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Home My WebLink About196-050 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. /16 0,) lJ 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 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No 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 r-; ALASKA \..IlL AND GAS CONSERV A TJON COMMlciSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged ø Abandoned 0 Suspended 0 WAG 20MC25.105 20MC25.110 21. Logs Run: MWD, MLL, DLL, RB, Temp, ZDL, CHT, LWD/FE, GR, CCL, PFC, POL CASING, LINER AND CEMENTING RECORD . SETTlÑG DEPTH MP,SE1'TINGDEPTHTVD.';~Hò~-'" .' , ~'.. »:AMoUN"i' G~De fop BOTToM :IOP.:Bó"M'oM :<SlZi:t:;. . CeMENT.JNßRecORQ';., PULLED H-40 Surface 110' Surface 110' 32" 390 sx Arcticset II L-80 Surface 2606' Surface 2606' 17-1/2" 1975 sx Fondu, 400 sx Permafrost II L-80 1 SO095 Surface 7700' Surface 6847' 12-1/4" 800 sx Class 'G', 300 sx PF 'C' L-80 7547' 11311' 6744' 9008' 8-1/2" 190sx Class 'G' L-80 11287' 12816' 8998' 9068' 6" Uncemented Slotted Liner tÛSING RECO~ '. . . SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.2#, L-80 6955' - 10745' 10690' 3-1/2",9.2#, L-80 11176' -11196' 11176' 25, A910;'FRAClÙRÌ(CEM?!-rr:§QÚ~~, ~TC~ . DEPTH,lNTERVAl (MO) ~UNT & KIND OF MATERIAL USED jM11T" P&A w' a bls Class 'G', 2nd Plug of 37 Bbls - IL '°0' j,<.IG*Class ,'rd Plug of 36 Bbls Class 'G' 6856' I Set EZ Drill Bridge Plug 6829' / Set Top of Whipstock PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oil-Bel 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: 1968' SNL, 4017' WEL, SEC. 27, T10N, R15E, UM Total Depth: 3275' SNL, 4007' WEL, SEC. 27, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 708703 y- 5928144 Zone- ASP4 TPI: x- 709657 y- 5923406 Zone- ASP4 Total Depth: x- 709705 y- 5922099 Zone- ASP4 18. Directional Survey 0 Yes ø No 22. CÀSING' SIZÉ 20" 13-3/8" 9-518" WT,PERFT,' 94# 72# 47# 29# 12.6# 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top'" and Bottom Interval, Size and Number; if none, state' none"): None MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE7 Oil-Bel Zero Other 5. Date Comp., Susp., or Aband. 2/7/2004 ß~ 6. Date Spudded 03127/1996 7. Date T.D. Reached 0411811996 8. KB Elevation (ft): KBE = 69.78' "9. Plug Back Depth (MD+TVD) 12816 + 9068 10. Total Depth (MD+TVD) 12816 + 9068 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. TVD GAs-McF WATER-Bel 1b. Well Class: ø Development 0 Exploratory 0 Stratigraphic Test 0 Service 12. Permit toÐrill Number ",/ 196-050/ 3O4-026/' 13. API Number I 50- 029-20498-01-00 14. Well Name and Number: PBU 17-04A / 15. Field I Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028334 17. Land Use Permit: GAs-McF WATER-Bel 20. Thickness of Permafrost 1900' (Approx.) \f~ c,\~o CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) 27. CORE DATA nïl'r-I\ I Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach se¡la'\!la,~ryc~. Submit core chips; if none, state "none". APR 292004 None Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE SIDE Alaska Oil & Gas Cons. Commission Anchorage (t' ~ ~ RØDMS 8FL MAY 0-4 200 ~ ~ 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 11154' 8937' 8963' None Shublik 11210' 11507' 9046' Sadlerochit 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 foregoing is true and correct to the best of my knowledge. Signed ~~ ~ T Sondra~wman ~~~t itle Technical Assistant Date cy-/ - ;(Cj - rf/ PBU 17-04A Well Number 196-050 304-026 Permit No.1 Approval No. INSTRUCTIONS Prepared By Name/Number: Drilling Engineer.. Terrie Hubble, 564-4628 Dave Wesley, 564-5153 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion). so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump. Submersible. Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OKjbJi\r\L.. ~ ~ 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 (300/143012000), 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 MILLOUTWINDOW @ 11,150' SLM - 11,161' CORR MD (NO SAMPLE). 02106/04 MIRU UNIT. LOAD IA WITH 1%KCL AND FP TO 2000'. 02107104 G: RIH WITH 2.5&J' C NTING NOZZLE. FLUID PACK WELL WITH 1 % KCL. IX 1 PUM 80 LS 15.8PPG G - CEMENT.SAW H OF 300 PSI, OPEN CK, HOLD 150 PSI BACK P S RE. PUH AFETY AT 8827'. EST TOC AT 11 ',WOC AND ORDER MORE CEMENT, Mlx/PUM 37 BLS 15.8PPG G CMT PUH LAYING IN CMT, UN~ TO OBTAIN 1:1 RETURNS. PARK AT SAFETY 935', RDER MC?~MENT. TEST CMT TO 610 PSI HOLDING 360 PSI. DISPLACE COIL AND BS TO DIESEL. MIX AND PUMP3§&BLS CLASS G CEMENT AT 15.8 PPG. 02108/04 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 1 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) WI 2.70" CENTRALIZER & SAMPLE BAILER, CEMENT FOUND IN SAMPLE BAILER. 