6233.69 FEET AT SOUTH 10 DEG. 26 MIN. EAST AT MD = 12894 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 166.25 DEG. TIE IN POINT 11147.66' WINDOW POINT 11166' INTERPOLATED DEPTH 12894' SPF Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/17-04AL1 500292049860 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 042696 JOB NUMBER: AK-MW-60047 KELLY BUSHING ELEV. = 69.78 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11147.66 12147.66 12894.00 8934.42 8864.64 8976.02 8906.24 8994.51 8924.73 4429.04 S 786.28 E 2213.24 5393.59 S 1014.76 E 3171.64 958.40 6130.47 S 1129.71 E 3899.49 727.85 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/17-04AL1 500292049860 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 042696 JOB NUMBER: AK-MW-60047 KELLY BUSHING ELEV. = 69.78 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11147.66 8934.42 8864.64 11239.88 8969.78 8900.00 11267.66 8973.55 8903.77 4429.04 S 786.28 E 2213.24 4510.82 S 808.14 E 2270.10 56.86 4537.10 S 816.20 E 2294.11 24.01 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 7 May 1996 Transmittal of Data ECC #: 6660.00 Sent by: HAND CARRY Data: GR/CCL Dear Sir/Madam, Reference: ARCO PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 GR/CCL FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 FAX to (907) 563-7803 _ Received by: Date: RECEIVED MAY '1 ,~ 1996 Alaska 011 & Ga; Con;. Commission Anchorage 0 !~11 I_1_ I I~] I~ May 8, 1996 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re' Distribution of Survey Data 17-04A Dear Mr. Grant, Enclosed are two hard copies of the above mentioned file(s). oLl~q-3Vell 17-04APB1 MWD survey, tie in point 7,699.78', window point 7,745' depth 11,561' , interpolated q.{~-~-~Well 17-04A MWD survey, tie in point 11,310.65', interpolated depth at 12,816' q{~ ,~'1 Well 17-04AL1 MWD survey, tie in point 11,147.66', kickoff point 11,166', interpolated depth 12,894' Please call me at 563-3256 if you have any questions or concerns. Regards, Dept. Specialist Attachments. Oil & Gas Cons. Commission Anchorage 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (.9p7) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johnst~-'/ Chairman/-x,'~~ Blair Wondze'll~.',~'..', P. I. Supervisor/'¢'2~'''' FROM: Bobby Foster, ',,~ ' SUBJECT: Petroleum Inspector DATE: April 11, 1996 FILE NO: AFMIDKDD.doc BOPE Test- Nabors 2ES ARCO - PBU - DS 17-04A PTD # 96~051 Prudhoe Bay Field Wednesday, April 11, 1995: I traveled this date to ARCO's PBU DS 17-04A and witnessed the bope test on Nabors rig 2ES. As the attached AOGCC BOPE Test Report shows there was 1 failure. A valve down stream of the chokes in the choke manifold leaked. The valve will be changed out or replaced and I will be notified. The dg was clean and all equipment seemed to be in good working order. The location was clean and there was good access to all areas of the rig. Summary: i withessed the BOPE test on ARCO's DS 17-04A being drilled by Nabors 2ES - test time 4 hours - 1 failures. Attachment · AFMIDKDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig:.. X Workover: ...... DATE: Drlg Contractor: NABORS ........ Rig No., 2ES. PTD # 96-005 ~ Rig Ph.# 65g-~1836' ' Operator: ARCO Rep.: EDDIE VAUGHN Well Name: DS~7-O4A Rig Rep.: ..... ROBERT 15~ENcH - Casing Size: 7"X4.5" Set{~ '/~ Location: Sec. 22 T. 1ON' R.' ~ ~5E ~erMian'" ~m~' ' Test: tn~al Weekly X'L 'othe'r ............... Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: .'.O,K' (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YE~ FLOOR SAFETY VALVES: Quan. Pressure Upper Kelly/IBOP 1 .~ !5 .0~.,000 Lower Kelly / IBOP Ii 500/5,000 Bali Type 1' "500/5,07_0 Inside BOP .1. 500/5,000 P/F P BOP STACK: Annular Preventer f Pipe Rams Lower Pipe Rams Blind Rams 1 Choke Ln. Valves ~ HCR Valves ' 2 .... Kill Line Valves ' 1 Check Valve Quan. Test Press. 300/3,000 500/5,000 50O/5,0O0 500/5,000 PIF CHOKE MANIFOLD: No. Valves 14 No. Flanges '32' Manual Chokes 1 Hydraulic Chokes I Test Pressure 500/5,000 Functioned Funcb'oned P/F ACCUMULATOR SYSTEM: .N /A System Pressure 3,000. , I P Pressure After Closure 1,650 , P. MUD SYSTEM: V'=ual Alarm 200 psi Attained After Closure 0 minutes 31 sec. Trip Tank YES YES System Pressure Attained I minutes 48 sec. Pit Level Indicators JY~s-' YES Blind Switch Covers: Master: YES Remote: YES Flow Indicator YES YES Nitgn. Btl's: 4 ~ 2050 A~;~7~' " ... Meth Gas Detector YES 'YES .... Psig. H2S Gas Detector YES YES' Number of Failures: f ,Test Time: 4,0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made w~in ' 2 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at': Fax ~0.' 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 " - ri I . _l I Il Il, Il_ I Il IllIl .I II Ill_Il II J I II I'11. . .I II I I I REMARKS:. FAILURE: A valve down stream of the chokes in the choke manifold leaked- it will be repaired , and I will be noUfied within 48 hours. NOTE:The extra test is due to several small leaks in te~t,e~uiprnent. ........ , : ' ', i '", .... ' .' ,, , i ,, , , ,.IL , , , i I i , , , , , ,1 I I, , , , I I i I ,.,~1... ,i , i ,,, I - , Distribution: orig-Well File c - OperJRig c - Database c - Trip Rpt File c - Inspector 'STATE' wITNE[sS REQUIRED? '" YES X NO 24 HOUR NOTICE GIVEN YES X NO I I I I , II I. II.I . I. II [ Waived By: Wrlnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AFMIDKDD.XLS ~LAS~ OIL AND GAS CONSERVATION CO~SSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 7, 1996 Terry T. Jordan Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Pmdhoe Bay Unit 17-4AL1 ARCO Al~ska~ Inc. Permit No. 96-51 Sur. Loc. 2795'NSL, 4830'WEL, Sec. 22, T10N, R15E, UM Btmnhole Loc. 2307'NSL, 3729'WEL, Sec. 27, T10N, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to reddll 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 wellbore segment of existing well 17-4A, Permit No. 96-50, APl 029-20498-01. Production should continue to be reported as a function of the original API number stated above. 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 wimess 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. Jo on ' BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department offish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Joan Miller - AOGCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 fla. Type of work Drill [] RedrillFI lb. Type of well. Exploratoryl-1 Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Plan RTE = 64.05 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028334 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2795' NSL, 4830' WEL, SEC. 22, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 3606' NSL, 4034' WEL, SEC. 27, TION, R15E 17-4AL1 U-630610 At total depth 9. Approximate spud date Amount 2307' NSL, 3729' WEL, SEC. 27, TION, R15E 03/06/96 $200,000.00 ~12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD andTVD) property line ADL 028331 2973 feet No Close Approach feet 2560 12595' MD/8954' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 799s feet Maximum hole angle 89 o Maximum sudace 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 Butt-Mod 3630' 7845' 6800' 11475' 9025' 350 sx Class 'G' 6" 4-1/2" 12.6# L-80 Butt-Mod 1435' 11160' 8940' 12595' 8954' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ...... Conductor '. .... ':' .... ~:. !!'.;_: ! ?" !:i~.~ ~....!,' Surface Intermediate Production Liner Perforation depth: measured ,':,?.:',.'.?'.,. true vertical i2o. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] IDrilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportE] 20 AAC 25.050 requirements[] 21. I hereby cedifv that the foregoing is true and correct to the best of my knowledge Signed C/v,-- Title Senior Drillin~l En~lineer Date ! (,// Commission Use Only Permit Number APl number ,-. Approval date See cover letter ~'~...~'"/' 50.O~._~---.~~"~(~ ,=~-~¢~?/~ for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directiona_J_l survey required ,~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; 1~5M; I-I10M; I-I15M; Other: 0figiJl8~ Signed r&¥ by order of Approved by f~RViCJ W, ,Johnstor~ Commissioner ~ne commission Date,~ Form 10-401 Rev. ~)2a-~1-85 Submit ~n- triplicate Well Name: DS 17-4A DS 17-4 L1 Type of Well (producer or injector): Well Plan Summary Producer I Surface Location: Start of Horizontal Location: End of Horizontal Location: Start of Horizontal Location: End of Horizontal Location: 2795' FSL, 4830' FEL Sec 22 T10N R15E Sadlerochit Zone 4 (lower) Lateral X = 709600.00, Y = 5923500.00 Sec 27 T10N R15E 3407' FSL, 4070' FEL X = 709180.00 Y = 5922060.00 Sec 27 T10N R15E 1979' FSL, 4533' FEL Sag River (upper) Lateral X = 709630.44 Y = 5923700.50 Sec 27 T10N R15E 3606' FSL, 4034' FEL X = 709974.00 Y = 5922410.00 Sec 27 T10N R15E 2307' FSL, 3729' FEL I AFE Number: Estimated Start Date: [unknown I March 6, 96 [MI~I 112975' I MDg2 I 12595' I Well Design (conventional, slimhole~ etc.) I p~g: I Nabors 2ES IOperating days to complete: 34 [9,042' ] [ RT'GL [ 30'8'I[KBE: 64.05 18954' I- HAW, multi-lateral Objective: The 17-4A sidetrack is proposed as a pilot well for the DS 16/17 periphery. If the pilot well is successful, a development plan to sidetrack existing SI wells to the undeveloped 16/17 peripheral area will be evaluated.. Mud Program: ~ '~"~"~'" "" ' ! ,".~ ;", '..-"', .... ..,. ~,,, r-.. A 9.8 - 10.20 ppg Biozan polymer / KC1 water based mud will be used ..... : ,.- -.~ :..i-'.'?-~-"~ Special design '" I considerations 1"'~C~ 1"'7 t'~A A / T I D,-A,qll DI,,,-, (~111qlql"lqtJ'~Tr Pt'](I'I:~ I Depth Density (TVD) (PPG) KOP' 10 to to 10.2 Target Production Mud Pro Depth Initial Final =erties: Density (PPG) 8.9-9.1 PV (CP) INT GEL 10MIN GEL FL cd30min OIL (%) SOLIDS (%) 10 15 5 10 10 0 5 to to to to to to to 18 30 15 29 5 0 8 I 6" hole section: FIo-Pro Polymer Yield 10 sec 10 min Point gel 30-40 15-20 18-24 30-40 15-20 18-24 Marsh . Viscosity 50-60 8.9-9.1 50-60 pH Fluid Loss 9.5-10.5 <6 9.5-10.5 <6 Directional: [ KOP:17995' MD / 7039' TVD Maximum Hole Angle: 1 89° through the target Close Approach Well: ] none Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Con Length Top Btm Tbg O.D. n MD/TVD MD/TVD 8.5" 7" liner 29# L-80 But- 3630' 7845/6800 11475/9025 Mod 6" 4.5" liner 12.6# L-80 But- 1650' 11325/9007 12975/9042 Lower slotted Mod Lateral 6" 4.5" liner 12.6# L-80 But- 1435' 11160/8940 12595/8954 Upper slotted Mod Sag/Lat Used tbg 3.5" tbg 9.24/ L-80 TD$ 11100 Surface 11100/8913 Cement Calculations: [ Liner Size: 1 7" drilling liner [ Basis:[ 50% open hole excess, 80' shoe joint, 1000' MD above the Sag River. Total Cement Volume: [ 350[ sxs of Class G Blend @ 1.17 ft3/sx (Estimated Volume ) I Liner Size: 1 4.5" both production liners is slotted ( NO CEMENT ) [ Well Control: DR l?-OziA /I.-1 RectHll Plan ,qnmmarv Pn~a 9 Well control equipment consisting of 5000 psi W.P. pipe rams, blind ram.q, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards Sadlerochit pressure is @ 3550 Psi at @ 8800' TVDss or EMW of 7.8 ppg Sag River Sand is in communication with Sadlerochit and it will have same BHP of 3550 psi at 8860' TVDss which is EMW of 7.71 ppg. Operations Summary: ,Rig-Work: 1. Move in drilling rig. 2. Pull BPV. Circulate out freeze protection cap from inner and outer annuli and recover for future use. 3. Install a TWC and test from below to 1000 psi. ND the production tree. 4. 