02114/04 CHEMICAL CUT 3-112" 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 W/WEIGHT/JARS/CCU2.625" ANCHOR BODY AND CHC HEAD (28.6' X 2.625"). GOOD INDICATION. DID NOT TAG TD. LEAVE WELL SHUT IN. ~ 17-04B, Sidetrack Pre-Rig Work. 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. 02120104 SET HOLD OPEN SLV @ 2192 SLM, BLED T-IAlOA TO 0 PSI. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/21/2004 2/22/2004 2/23/2004 2/24/2004 ,~ ~. Page 1 .. BP EXPLORATION Operations Summary Report 17-04 17-04 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES 00:00 - 06:00 From - To Hóurs PRE Task Code NPT Phase 6.00 MOB N 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 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 04:30 - 05:30 05:30 - 08:30 08:30 - 13:00 13:00 - 13:30 13:30 - 16:30 1.00 WHSUB P 3.00 WHSUB N 4.50 WHSUB P DECOMP WAfT DECOMP DECOMP 0.50 WHSUB P DECOMP 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 DEiscriptjon ofOperiitiòn$:~. Waiting on the Wells Group to release DS 17-04 to drilling. VECO removed the well house & flow line. Well turned over to Drilling @ 06:00 Hrs. Perform 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 performing 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 3-1/2" x 9-5/S" Annulus to Choke Manifold in Preparation to displace diesel from wellbore. Checked 3-1/2" Tubing x 9 5/8" 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 DFAL DECOMP DFAL DECOMP N N 21 :30 - 00:00 2.50 FISH DFAL DECOMP N 00:00 - 02:00 2.00 FISH DFAL DECOMP N 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 DFAL DECOMP N 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 13 5/8" 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.O.LD.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 ftI1bs 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-5 Lock-out TooI- 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. Pronted: 3/1512004 10.15:11 AM ~. r'o, Page 348 BP EXPLORATION Operations Summary Report 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 - To Hours Task Code NPT Phase 2/26/2004 16:00 - 23:00 7.00 FISH N DFAL DECOMP 23:00 - 00:00 1.00 FISH N DFAL DECOMP 2/27/2004 00:00 - 02:00 2.00 FISH N DFAL DECOMP 02:00 - 02:30 0.50 FISH N DFAL DECOMP 02:30 - 03:30 1.00 FISH N DFAL DECOMP 03:30 - 06:30 3.00 FISH N DFAL DECOMP 06:30 - 08:00 1.50 FISH N DFAL DECOMP 08:00 - 11 :00 3.00 FISH N DFAL DECOMP 11:00-14:30 3.50 FISH N DFAL DECOMP 14:30 - 18:30 4.00 FISH N DFAL DECOMP 18:30 - 21:30 3.00 FISH N DFAL DECOMP 21 :30 - 23:00 DECOMP 1.50 FISH P 2/28/2004 23:00 - 00:00 00:00 - 01:00 01:00 - 11:00 DECOMP DECOMP DECOMP 1.00 FISH 1.00 PULL 10.00 PULL p P P 11:00 - 11 :30 0.50 PULL P DECOMP 11:30 - 12:00 0.50 CLEAN P DECOMP 12:00 - 14:30 2.50 CLEAN P DECOMP 14:30 -17:00 2.50 CLEAN P DECOMP 17:00 - 19:00 2.00 CLEAN P DECOMP 19:00 - 20:00 1.00 CLEAN P DECOMP 20:00 - 21:30 1.50 CLEAN 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 PJSM wI SWS Crew on 2.68" Jet Cutter Run. RlU to run Jet Cutter. RIH wI 2.68" Jet Cutter. Correlate collars & position Cutter @ 7500' Latch onto Landing it & P/U wI 150K on Weight Indicator Fire Jet Cutter - No Indication on String Wt. - Pull up to 2ooK - Tubing not Free. POH wI Jet Cutter. Confirm jet Cutter has Fired. UD Tools. 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 133/8" OD Tubing Hanger in 135/8" ID BOP Stack. PJSM wI SWS. M/U & RIH wI Free Point Tool. Free Point Tool failed. POH. Found Moisture in E-Line. Cut Line & Re-Head. RIH wI Free Point Tool and take Stretch Readings at various depths. 100 % Stuck @ 7221'. 93% Free @ 7004' M/U 2.68" Jet Cutter & RIH. Correlate & position cutter @ 6950'. Attempt to Fire Cutter. No Success - Misfire. POH 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, 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 RlU Tongs & control line spooler. UD Landing Jt. & Hanger. Blow down Top Drive C/O to Short Bails. 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. RID Tubing Equipment & Clear Rig Floor, M/U Wear Bushing on Running Tool & Install Same. Load rig floor wI CIO BHA. M/U Same + 9 DC's & 20 Jts, 5" HWDP. RIH. P/U & RIH wI 75 Jts, 5" DP from Shed. Continue RIH with Stands of 5" DP from Derrick. Take Weight @ 6,612'. 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. 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' 3/1512004 10'15:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .~ ~ Page 4 - BP EXPLORATION Operations Summary Report 17-04 17-04 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Date From - To Hours Phase 10:00 - 11:00 1.00 DHB P 11:00 - 13:00 2.00 STWHIP P 13:00 - 17:00 4.00 STWHIP P 17:00 - 17:30 0.50 STWHIP P 17:30 - 18:45 1.25 STWHIP P 18:45 - 21 :45 3.00 STWHIP P 21 :45 - 22:45 1.00 STWHIP P 22:45 - 23:45 1.00 STWHIP P 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 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 16:30 - 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 DECaMP DECOMP DECaMP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 0.25 STWHIP P 3.50 STWHIP P 2.50 STWHIP P 1.50 BOPSUPP 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 DRILL INT1 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. RlU SWS. M/U SWS CCL & HES EZ-DRILL Bridge Plug. RIH, Correlate wI GR & Set EZ DRILL BP @ 6,856'. - RlU & 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 w/1.1S deg Bend - 8. Stabilizer - COR Assembly - MWD Assembly - 8-1/2. Stabilizer - 3 x 6-3/4. Flex Collars - XO - Jars - 20 Jts 5. HWDP - 81/2. 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 I U Top Drive, Established Parameters: String Weight Up 155,000#, String Weight Down 140,000#, Pump Rate 560 gpm, 1550 psi, ECO 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 SOOgpm,1,420psi. Drilled 8-112. Directional Hole by Rotating and Slidin f 6,858' to 7,289'. WOB Sliding 12,000# - ,OB Rotating 10,000# - 18,0 00, Motor RPM 157, Torque ,000 ft Ilbs - On Bottom 7,000 ft I Ibs. mp Rate 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: 3/15/2004 10'15'17 AM iiJ úÆ q Z- ì { z..Cì' 0 t.J . - ( STATE OF ALASKA ( I) [ìj f I 2..'ý /4- ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 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 IBI 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 prill Number BP Exploration (Alaska) Inc. B Development 0 Exploratory 196-050 / 3. Address: 0 Stratigraphic Test 0 Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20498-01-00 7. KB Elevation (ft): KBE = 69 78' 9. Well Name and Number: . PBU 17-04A ./ 8. Property Designation: 10. Field / Pool{s): ADL 028334 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRE$ENTWELLCONDITIONSUMMARY .. ... '.. '.' '.' Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12816 9068 12816 9068 None None CasinQ LenQth Size MD TVD Burst Collapse Structural CUllUULlL r 110' 20" 110' 110' 1530 520 ~llrf!::l"Ø 2606' 13-3/8" 2606' 2606' 5380 2670 1.£ . .£. 7745' 9-5/8" 7745' 6878' 6870 4750 Proch Irtinn liner 3764' 7" 7547'-11311' 6744' - 9008' Liner 1529' 4-1/2" 11287' - 12816' 8998' - 9068' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 11399'-12814' 9035'-9067' 3-1/2",9.2# L-80 10745',11176'-11196' Packers and SSSV Type: 7" x 4-1/2" Baker 'ML' packer; 7" x 4-1/2" Baker 'S-3' Packers and SSSV MD (ft): 11176'; 10690' packer; 3-1/2" Camco 'TRDP-1A' TRSV 2210' 12. Attachments: 13. Well Class after proposed work: B Des~ription Su~mary of Proposal 0 BOP Sketch 0 Ex lorator B Development 0 Service 0 Detailed Operations Program p y 14. Estimated Date for / 15. Well Status after proposed work: Commencing Operations: February 5, 2004 0 Oil 0 Gas 0 Plugged B 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 Isaacspn Title Senior Drilling Engineer \"' L 1 \I I I. Prepared By Name/Number: SiQnature L, . 1\ - ~N~.- Phone 564-5521 Date '/2 r 10f.\ Terrie Hubble, 564-4628 Commission Use Only I Sundry Number: 304- ¿;;;;..t:::; 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 eEl VE 0 t R P r fo Ò fr' ¡ -..'" () '. ~ t . Other: l eS .;>() C " JAN 2 8 2004 , '~I/ íj ; I ~lf Alaska Oil & Gas Cons. Comrnis:;ion Subsequent tJ rm r uirec 0- "'f '.If 1/ Anch . ..' orage , ~i:\((-'hÎ,t!.ì.\Hi~W[ï:;:r: [1.[' Ð@22004 .. ~~7{F\ì11~B\~a;.t!.., If . ~:Ð BY ORDER OF Approved -'I'r j'Æ COMMISSIONER THE COMMISSION Date"/; r¿b ht/- Form 10-403 ~ed 1~~ ~ 0 R I G I N A L ,,___?pbmit 7S~tcate I ..-sr-L. ÆB o~ ~ . ( ( bp O~'.'I.'.'.':" ¡þ' ':, ,""..." ,'"' ~'J~ I, 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. ,...,.he well remained SI 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 24, and a 1700' lateral drilled into the Sag River. An isolation packer was set between the two soAhat contributions from each lateral could be determined. Initial production averaged about 380 bopd:;"ith 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 24. Geochemical analysis suggested the Sag River was not ,/" contributing any production. Logs in the Ivishak section show~çt high water saturations through most of the upper section until the well bore dipped into the HOT pt'9t5õut~000' SS. Current production is about 100 BOPD, and 500 BWPD. Cumulative production ~~/- The 17 -04B sidetrack is scheduled for Nabors rig 7ES. Current estimates have it beginning around February 21,2004, following the completion of the 17-07A sidetrack. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Notify the field AOGCC representative with intent to plug and abandon Pre-Ria ODerations: 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 ,000psi. Pump sufficient cement to fill both the A and AL 1 well bores, plus squeeze approximately 10bbls, aæd e the cement top up in the tubing tail at -1 0,650'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: ,so, 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. t 6. 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. T\.vL~ ;0 '.. Lias tt'Pp~ÎV'Ä-(. 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. Pull 3%" 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 95/8" 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 :t 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 TO 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: 02/05/04 Estimated Spud Date: 02/21/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 17-04A & AL 1 Application for Sundry . TREE == . 5-1/16" CrN ~ WELLHEAD== FMC ~ 17 04A & AL1 ( SAFETYNOTES:WELLANGLE>70deg@ ACTUATOR == AXELSON - 11350' & > 90 deg @ 11648'. KB. ELEV == 69.78' SF. ELEV == NA -15-1/2" X 3-1/2" XO ID == 2 992" I KOP == 4250' ' . Max Angle== 91 @11711' -13-1/2"CArv1COTRDP-1A TRSV,ID==2.812" I Datum MD = 11003' Datum TVD:: 8800' SS GAS LIFT rvtANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 113-5/8" CSG. 72#, L-80. ID = 12.347" 1 1 3405 3405 1 MMG DOME RK 16 05/17/96 2 4693 4675 17 MMG DV RK 0 05/17/96 3 6271 5905 50 MMG DOME RK 16 05/17/96 4 7765 6892 48 MMG DV RK 0 05/17/96 5 9198 7806 56 MMG DV RK 0 05/01/96 6 10112 8396 53 MMG SO RK 24 05/17/96 -1 9-5/8" X 7" BKR ZXP PKR, ID = 6.310" I I 9-5/8" CSG 47# L-80 ID = 8.681"1-1 7700' r- ' , , -1 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, ID = 2.992" 1 3-1/2" HES X NIP, ID = 2.813" 1 3-1/2" WLEG, ID = 2.992" 1 7" LNRMILLOUTWINDOW, 11161'-11172' (17-04AL1) / * TOL 10' OUT OF WINDOW. * OPEN HOLE TO 11183'. ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/30/80 <... 1118~-1 4-1/2" BKR HRS SL V, ID = 4.375" 1 ANGLEATTOPÆRF: 63 @ 11202', Note: Refer to Production DB for historical perf data - - I 11202" 1-1 4 1/2" SL TD LNR, ID = 3.958" I SIZE SPF INTERV AL Opn/Sqz DA TE - - - - 4-1/2" SLTD 11202-12871 0 05/01/96 ~ ---- 4-1/2" SL TD 11399 - 11927 0 05/01/96 - - - - - - -- 4-1/2" SLTD 11929-12814 0 05/01/96 ----- ---- -- --- I BTM OF 4 1/2" SL TD LNRI-I 12871 ~ þ- 141/2" LNR, 12.6#, L-80, .0152 bpf, ID:: 3.958" 1 -I 7" X 4-1/2" BKR ML PKR, ID = 2.937" 1 -I 3-1/2" HES XN NIP, ID = 2.750" I 13-1/2"TTP,9.20#,L-80,.0087bPf, ID=2.992" 1 11194' -i I 3-1/2" WLEG, ID = 2.992" -I 7" X 4-1/2" TrN SS HORIZ. PKR, ID = 3.918" 1 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1 -I BTM OF 41/2" SL TD LNR 1 ITOPOF41/2" SLOTTEDLNR,ID=3.958" 1--1 11399' I 14 1/2" SLOTTED LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 DA TE REV BY COMMENTS DA TE REV BY COMMENTS PRUDHOE BA Y UNrr 10/13/80 ORIGINAL COMPLETION 01/09/02 GClKAK SLOTTED LNR CORRECTION WELL: 17-04A / AL 1 03/19/88 RWO 01/16/04 dew Slotted liner correction ÆRMIT 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' FEL, Sec. 22, TION, R15E 11/09/01 CHltlh CORRECTIONS BP Exploration (Alas ka) ", TREE = 5-1/16" CWV ( l' WELLHEAD= FMC 17 04A & AL1 Pre Rig SAFErYNOTES:WELLANGLE>70deg@ ACTUATOR = AXELSON - 11350' & > 90 deg @ 11648'. KB. 8...EV = 69.78' BF. ELEV = NA -i 5-1/2" X 3-1/2" XO, ID = 2.992" 1 KOP = 4250' _Max ~.!'gle =--~ @-~ -i3-1/2" CAMCO TRDP-1A TRSV, 10 = 2.812" 1 Datum MD = 11003' GAS LIFT MANDRELS DatumND= 8800'SS ST MD ND DEV lYPE VLV LTCH FORT DATE 1 3405 3405 1 MMG DOME RK 16 05/17/96 113-5/8" CSG, 72#, L-80, ID = 12.347" l-i 2606' I 2 4693 4675 17 MMG DV RK 0 05/17/96 3 6271 5905 50 MMG DOME RK 16 05/17/96 4 7765 6892 48 MMG DV RK 0 05/17/96 PrerigE-lineChemicalcut l-i -7,525' 1 5 9198 7806 56 MMG DV RK 0 05/01/96 6 10112 8396 53 MMG SO RK 24 05/17/96 -i 9-5/8" X 7" BKR ZXP PKR ID = 6 310" 1 I 9-5/8" CSG, 47# L-80, ID = 8.681"1.., 7700' r- ' , .., 9-5/8" X 7" BKR HMC HGR, ID = 6.200" I Minimum ID = 2.750" @ 11187' 3-1/2" HES XN NIPPLE -i 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 I Pre rig coiled tubing cement P&A l-i 13-1/2"TBG,9.2#,L-80,.0087bPf,ID=2.992" 1 10744' -i 3-1/2"HESXNIP,ID=2.813" I -i 3-1/2" WLEG, ID = 2.992" 1 PERFORA TION SUMMARY REF LOG: BHCS ON 09/30/80 -i 4-1/2" BKR HRS SLV, ID = 4.375" I A NGLE AT TOP PERF: 63 @ 11202' Note: Refer to Production DB for historical perf data I 11202' l-i 4 1/2" SL rD LNR, 10 = 3.958" 1 SIZE SPF INTERVAL 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 I BTM OF 4 1/2" SL rD LNRI 14 1/?" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 / -i 7" X 4-1/2" BKR ML PKR, ID = 2.937" 1 -I 3-1/2" HES XN NIP, ID = 2.750" 1 13-1/2"lTP,9.20#,L-80,.0087bPf, ID=2.992" 1 11194' -i 1 3-1/2" WLEG, ID = 2.992" -i 7" X 4-1/2" TWV SS HORIZ. PKR, ID = 3.918" 1 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1 """ -i BTM OF 41/2" SL rD LNR 1 TOPOF 41/2" SLOlTED LNR, ID = 3.958" 1-1 11399' 1 141/2" SLOlTED LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 DA TE REV BY COMMENTS DA TE REV BY COMMENTS PRUDHOE BAY UNIT 10/13/80 ORIGINAL COMPLETION 01/09/02 GC/KAK SLOlTED LNR CORRECTION WELL: 17-04A / AL 1 03/19/88 RWO 01/21/04 D8N Proposed Pre rig work ÆRMIT 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' FEL, Sec. 22, TION, R15E 11/09/01 CH/tlh CORRECTIONS BP Exploration (Alaska) { MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor (p-\ DATE: June 27,2002 Chair ý',(ò~. /h.. ^ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~''fJ! PAl P.I. Supervisor' \ ...û":) 3H '<"'t \ V multiple FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL W~I 4 P.T.D. P Notes: W~I 4 P.T.D. P Notes: W~I 4 P.T.D. P Notes: Well P.T.D. Notes: W~I 4 P.T.D. P Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. p::: Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details Page 20f3 M.I.T.'s performed: § Number of Failures: Q Total Time during tests: 3 hrs. Attachments: none ~ D2!!! SCANNED AUG 0 1 2002 MIT report form 5/12/00 L.G. mit(2) kru 3h 6-27-02js.xls 7/16/2002 MEMORANDUM State of Alaska AlaSka Oil and Gas Conservation Commission TO: Julie Heusser Commissioner DATE: December 15, 2000 THRU: FROM: Tom Maunder, ~~~ P. I. Supervisor ~.c_~%,~°c~ Chuck SCheve; : SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 17 Friday, December 15~ 2000: I traveled to BPX's Drill Site 17 and witnessed the semi annual safety valve system testing. As the attached AoGcc Safety Valve System Test Report indicates I witnessed the testing of 15 wells and 30 components with one failure. The Surface Safety Valve on Well 17-4 Failed to close on its .initial test. After this valve was serviced and the hyd lines flushed it operated prOPerlY and passed the retest. Mark Womble performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspeCted the wellhouses on this location while witnessing SVS tests. All the Wellhouses and associated equipment appeared clean and in good condition Summary: I witnesSed SvS testing at BPX's PBU Drill Site 17. PBU DS17, 15wells 30 components 1 failure 3,3% failure rate - 19 Wellhouse inspections Attachment: SVS PBU DS17 12-15-00 CS X UnclasSified __ COnfidential (Unclassified if doc. removed ) Confidential' Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Mark Womble AOGCC Rep: Chuck ScheVe . Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe / PBU / DS 17 Separator psi: LPS 165 Date: 12/15/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 17-01 1800550 165 150 130 P P OIL 17-02 1800700 165 150 100 P P OIL , 17-03A 1972160! 165 150 110 P P OIL 17-04A 1960500 165 150 120 P 5 12/15/00 OIL 17-05 1800960 165 150 110 P P OIL: 17-06 1801320 17-07 1810660 165 150 140 P P OIL! 17-08 1810740] 17-09 1810900! 165 150 100 P P OIL , 17-10A 1991100! 17-11 18424401 165 150. 120 P P OIL 17-12 1842450 165 150 120 P P OIL 17-13 1841790 165 150 110 P P OIL 17-14 1841660 165 150 140 P P OIL 17-15A 1991310 17-16 1920910 165 150 -130 p p OIL 17-19A 1970550 165 150 130 P P OIL i7-20 1921150 165 150 120 P P OIL 17-21 1921250 165 150 130 P P OIL Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.3% [390 Day Remarks: Surface Safety on 17-4 failed to close, it was serViced and retested. Page 1 ofl SVS PBU DS17 12-15-00 CS.xls PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/13/98 RUN DATE RECVD 96-050 DIR SURV 96-050 DIR SURV 96-050 BHP 96-050 DLL/MLL 96-050 SSVD 96-050 Z-DENS 96-050 PROD PROF 96-050 7456 96-050 NGP TVD 96-050 NGP/RES MD 96-050 NGP/ROP MD 96-050 NGP/RES TVD 96-050 7596 96-050 7597 LR~SPERRY-17-04APB1 ~/S PERRY- 17 - 04A L~/SEPIA ~SEPIA ~/SEPIA ~SEPIA ~ 10600-11400 ~'ATLAS DLL/MLL/ZDL/GR ~r~8668-9o71 PB1 j~1o56o-12816 ~10560-11561 PB1 ~8668-9o68 ~ 4,5,7,10-12 SPERRY GR/RES ~T~4,5,7-9 SPERRY GR/RES PB1 05/09/96 05/09/96 1 04/16/96 1 04/16/96 1 04/16/96 I 04/~6/96 FINAL 08/08/96 1 09/10/96 FINAL 11/20/96 FINAL 11/20/96 FINAL 11/20/96 FINAL 11/20/96 01/29/97 01/29/97 10-407 tR~COMPLETION DATE DAILY WELL OPS R 3 /Iq/9~/ TO Are dry ditch samples required? yes ~ And received? Was the well cored? yes r{~. Analysis & description received? Are well tests required? /y~s ~ Received? Well is in compliance Initial COMMENTS C! I::! I I--I.