'N/U BOP's. Test BOP's to 250 / 5000 psi against TWC. Test annular to 250' /2500 psi. Remove the test plug. '5. Pull and lay down the 4-1/2 "x 3-1/2" tubing. Inspect for NORM. ( Check the location and depth of the cut on production handover form ) . PU a 9 5/8" EZSV on 4 1/2" DP. RIH and set it @ 8245' MD which is 200' below the base of the planned section. Sting out. Displace hole to drilling fluid ( which will be used as milling fluid ) and & spot 18 ppg mud up to the base of the proposed 9-5/8" section. POOH. Test the 9-5/8 casing at this time to 3500 psi to ensure integrity. 7. P/U Section Mill on 4.1/2" DP & RIH. Cut window from 7995' MD to 8045' MD. POOH after ensuring the hole is cleaned and free of metal cuttings. ! RIH open ended to 8145' MD' and spot a kick-off plug from 8145' MD up to ~ 200' above the top of the section ( @ 7795' MD' ). Pull 12 stands, shut in and perform hesitation squeeze. Attempt to achieve a 1000 psi squeeze but do not displace TOC below 100' above section top. ( Refer to recommended practices for KO Plug ) l~q I~_O/IA /I _1 l~actrill Plnn .~llrnrnBrv Pl~l~'e 3 Si Run in with an 8-1/2" steerable assembly (MWD - directional) and dress the cement to 5' below the section top. Circulate hole clean. Kickoff and directionally drill to the target at 11475' MD ( 8961' TVDss ). See attatched directional plan #3. ( Use sample catchers ~ 100' from the target and while drilling 6" horizontal hole ) 10. After DP conveyed logs are ran ( logging program is triple combo, GR/Neutron/Res) make a conditioning trip with a 8 1/2" hole-opener for the open hole section. Rabbit the drill string. 11. Run a 7" 29#, L-80, But/Mod liner with 9 5/8 x 7" packer / hanger to bottom in the 8-1/2" hole and space out for about 150' of lap. Refer to Standard Recommended practices for liner running procedure. Reciprocrate liner 20-30' during circulation and cementation. ( Will run approx, three STL joints of 7" liner across of Sag river) 12. Cement the liner in place with the total cement volume based upon 50% open-hole enlargement plus the 80' shoe volume, plus 150' of liner lap, plus 150' inside of 9-5/8 with DP in hole). Est volume is 350 sks. Set liner hanger / packer with 4200 psi. Reverse out clean. 13. Re-test BOP's as needed. 14. Run in with 6'-- steerable drilling assembly (MWD - GR) on 4-1/2" x 3-1/2" drillpipe. Clean out to landing collar. Test casing to 3500 psi for 15 min. Drill out of shoe joints plus 10' new hole. Displace hole to FLO-PRO system 15. Drill 6" hole to TD of @ 12975' MD. See attatched directional plan #3 ( Utilise sample catchers ) 16. Install a 4-1/2", 12.6#, L-80, But-Mod liner with 4-1/2" X 7"- L-80 packer / hanger to bottom in the 6" hole and space out for about 150' of lap. POOH and LD running tool. ML Packer Running Procedure 17. 18. RU electric line (multi-conductor cable) unit. PU Baker ML packer and RIH on No. 20 E-4 setting tool (with":~li:)'~' burning powder charge), P.O.L. (Iow side Iocator) with eccentric weight bars, GR and CCL. The assembly should be configured as shown below: 4-1/2" WLEG / Muleshoe.(1.5') 4-112" tubing pup joint (6') 4-1/2" XN nipple (1.5') Length of packer assembly= 20' 9" 4-1/2" tubing pup joint (6') Length of running tools - 31' 0" 4-1/2" x 7" ML packer, O.D. = 5.75" (5' 9") Atlas E-4 setting tool Total assembly length = 51' 9" Eccentric weight bars CCL DR 17-04A / T.-1 Redrill Plan Summary Paee 4 19. 20. 21. P.O.L. (Iow side Iocator) - (swivel above) PFC - GR - (multi-head above) NOTE: Eccentric weight bars should be oriented (in the assembly) such that their position on the Iow side of the hole (when on depth) places the packer orientation lug and the WLEG muleshoe on the high side of the hole. RIH with ML packer on E-line through the Sag River interval. Log up across the lower RA tag and place the packer on depth as shown below. Compare and confirm packer space-out with MAD pass data across this interval acquired earlier in the well. NOTE: Based on proposed plan, desired kick-off point and tool dimensions, the top of the packer should be at 11,172' MD (17' measured depth below the planned top of whipstock depth) and the top of the whipstock is to be at 11,855' MD (+_5' TVD below the top of the Sag River). It is critical that all open hole below the eventual whipstock exit (from 7" casing) be in the Sag River (i.e. no exposed Kingak). Set the ML whipstock packer; POOH and lay down wireline setting and correlation tools. RIH with gyro on E-line-and re-confirm orientation of lug on whipstock packer. POOH and rig down E-line. Report packer lug orientation to Anchorage office. Tool assembly should be configured as follows: Baker ML Orientation sub (same as for whipstock, but without seals or anchor) Gyrodata Wellbore Surveyor Whipstock Running/Setting Procedure 22. PU the Baker Window Master Milling System oriented to 15° left of high side. Insure that the MWD is oriented to the whipstock face. PU the assembly as shown below: See attached schematics, Figures 5 & 6. ML Anchor w/50K shear ring (3-1/2" IF pin down) Whipstock (3-1/2" IF pin down) 5.529" OD Window mill- Shear screw set for 45K (3-1/2" REG pin up) 5.875" OD Lower watermelon mill (3-1/2" IF box) 3-1/2" Flex joint 6.059" OD Upper watermelon mill 3-1/2" HWDP (2 joints) . · 4-3/4" OD Bumper Sub 4-3/4" MWD 4-3/4" Drill Collars (9 joints) :.-,~'~,--- 3-1/2" HWDP (21 joints) ~ ':;~: '''''~ '~ ~''~' ~'' ::.~:~i!,,!.;,...i::-: ~.... .~; ,:.~i'; .... .- · r~ 1'-/_tM A / I _1 l~,~,-trill Plan .qnrnrnarv Pa~e 5 NOTE: PU 1 joint of HWDP and MU with upper watermelon mill, flex joint, lower watermelon mill and window mill. Whipstock (with anchor assembly locked into orientation position) should picked up with air hoist. Close the blind rams and secure the' whipstock in the rotary table. Bolt the window mill to the whipstock making sure the shear pin is as snug as possible. 'Peen' the shear pin hole border on whipstock backside to secure same and keep from falling out. Gdnd off any excess pin sticking out above the whipstock backside. 23. TIH slowly (_--H:J0 seconds per stand). Avoid any abrupt stops which could cause the pin to shear prematurely. Set the slips gently on every connection! Reduce tripping speed to +_180 seconds per stand when the whipstock is within one stand of the ML Packer. Continue TIH to _+30' above the packer and stop. PU kelly and record PU and SO string weights. NOTE: As the whipstock is tripped through into the 65° (cased hole) angle section, double check pipe strap and depth correlation with upper RA tag. 24. Start mud pumps and orient whipstock assembly with respect to desired orientation (high side). If lug is 180° off of desired orientation, 'rotate assembly until whipstock anchor is within 45° of correct alignment (should be high side). Pulse the MWD to reconfirm whipstock orientation before "latch-up". If orientation is off greater than +-10°, contact Anchorage office. 25. Slack off slowly into packer, setting no more than 4-6K down weight. If not oriented exactly on azimuth, a changing MWD toolface will indicate the tool is properly locating into the ML Packer. PU slowly (15K over string PU weight) to insure latched into packer. If not latched, reorient with MWD and align lug again. NOTE: If "latch-up" is not accomplished after _+360© of pipe rotation, do not continue to feel for "latch-up". This may weaken the shear pin and it may shear before positive latch is certain. If no "latch-up" is observed, POOH and check assembly carefully paying particular attention to groove on anchor seal assembly. 26. Assure positive "latch up" by PU +-15K over earlier reco'rded pU weight. Slack off 40-50K at the Whipstock to shear bolt. Free rotation of the drillstring will indicate that the pin is sheared. 27. Once sheared from the whipstock, displace well with reconditioned. FIo._-Pro:mud. Window Milling Procedure 28. Begin cutting window using only enough WOB and possible especially for the first 2-3' to insure good directional behavior and a good cut into the casing. High WOB's should be avoided during the milling operation. Higher WOB's tend to cause loss of control of the window cutting behavior. Also, the mill may walk to the right (indicative of good cement bond) or to the left (poor cement bond). It may also cut into the face of the whipstock. If T'~e 1"7_/3AA IT _1 l~,:,Ari11 Plnn .qllmrn;ll-XJ' Pno'P ~ 29. the window mill has a tendency to slow in penetration rate above the halfway point down the face of the tool, additional WOB may be necessary to "bow" the assembly off high center. This point in the milling process is where most of the actual metal cutting process occurs, so lower ROP's should be expected. Many "green" mills have been pulled at this point. The final 2-1/2' of window should be cut with extreme care. If void (i.e. minimal cement) exists behind pipe, the mill may "jump off" the whipstock instead of traveling along the whipstock face as designed. Cement calculations in the odginal 8-1/2" hole were planned to insure high compressive strength slurry to a minimum of 500' above the planned window exit depth. Recommended window milling timeline and parameters are: Time Torque WOB Cum. Footage RPM (min) (ft lbs) (lbs) (ft) 0 2250 0 10 3000 1000 15 3OOO 2OOO 20 3000 2000 30 3000 2000 35 3000 3000 40 3500 3 - 5K 2.50 45 4000 5000 1 hr 10 4000 5 - 6K 4.50 1 hr 20 Reaming 5.00 1 hr 30 3500 4000 5.25 1 hr 45 2500 4000 6.50 1 hr 55 3000 4000 7.00 2 hr 10 2500 4000 7.75 2 hr 20 3000 5000 8.00 2 hr 30 3500 5000 8.50 2 hr 45 4000 5000 10.0 2 hr 55 Reaming 12.0 3 hr 10 3500 Formation 14.0 3 hr 20 Formation 16.0 0.00 50 0.50 50 0.75 50' 1.00 50 1.50 50 2.00 5O 80 3.00 80 80 NOTE: Recommended flow rates are 5-6 bbl/min. After milling 16' past top of whipstock, it should be noted that the mill should be now drilling entirely new formation (if able to drill ahead). Observe similar 5K WOB and 100 RPM parameters unless additional WOB is neccesary to make hole. The combination of casing 'and open hole milling must total 29' to allow the watermelon mill to pass completely through and down to the bottom of the window effectively reaming the sidetracked interval. DO NOT MILL FARTHER THAN 29' PAST THE TOP OF WHIPSTOCK. l'3.q 1'7_f/AA / 1.