- I I~ G S E i:IL/I I~ ~: S WELL LOG TRANSMYFrAL To: State of Alaska January 23, 1997 Alaska Oil and Gas Conservation Comm. Attn: Loft Taylor ~, 0~~ ,,~Oc~A ~4 ! ~ 3001PorcupineDr. 4(~ */~o ~(9..,~rA4 qLg. <>~4,r~c5 Anchorage, Alaska 99501 MWD Formation Evaluation Tapes - DS 17-04A, 17-04A PB1 & 17-04AL1 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention Yam Galvi~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3 LDWG formatted magnetic tapes w/th LIS listing. API#: 50-029-20498-01, 50-029-20498-70 & 50-029-20498-60 respectively. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company r'l Fi ICl_! IM G 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: ~- 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-20498-01 2" x 5" TVD Resistivity & Cramrna Ray Logs: 50-029-20498-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia DS 17-04A PBI: ~Co ' 2" x 5"MD Gamma Ray Logs: 50-029-20498-70 2"x 5" TVD C_ranuna Ray Logs: 50-029-20498-70 DS 17-04ALl: 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 HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS I LDWG TAPE+LIS ECC No. Run # 1 6642.00 Run # 1 6666.00 Run # 1 6676.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10319 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 8/5/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter D.S. 2-!0 75-~-©;5\ STATIC PRESSURE sURVEY 960710 I 1 D.S. 2-2,,2 [?..,- C)b,~ PRODUCTION. pROFILE 96.0704 I 1 D.S. 3-04 "/~- o~t INJECTION PROFILE LOG 960704 I I ......... ~,-.~ F D.S. 3-19 ?~-o~i ~_ PRODUCTION PROFILE LOG 960704 I I ,,, D.S: 3.-33 ~ --!(O INJECTION PROFILE LOG 960703 I 1 D.S. 4-32 -~'-OUL{ COMPENSATED NEUTRON LOG 960714 I 1 AUG 03 D.S. 6-20 ~?--"' I'Z.H PRODUCTION PROFILE 960707 1 I ~,~,,,~,,.,~;l&~_~Cotls. C(} . . /~10,;1~.~ D.S. 13-21 ~.2-- O'5'"'~ INJEOTIONPROFILE 960708 1 I ~l~{',Jlofa_qe D.S. 13-32 '~?..- t?-.'~ INJECTION PROFILE 960708 1 1 ,, , D.S. 15-1 ~?..-oo(~ PRODUCTION PROFILE LOG 960706 I 1 ,, , D.S. 15-36 ~'H- 0'3"2. PRODUCTION PROFILE LOG 960706 I 1 D..S. 16-27 cJ?-.-o~,.,o PRODUCTION PROFILE LOG 960704 1 1 D.S. 17-4A ~- O~O PRODUCTION PROFILE 960711 I I S I G N E D: _~~____~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. -- STATE OF ALASKA ALAS.,,,-, OIL AND GAS CONSERVATION C,.,MMISSION 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. 96-50 "3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20498-01 ~--,~'~:¢'~'i' 9. Unit or Lease Name '4. Location of well at surface -._ 2795' NSL, 4830' WEb, SEC. 22, T10N, R15Ei- Prudhoe Bay Unit At top of productive interval ,~ r.,, .~. ~~ '-.~ 10. Well Number 1855' SNL, 4006' WEb, SEC. 27, T10N, R15E ~`. ~_~,/~'__ i~.,. ~ !-.~~~¥ '~..Z-;~-,4¢.-', 11. Field17'04Aand At total depth Pool ~ ~ ~i-7'~. SNL, 3995' WEb, SEC. 27, T10N, R15E Prudhoe Bay Field / Prudhoe Bay '5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 69.78I ADb 028334 ,12. Date Spudded03/27/96 I13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' water depth' if °ffsh°re I 16' N°' °f C°mpleti°ns04/18/96 05/01/96 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set]21. Thickness of Permafros! 12816 9068 FT] 12816 9068 F'r] []Yes ©No I 2210' ME)! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, MLL, DLL, RD, Temp, ZDL, CHT, LWD/FE, GR, CCL, PFC, PCb 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-I'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM 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 and 400 sx Permafrost II 9-5/8" 47# L-80/S0095 Surface 7745' 12-1/4" 800 sx Class 'G', 300 sx Permafrost 'C' 7" 29# L-80 7547' 11311' 8-1/2" 190 sx Class 'G' 4-1/2" 12.6# L-80 11287' 12816' 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" 11176' - 11196' 11176' MD TVD MD TVD 3-1/2" 10745' 10690' 11399' - 11927' 9035' - 9053' 11929' - 12814' 9053' - 9067' 26. AC~D, 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-BBb GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~1~ I Flow Tubing Casing PressureCALCULATED ~ 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. RECEIVED ~'~; ~.-~, -] ;'~\ ~ JUN 0 3 1996 Form 10-407 Rev. 07-01-80 Submit In Duplicate .. 