-1 ~.dvill Plnn ~]lmmat'v PRo'P, '7 30. Work the milling assembly up and down through the window several times to insure all tight spots and torque are minimized or eliminated. Ideally, assembly should be able to trip through window interval with pumps off. Circulate and condition. Pump high vis pill to assist with removal of metal and cement cuttings. NOTE: Upon removal of the milling assembly, inspect the gauge of. the upper full-sized watermelon mill. If the watermelon mill is more than 1/8" undergauge, plan an additional reaming trip to insure directional BHA's can get through window. If additional reaming is needed, run new full-sized watermelon mill AND new full-sized window mill. Drilling Upper Lateral (Sag River) 31. PU 6" bit, 2-1/4- 2-1/2© (pending required DLS) BH motor, GR/EWD Resistivity MWD and TIH. Directionally drill building angle (initially) at 40°/100' to _+11,259' MD (_+8,928' TVD) per directional plan#3 or as directed by the onsite geologist. POOH. Be sure to orient the bit away from the whipstock face BEFORE inducing bit rotation and/or attempting to the exit the window, NOTE: A 30°/100' DLS is planned to reach desired target before tripping for the lateral drilling assembly. Due to dogleg constraints of the Sperry Slim Phase 4 Resistivity tools, these tools will not be run through any doglegs over 30°/100'. Insure all Sperry Sun guidelines for tripping ALL MWD tools through high doglegs are observed (30°/100' sliding and 14°/100' rotating). As GR is the primary geo-steering .device, resistivity tools have been eliminated. It is highly recommended that stablizers (in the BHA) NOT be run until a minimum of 70-100' of progress is made outside the window (this will allow insertion of stabilizers - as long they are positioned below the window prior to drilling ahead - on subsequent trips). This will help minimize damage to the whipstock face. IMPORTANT WHIPSTOCK / WINDOW GUIDELINES ALWAYS TRIP SLOWLY AND CAREFULLY (_+90 SEC PER STAND) WITH ALL BHA'S THROUGH ANY MILLED WINDOW. NEVER ROTATE UP OR DOWN ON THE FACE OF THE WHIPSTOCK WITH A ROCK BIT OR STABILIZER. These items may "catch" the edge of the whipstock and damage it or cause it to turn inside the casing thereby either partially or completely covering the window exit. NEVER ENGAGE PUMPS (WITH MUD MOTOR IN THE BHA) WHILE THE BIT IS ON THE FACE OF THE WHIPSTOCK) Bit rotation may "catch" the edge of the whipstock and damage it or cause it to turn inside the casing thereby either partially or completely covering the window exit. 32. 33. If at any time during drilling operations a problem is encountered tripping through the window area, a watermelon or string mill should be run in the drilling assembly to clean up the window area. If fishing operations are commenced through the window area, always run as small as an O.D. fishing tool as possible. If overshots or box taps are utilized, small cutlips (1/2 - 1") are recommended. And while fishing assemblies should be flexible, string mills should be run directly above any fishing tools. The string mills will provide standoff and prevent any cutlip or other "edges" from hanging up on the top and bottom edge of the whipstock face. PU 6" bit, 1-1/4© BH motor, GR/EWD Resistivity MWD, TIH and directionally drill a horizontal hole to a TD of ___12,595' MD,_+8,954' TVD per directional plan #3 or as directed by the onsite geologist. POOH. NOTE: ABOVE. OBSERVE WHIPSTOCK/WINDOW TRIPPING GUIDELINES Make a conditioning trip with the Baker Fixed Blade 6" hole opener. Circulate and condition the well bore. POOH to window area, just above whipstock. Circulate bottoms up. Drift all drill pipe to 2.00" and SLM on last trip out of hole prior to running liner. ~' . · . NOTE: PU NB "rounded shoulder" stabilizer above rigid blade hole opener (similar to previous applications with this BHA) to insure standoff while tripping through the whipstock/window area. Observe window tripping guidelines. This BHA had to be gently worked through the window on the S-29A well. Upper Lateral (Sag River) Completion 34. RU and run 4-1/2", L-80, slotted liner (per Recommended Practices). Run liner as configured below and hang-off in rotary table: 4-1/2" Baker "bladed" guide shoe 4-1/2" blank pup joint (20' or as needed to space out liner near bottom) 4-1/2" Baker drillable pack-off bushing ~:. 4-1/2" slotted liner (length to be determined) 4-1/2" slo~ed (top 1/2) x blank (boSom 1/2)"circulating joint" Baker C-2 se~ing tool with 6' sleeve e~ension NOTE: Liner should be spaced out to land the top of the sleeve extension 5-10' off the base of the whipstock (in open hole). 'The 4-1/2" liner top must be landed COMPLETELY outside the 7" casing window exit. 35. With the liner hung off in the rotary table, PU the polished nipple, 2-1/16" internal circulation string and cup diversion tool spaced out as needed. I'~ l'-/J'~/I A /1' _1 'P,~A.,411 PI,~n (~llmm.,-';l'l.~/' P~IO'P C) 36. MU Baker C-2 setting tool (installed in the setting sleeve) to 2-1/16" intemal wash string. 37. MU C-2 setting tool, now attached to internal wash string, to 4-1/2" liner. DoCument all footages on space out. 38. MU one stand of drill pipe and lower assembly. Break circulation, but do not exceed recommended rate of 2-3 BPM. Do not exceed circulating pump pressure of 1,500 psi without consulting with Baker Field Engineer. Document pickup and slackoff weights of liner. 39. RIH with liner on 3-1/2" drillpipe observing tripping guidelines in the window area. Control running speed to prevent formation damage. NOTE: Before entering open hole at the window, record PU and SO weights of the string. Break circulation, but do not exceed 2-3 BPM. Record pump pressures. 40. Continue into open hole with the liner. The hole may be circulated if necessary however, rates should be kept to 2-3 BPM if possible. Do not exceed 1,500 psi circulating pressure. 41.- Tag bottom with liner shoe and place the liner top on depth (5-10' outside window). CONTINGENCY FOR NOT REACHING (SAG RIVER) TD WITH 4-1/2" LINER If for any reason the 4-1/2" liner does not reach TD in the Sag River lateral, DO NOT RELEASE FROM LINER. POOH with the liner and make a second hole opener run to clean out any bridges or obstructions and rerun the liner. If 1unable to POOH with the 4-1/2" liner, an inside casing cutter should be run and the liner cut below the window area at an appropriate depth to insure no 4-1/2" liner remains inside the 7" casing. 42. Tag bottom and rotate to the right to release the liner from the C-2 setting tool. Release from liner running tool leaving top of liner 5-10' outside window. PU 4-5' to confirm released from running tool (loss of weight). Tag liner top to confirm outside window. 43. PU-workstring, establish circulation and displace the well with sea water circulating 'as necessary to clean annular area. Contrary to Recommended Practices, do not spot lithium hypoclorite breaker in this well. 44. · POOH to top of 4-1/2" liner (at whipstock face) and circulate bottoms up. Continue POOH with setting tools and 2-1/16" wash string. (Do not rotate out of hole). Rack back DP. Lay down the 2-1/16" internal wash string. Whipstock Retrieving Procedure DS 17~04A /L-1 Redrill Plan Summary 45. 46. 47. 48. 49. 50. PU hydraulic "lug type" retrieving tool on HWDP as configured below: Hydraulic "lug type" retrieving tool (3-1/2" IF) 3-1/2" drillpipe (1 joint) 4-3/4" Bumper jars 4-3/4" Jars 4-3/4, MWD 3-1/2" IF Pump out sub (1-1/2" ball seat) 4-3/4" Drill collars (9 joints) 3-1/2" HWDP (21 joints) After PU retreiving tool and one joint drillpipe, RIH on one joint of DP, kelly up and engage mud pumps. Increase flow rate slowly until a standpipe pressure of 1,300-1,500 psi is reached. In this pressure range, you should see a marked pressure fluctuation indicating the latching key has fully retracted. Carefully PU retrieving tool, with jetting sub still below rotary table and confirm latching key is in the retracted position. Shut pumps down and stand the kelly back. PU remaining retrieving assembly and TIH. Stop approximately 30' above whipstock. Record PU and SO weights with pumps off. Kelly up, engage mud pumps, orient and align whipstock retrieving key and wash down the face of the whipstock past the key slot. Circulate (225 GPM minimum for MWD) for 30 minutes to clean whipstock face. While circulating, reciprocate pipe slowly (12' strokes) up and down the face of the whipstock. PU 3' above top of whipstock and recheck alignment. Once aligned, consider locking the rotary. Shut pumps down. Slack off into whipstock key slot. Retrieving key should bottom out in key slot (may see slight "bobble" on weight indicator). With pumps-off, PU and engage retrieving key into key slot. Overpull indicates positive latch-up. Whipstock should require 50-80K of overpull to release. Once released, unlock the rotary (if locked in Step #59) and POOH. Rack back the DP. NOTE: Extreme care should be taken when pulling the whipstock through the 7" casing and especially the BOP stack. DO NOT ROTATE OUT OF HOLE. Once whipstock is retrieved, it may be necessary to RIH with BHA listed below on DP to ML packer. This trip will be made ONLY if hole conditions suggest the 'ML Packer assembly is obstructed or if a casing scraper run is required prior to running the permanent production packer. Slowly sting into ML packer and 4- 1/2" tailpipe. Circulate and.condition. POOH laying down. 2-1/16" mule shoe 2-1/16" pipe (1 joint) 3-12" DP 7" casing scraper (spaced out to 'scrape' production packer interval - minimum 11,250' MD) 3-1/2" DP 5" DP CONTINGENCY TOOLS FOR WHIPSTOCK RETRIEVAL Hydraulic "dog type" Retrieving Tool "Rolling Dog" Overshot (with cutlip guide) Box tap assembly Whipstock mills NOTE: These tools (with back-ups) to be on location should the need arise. Note: Refer to Standard Completion Running Procedure as well as Proposed completion diagram for more details. 51. 52. Run the 3-1/2", L-80 BUT-MOD completion assembly spaced out to place end of tail pipe above the TSAD. ( TT tb be spaced out @ 12150' MD ) Tubing detail as follows: ( Refer to Proposed Completion Diagram for more -details ) · 3 · 3 · 3 · 3 · 3 · 3 · 3 · 3 · 3 · 3 · 3 · 3 1 1 1/2", L-80 1/2", 9.2#, 1/2", 9.2#, 1/2", L-80 1/2", 9.2#, /2" WLEG /2", 9.2#, L-80 BUT-MOD 10 ft pup joint Otis "XN" Nipple (2.725" ID) L-80 BUT-MOD 10 ft pup joint L-80 BUT-MOD 10 ft pup joint Otis "X" Nipple (2.813" ID) L-80 BUT-MOD full joint /2II , 1/2", 31/2", GLM's 31/2", 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint 1/2" X 7" Packer 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint 9.2#, L-80 BUT-MOD tubing joint 9.2#, L-80 BUT-MOD 10 ft pup joint 9.2#, L-80 BUT-MOD tubing with GLM's Depths to be determined later. L-80 Tubing Retrievable SSSV @ 2,200' MD 3 1/2", 9.2#, L-80 BUT-MOD tubing to surface 3 1/2" tubing hanger Space out, test the SSSV and circulate with corrosion inhibitor prior to setting packer. Drop the packer setting'ball. Pressure the tubing to 4000 psi and set the packer. 53. Close the SSSV, install a TWC, and test to 1000 psi. Remove BOP's. 54. Install and test the production tree to 5000 psi. Pull the TWC valve. 1"~.~ 1"/ /'~/1 A IT _1 1~,~,-lrill Pl~t~ C~mmFiru PRg~'. 1'2 55. 56. 57. 