30. Formation Tests -" Geologic Man. · 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 11210' 8963' Top of Sadlerochit 11394' 9034' 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 Signed Tern,/ Jordan '~'~"/ ,'~ ~ Title Senior Drilling Engineer Date 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 199G Form 10-407 Rev. 07-01-80 Alaska 01t & Gas Cons. Commissiorp Anchorage SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO WellName: 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 ~,laska 0ti & Gas Cons. Commission Anchorage Operations Summary for: . -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 2 Operations Summary for:., -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 hole 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 RECEIVED JUN 0 3 1996 Alaska 011 & Gas Cons. commission Anchorage Operations Summary for: ,, -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 Casing in stands to 11311 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: .. -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 to 11745 ft. Held safety meeting. Drilled to 12122 ft. Held safety meeting. Drilled 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 1529ft (4.5 in OD). Rigged down Casirt(z, handling equipment. Ran Casing on landing string to 2500 ft. ~ ~ ~ ~/~D Page 5 Operations Summary for: -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 no. 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 1996 (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 Operations Summary for: .-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 RECEIVED JUN 0 ~ 1996 ~,laska 0il & Gas Cons, Commission Anchorage SPF '.~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/17-04APB1 500292049870 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 040896 MWD SURVEY JOB NUMBER: AK-MW-60037 KELLY BUSHING ELEV. = 69.78 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 7699.78 6846.31 6776.53 7745.00 6877.52 6807.74 7753.10 6883.28 6813.50 7844.79 6949.39 6879.61 7938.60 7016.70 6946.92 47 45 S 15.00 W . 44 58 S 10.01 W 10. 44 30 S 9.06 W 10. 43 17 S 1.31 W 6. 45 5 S 6.70 E 6. 00 2115.46S 525.19W 07 2147.38S 532.30W 11 2153.00S 533.25W 00 2216.22S 539.03W 25 2281.43S 535.89W 1229.17 1248.26 1251.82 1295.15 1345.91 7970.33 7038.85 6969.07 8001.24 7059.82 6990.04 8031.97 7079.96 7010.18 8063.90 7100.47 7030.69 8095.30 7120.71 7050.93 46 20 S 9.40 E 48 11 S 9.00 E 49 54 S 9.40 E 50 9 S 10.40 E 49 37 S 11.90 E 7.24 2303.92S 532.70W 6.06 2326.32S 529.07W 5.65 2349.23S 525.36W 2.53 2373.33S 521.16W 4.02 2396.89S 516.51W 1364.81 1383.95 1403.51 1424.30 1444.97 8125.10 7140.08 7070.30 8157.22 7161.12 7091.34 8187.98 7181.25 7111.47 8219.35 7201.61 7131.83 8251.34 7222.10 7152.32 49 16 S 14.10 E 48 53 S 16.30 E 49 21 S 18.30 E 49 41 S 20.40 E 50 37 S 22.70 E 5.72 2418.95S 511.42W 5.32 2442.37S 505.06W 5.15 2464.57S 498.14W 5.20 2487.08S 490.24W 6.24 2509.92S 481.21W 1464.83 1486.54 1507.71 1529.77 1552.82 8281.94 7241.37 7171.59 8313.54 7261.01 7191.23 8344.95 7280.21 7210.43 8376.57 7299.26 7229.48 8471.93 7356.18 7286.40 51 19 S 24.70 E 51 51 S 26.40 E 52 46 S 29.40 E 53 6 S 30.60 E 53 38 S 36.50 E 5.57 2531.68S 471.66W 4.55 2554.02S 460.98W 8.09 2575.98S 449.35W 3.21 2597.83S 436.73W 5.00 2661.55S 394.46W 1575.42 1599.20 1623.33 1648.03 1723.73 8567.15 7412.64 7342.86 8662.08 7469.25 7399.47 8756.64 7526.19 7456.42 8850.66 7583.90 7514.12 8944.53 7642.68 7572.90 53 37 S 37.50 E 53 9 S 36.60 E 52 46 S 37.30 E 51 30 S 37.20 E 50 57 S 37.30 E .85 2722.79S 348.31W .91 2783.60S 302.40W .71 2843.93S 257.02W 1.36 2903.02S 212.09W .58 2961.27S 167.80W 1800.14 1876.09 1951.32 2025.32 2098.28 9038.37 7702.43 7632.65 9132.84 7763.53 7693.75 9225.92 7824.19 7754.41 9320.91 7886.39 7816.61 9416.81 7949.59 7879.81 49 55 S 37.70 E 49 28 S 37.20 E 49 12 S 37.30 E 48 58 S 37.60 E 48 34 S 37.05 E 1.15 3018.67S 123.75W .63 3075.87S 79.94W .30 3132.07S 37.21W .33 3189.06S 6.44E .61 3246.42S 50.18E 2170.43 2242.28 2312.67 2384.25 2456.17 9511.00 8011.54 7941.76 9604.27 8072.30 8002.52 9698.79 8133.41 8063.63 9792.36 8193.65 8123.87 9886.75 8254.55 8184.77 49 11 S 36.20 E 49 30 S 35.90 E 49 56 S 36.20 E 49 54 S 36.70 E 49 43 S 37.30 E .95 .41 .52 .41 .53 3303.36S 92.51E 3360.57S 134.15E 3418.87S 176.58E 3476.46S 219.12E 3534.05S 262.52E 2526.84 2597.25 2669.00 2740.30 2812.16 ORIGINAL SPF Y-SUN DRILLING SERVICES ANCHOR3~GE ALASKA PAGE SHARED SERVICES DRILLING PBU/17-04APB1 500292049870 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 040896 MWD SURVEY JOB NUMBER: AK-MW-60037 KELLY BUSHING ELEV. = 69.78 FT. OPERATOR: ARCO ALASKA INC 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. 