58. While holding the 1500 psi on the tubing, pressure test the annulus to 3500 psi for 30 minutes. First bleed off the annulus, then the tubing to 0 psi. Open the SSSV and shear the RP on the upper GLM with 2900 psi annulus pressure. Bleed off pressure and freeze protect with diesel to 2200' MD. Set a BPV. Close the SSSV and secure the well. Release rig. Complete appropriate documentation and hand-over to Production. Note: If there are any questions about this drilling permit please call Zeljko Runje at 564-4825 Ma~-01-96 17:34 AnadPill DPC 907 344 2160 P.05 I SHARED SERVICES DRILLING mm m i . I m ii " , Ub 1/-U4A IHJ] HA 51UhIHAIJK . . " VERTICAL SECTION VIEW m ~z-~ · ~ ............. Section at: 197.84 . i TVO Scale.' I inch-= 1200 feet ~ i ,[ Dep Scale.' I inch = t200 feet ', Drawn ..... · 03/01/96 I I i m . 0-- ,, Marker Identification MD BKB SECTN IN~N A) TIE-IN S~VEY 7gBl 70~ 2396 48.00 B) TOP OF WINDOW 7995 7039 2407 47.99 ~ ~ C) K~ CURVE 7/100 8000 7042 24tl 47.99 0 ............ ! ........ ~ ...... D) E~ 7/100 CURVE 8660 7482 2820 53.84 , El START CURVE 15/100 10938 8826 3796 53.84 F) END i5/lO0 CURVE 11033 8878 3847 59.64 61 START CURVE 15/tO0 1114~ 8933 3916 59.64 J H) 7' LINER POINT 11475 9025 4207 89.35 ~ I1 END iS/lO0 CURVE 11475 9025 4207 89.35 J) TARGET (SSL) 11475 9025 4207 89.35 I 0 ..... ~ ................. ~ K) ID (ESL) i2975 9042 5707 89.35 i ,, $ I O-~=~ _ ~_ 2~ ................. . ',, , . I ANAE)RI LL AKA-DF'C ~ , ~- , . '. ' , . ~__ ] ! ~E8 ' ~l .... ~ '~-- -- '-~ ...... : . _~. ~ ...... ~= __ . k=s'~ --,~ ....... ~ ....... . . ..,; ..... :.,., I ~ · ~- ~ ~::: ;;~:-~---~-, - ..... _.::::: :::~:~::::::~::: :'::~:: ........ ,-==...=. , .. ~A~.~3~: =::=~,~D,: =. .... ' ' :i:::::: :::::::::::::::::::::::: ~0.,.~_ ~ - _. a ....... - .... . .......... , ........ . ............. I i Mar-01-96 17:35 Anadrill DPC 907 344 2160 P.07 i. SHARED SERVICES DRILLING I I I mm I I m Harker'ldentification A)'TIE-IN SURVEY 798~ 7995 ~00 10938 1~033 1t~42 11475 11475 11475 12975 N/S : -E/W 2337 S 59B 2340 S 598 W 2799 S 506 4206 5 679 E 4273 S 72t E 4358 S 780 E 4667 5 769 E 4667 S - 769 E 4667 S 769 E 6095 S 309 E B) TOP DF WINDOW C) KOP CURVE 7/t00 D) END 7/100 CURVE E) START CURVE 15/100 F)'END t5/100 CURVE G) START CURVE-25/J00 H) 7' LINER POINT I) END 15/JO0 CURVE d) TARGET (6SL) K) TO (ESL) ._ i I i m DS- 17-04A (P3) .HA SIDETRACK PLAN VIEW I 'CLOSURE · 6103 feet at Azimuth 177.~0 DECLINATION.' +28.66! (E) SCALE.' ...... : $ inch = $000 feet DRAWN ' 03/0t/96 I i m I I ~nadr~ ]] SchYumberger ~ { AI"~/ADRIL. AK/~-DPC - I '-- -" I / APl>Dc* ' ~.'~.'~ L.. J - } ....................... : "' i ............. m . . . , ,.m ' .... " ~ ..... ~ .........~ .......... i ...... . - , ~ ~ "l - ~ . I · i~ ...... , ......... ............. ........... - ' -- m mm j m _ I . , 3500 :~nn 2500 2000 1~ tnnn qnn n nan ,nnn ,=~ ............... S'HARE:D j i ii i i SERV'I'C"k_S iii ii DS. ~ 7-04A VERTICAL i ii i i i i ! _. ii I,,... An~dr~]] ScMu~ber#er,.. i i ! (P3) MULTI-LAT SECTION VIEW Section at: 166.68 , ~ ~ ,ITVD sca elpep Sca] ! inch = 200 feet ! :" i le I inch = 200 feet i I i ,, ANADI~ILL , DP~ . i , ~__ I . . ... A, .~'~r~ .,,.-~\/~i'~ ., I ~LL=DS17~AL1 (MULTI -~ [P~N " ....... :'~ ......... ii1~' 11i~S' CU~40,0'1100', '. i i _,,c....,o,.c..,,.,,*,,. i i jNI [IAL.~ TO ~ 1~6.26', F~ 8914' ~ TO 8933' ' ~ ..... 11195' 11227' DRILL TANGENT TO CUE~ POI~. i .... I ' f HOLD INC 95.91', ON ~ 1~.26', I ' I 11227' 11259' CUR~40.0'/I~'. . : i 'l ..I, 11259' 125~5' ~GLEMUL~-~T.' ~ : I * I ~ t .. I.. ~ . : ..... . · . .D · ' ' ~ i .. , .. .?:. . i i I ¢. ! -_.~ ...................... , .......... ~ .......... , .......... F .... , ~.~'. .-~ ~., .... i' , , , l ......... ,.,%:. ..~ ~:; ~ I .... ,. -~ , 7: ~' ": PC /:';"' ' i i ::' ;' ~, '~"I ' , [ L. ' ': .:: ~L: ...: .:, , · ':' ' :- I ~ ... ........ '": ~:' '~' .... ; ' i ' ' ' ;' .:": -'~; ..... : ~ i .'. qF:~ ,' ~.t' ~ - -- ~ ~ '::,:' .......... ::_? - - ...................................... ~ '-- ~ F:'~ ; ~ . ~ ' I 'i. I i i D 4200 ~4300 4400 4500 4600 4700 4800 4900 5000 5100 ~ ' 5300 5400 5500 5600 §700 5800 5900 6000 Section' Departure i i i i J (c)96 1704ALP3 3.0b.02 ~ 42 PN P) Mar-01-96 17:41 Anadrill DPC 907 344 2160 P.16 SP~'ARED 'SERV T C'E'S' DR ILL I N6 mm l m ~- '- N/S 1ti04 4329 S ti195 4408 S 1i227 a4~8 s ii259 4468 S i1259 4468 S t2595 5767 S i mmml m Marker Identification A) TIE~IN C~VE 40/100 8) END 40/IOOmCURVE 6) CURVE'aO/tO0 O} ENO 40/100 CURVE F} lO E/W 782 795 [. 805 -805'E iii3 E im m m m m mm m · DS' ':tT'-O4A '(P3) MULTI-LAT " .PLAN VIEW 5874 feet. -at Azimuth 169.08 +28.661 (E) 1 inch = lO00 feet DRAWN '. 03/01/98 DECLINAt'ION.' SCALE ' ' ,4n adr.i ] ] ',Cch ] u¢b er ger' ) ,. ] . KB .... ) ....... I ...... : .................... ; f m , AN,* ,DRILL , · ................... .... ' ~ %' . . ~ ~ ..~.i ' · I ' ' · '' ~' , ~d m m mm ' ...................... ~ ..... . .......... ] ........ , o~ ' ~ ................ i ~ ~ .............. ' ~ ~ I 3500 ~n~ ~=0o 2000 15oo 1o00 500 0 500 toofl t~nn ~nnn WELL PERMIT CHECKLIST FI .LD FOO . redrll [] serv E ON/OFF SHORE ADMINISTRATION ENGINEERING APPR DATE 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. I 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 ...... Y If deviated, is wellbore plat included ........ Y Y Operator only affected party ............... Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... 14. Conductor string provided ............... N 15. Surface casing protects all known USDWs ........ 1.Y N 16. CMT vol adequate to circulate on conductor & surf csg. ~ Y N 17. CMT vol adequate to tie-in long string to surf csg . . . ~ N 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to __~OO psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N// 31. Data presented on potential overpressure zones ..... Y /~ 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ~/~ N 34. Contact name/phone for weekly progress reports . . . ;/. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH JDN HOWlljb - A:\FORMS\cheklist rev 11195 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simp!ify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. subfile 2 is typ&: I TAPE HEADER PRUDHOE BAY I/NIT MWp/ ,t LOGS WELL N~ME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NIIMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 17-04AL1 500292049860 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 22-JAN-97 MWD RUN 4 MWD RUN 13 MWD RUN 14 AK-MM- 960313 W. ALLEN W. ALLEN W. ALLEN J. CARLILE G. BECK GJ BECK i0N 15E 2795 4830 69.78 68.38 28.65 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 7550.0 8.500 7.000 11166.0 6.000 12893.0 MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. WELL 17-04AL1 IS REPRESENTED BY RUNS 1-4 AND 13-15. RUNS 1-3 ARE DIRECTIONAL ONLY AND NO DATA IS PRESENTED. RUNS 4, 13, 14, AND 15 ARE DIRECTIONAL WITH GAMMA RAY (SGRD). ALL GAMMA RAY DATA ACQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTOR, AND IS DENOTED AS NGP/SGRD. WELL 17-04AL1 HAS BEEN DEPTH SHIFTED. WELL 17-04AL1 WAS KICKED-OFF FROM WELL 17-04A AT 11166'. WELL 17-04AL1 WAS DRILLED TO TD AT 12893'. · OMI ,~0~lS H,T,~{ON : NiIOO X~f~ ,gOHGZI~{~ : I~ng~0-LI : '~>IS~ OO~I~ : NO JYIO' 0'£68EI O'E£IEI O'E£IEI O'S8EII O'~8~II 0'99III 0'99III 0'09~0I 0'9~8EI · psBz@m sunz qTq II~ ss~Xq ~IOI :q~6usI p~oos~ mnmTx~M ss~Xq E9 :q~Bu~I p~oo~ mnmTuTM smn~p 0I~I 89 :~poD 00000~'0 = 6u~o~dS ISA~ sI~ 000000'~6~0I = q~d~G pu~ ~IT~ sdei 000000'~68EI = qqd@G q~eqS eIT~ I0 018 06 ~ I0 0I£ 06 ~ pon sID clKL clKi q~Bus% ~zls A~D A~D S~U~ s~IdmmS spoD IOOi sm~M :ssA~nD ~ Z :GI q~dsp sdei (~9 #ZdXL) G~ODZ~ 0 0' : (~T) .~.~onk~v~s ~oo~ 000 ' 00' : (MI) NOIID~HHOD ~OH :XIISN~ XI~i~ :XI~4 qOOi NO~LO~N . 0' 0' 000 ' 000 ' 000 ' 000 ' 0'9 000E£ £'6 0'8/. 00'0I M,~MX~IOd ~IDA 0'0~£ 00S'8 : (~) H£&2q ©NIS~D S.~2~I~G : (NI) 2ZIS ~I~ ~OH N~dO ~ ©NIS~D O/knf ~OH~O~ 0II d~N ~SWi1N ~OOi ,~X,T, ~O0.T, HGOD ~IO0,T, %{O(INHA (NO,T.T,05 03, dO,T,) ~NI%LT, S ~IO0~] E'O/. L'pCj 0 0'99III 0'09SOI 0'99III E~0'E 'I~0'E dH~ ~£'I DSH 96-~d~-E0 0'59III 'SSIl~ eqexedes uT unx qlq qoea xo~ eqep xep~eq BoI pue saAxnD OMM M~r~ :~Z~MO_N ZqI~ ~Z~ZH Z~I~ SI~ :aclKq sT £ eiT~qnS ade.~ ss~Xq ~IOI :q~6usI p~oos~ mnmTxeM ss~Xq ~9 :q~6usI p~oos~ mnm~uTM '''sp~oo~ 08 £ :~IT~qns ~dei smn~ep 060~ 89 :spoD :X~mmns 5uipoosp spoo uoy~u~ss~ds~ 000000'~6~0I = q~ds~ puz sI~f 000000'SLIII = q2d@Q 2~S aIT~ I0 018 06 ~ I0 0I£ 06 ~ ~ SZLX~ ~IOI (0 #ZdXi) ~ODZ~ ~L~ ~ ~ ~Hd~ I 89 GMI4 dO~ E ~ Id~r~f I 89 GMI4 ~© I poM sID clKi clKi q~Bus~ sz!s s~u~ s@Idm~S spoo IOOi ~m~N ~rMS~ : ZdO~IS Hi%ION : X%f~{ ZOHCK'i%td : i~l~f~0 - L I : · DNI '%f)IS~f%f OOH%f : NflOO MM ND ~ape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11135.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11241.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 24-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 11285.0 11166.0 11285.0 0 62.0 81.1 TOOL NUMBER NGP 246 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11166.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD'VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO - PRO 9.10 68.0 8.7 43500 5.8 .000 .000 .000 .000 .0 137.5 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 01 REMARKS: MWD RUN 13. CN WN FN COUN STAT : ARCO ALASKA, INC. : 17- 04AL1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 5 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 11295.000000 Tape File End Depth = 11125.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15434 datums Tape Subfile: 4 68 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes rape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11239.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) .MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12092.0 25-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 12132.0 11285.0 12132.0 0 88.9 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER~ NGP 246 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 11166.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.20 68.0 8.6 44000 6.6 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 14. CN WN FN COUN STAT : ARCO ALASKA, INC. : 17-04AL1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 22 Tape File Start Depth = 12140.000000 Tape File End Depth = 11230.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9554 datums Tape Subfile: 5 85 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes rape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11990.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: D©WNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED .(RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12845.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 15. 27-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 12893.0 12132.0 12893.0 0 83.7 92.6 TOOL NUMBER NGP 246 6.000 11166.0 FLO-PRO 9.30 58.0 8.9 46000 5.6 .000 .000 .000 .000 .0 154.4 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. 17-04AL1 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 22 Tape File Start Depth = 12893.000000 Tape File End Depth = 11980.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20916 datums Tape Subfile: 6 85 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 = ~GOD N%Ifl&~H N~&SXS · spuoD~s 60'I = SmTJ UoT~nssxs pssd~IS d£I:8 £6 N~f~ IE snl :uoT~nD~x~ ~o pu~ s~Aq ~£I :q~Bu~I p~o~ mnm~x~ s~Aq g£I :q~BusI p~oms~ mnm~uy~ I0 IE/I /L6 IO /L6 SIq :~cL{q sT L SIT~qns sd~j.