9981.26 8315.18 8245.40 10075.81 8373.78 8304.00 10171.66 8432.28 8362.50 10264.49 8489.86 8420.08 10356.69 8546.95 8477.17 50 28 52 53 51 52 51 27 52 1 S 37.40 E .81 3591.69S 306.50E S 37.90 E 2.58 3650.41S 351.81E S 38.60 E 1.20 3710.03S 398.81E S 38.70 E .46 3766.90S 444.29E S 38.20 E .74 3823.60S 489.31E 2884.45 2958.44 3034.22 3106.93 3179.21 10449.58 8602.74 8532.96 10552.63 8662.18 8592.40 10583.98 8680.05 8610.27 10615.55 8698.19 8628.41 10647.19 8716.35 8646.57 54 8 55 24 55 5 54 45 55 13 S 38.00 E 2.29 3882.03S 535.12E S 38.00 E 1.22 3948.36S 586.94E S 36.60 E 3.79 3968.85S 602.55E S 37.60 E 2.82 3989.45S 618.14E S 36.70 E 2.76 4010.11S 633.78E 3253.31 3337.30 3362.98 3388.73 3414.56 10679.43 8734.18 8664.40 10709.73 8749.87 8680.09 10738.76 8763.96 8694.18 10771.05 8778.63 8708.85 10802.57 8791.72 8721.94 57 35 60 2 61 50 64 8 66 46 S 34.00 E 10.16 4032.01S 649.31E S 31.60 E 10.55 4053.80S 663.35E S 29.60 E 8.64 4075.64S 676.26E S 26.30 E 11.54 4101.05S 689.73E S 23.60 E 11.42 4127.05S 701.82E 3441.24 3466.85 3491.74 3519.67 3547.12 10833.27 8803.15 8733.37 10864.25 8813.81 8744.03 10895.79 8824.74 8754.96 10927.84 8836.98 8767.20 10960.09 8850.70 8780.92 69 32 70 10 69 18 65 45 63 54 S 19.70 E 14.85 4153.53S 712.32E S 17.70 E 6.40 4181.07S 721.64E S 17.40 E 2.93 4209.28S 730.56E S 15.50 E 12.33 4237.68S 738.95E S 14.70 E 6.16 4265.86S 746.56E 3573.87 3600.63 3627.62 3654.40 3680.49 10992.05 8864.81 8795.03 11023.62 8878.78 8809.00 11053.94 8892.17 8822.39 11084.81 8905.89 8836.11 11116.49 8920.16 8850.38 63 40 63 46 63 47 63 27 63 0 S 14.40 E 1.11 4293.61S 753.76E S 13.30 E 3.14 4321.10S 760.54E S 13.10 E .59 4347.58S 766.75E S 13.40 E 1.43 4374.50S 773.09E S 14.00 E 2.21 4401.98S 779.79E 3706.00 3731.02 3754.92 3779.23 3804.19 11147.66 8934.36 8864.58 11168.94 8944.13 8874.35 11223.08 8968.84 8899.06 11251.72 8981.82 8912.04 11280.14 8994.69 8924.91 62 47 62 34 63 6 63 0 63 8 S 12.90 E 3.21 4428.96S 786.24E S 12.40 E 2.33 4447.41S 790.38E S 11.70 E 1.52 4494.52S 800.44E S 12.90 E 3.75 4519.46S 805.87E S 14.80 E 5.98 4544.06S 811.94E 3828.63 3845.15 3887.00 3909.23 3931.63 11310.65 9008.09 8938.31 11342.00 9021.24 8951.46 11373.85 9034.14 8964.36 11407.09 9046.40 8976.62 11438.78 9056.18 8986.40 64 47 65 35 66 38 70 4 73 57 S 9.40 E 16.80 S 5.20 E 12.43 S 5.00 E 3.32 S 3.40 E 11.25 S 3.70 E 12.31 4570.85S 817.67E 4599.07S 821.29E 4628.08S 823.87E 4658.89S 826.13E 4688.96S 828.00E 3955.44 3978.90 4002.27 4026.77 4050.46 SPE' '-SUN DRILLING SERVICES ANCHOPJtGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/17-04APB1 500292049870 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 040896 MWD SURVEY JOB NUMBER: AK-MW-60037 KELLY BUSHING ELEV. = 69.78 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11469.00 9063.44 8993.66 78 13 S 3.60 E 14.13 11497.45 9068.19 8998.41 82 31 S 3.00 E 15.26 11515.25 9070.10 9000.32 85 9 S .80 E 19.17 11561.00 9073.97 9004.19 85 9 S .80 E .00 4718.23S 4746.23S 4763.91S 4809.49S 829.86E 4073.54 831.48E 4095.51 832.06E 4109.10 832.70E 4143.54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4881.05 FEET AT SOUTH 9 DEG. 49 MIN. EAST AT MD = 11561 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 138.27 DEG. TIE IN POINT 7699.78' WINDOW POINT 7745' INTERPOLATED DEPTH 11561' SPE~ '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/17-04APB1 500292049870 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 040896 JOB NUMBER: AK-MW-60037 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 NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7699.78 6846.31 6776.53 2115.46 S 525.19 W 8699.78 7491.85 7422.07 2807.83 S 284.41 W 9699.78 8134.05 8064.27 3419.48 S 177.03 E 10699.78 8744.84 8675.06 4046.52 S 658.80 E 11561.00 9073.97 9004.19 4809.49 S 832.70 E 853.47 1207.93 354.46 1565.73 357.81 1954.94 389.21 2487.03 532.09 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/17-04APB1 500292049870 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 040896 JOB NUMBER: AK-MW-60037 KELLY BUSHING ELEV. = 69.78 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 7699.78 6846.31 6776.53 2115.46 S 525.19 W 853.47 7733.95 6869.78 6800.00 2139.64 S 530.79 W 864.17 7872.93 6969.78 6900.00 2235.60 S 539.01 W 903.15 8016.27 7069.78 7000.00 2337.43 S 527.30 W 946.49 10.70 38.98 43.34 8170.43 7169.78 7100.00 2451.92 S 502.16 W 1000.65 8327.83 7269.78 7200.00 2564.04 S 455.81 W 1058.05 8494.86 7369.78 7300.00 2676.40 S 383.47 W 1125.08 8662.97 7469.78 7400.00 2784.17 S 301.98 W 1193.19 8827.99 7569.78 7500.00 2888.88 S 222.82 W 1258.21 54.17 57.40 67.03 68.10 65.02 8987.49 7669.78 7600.00 2987.78 S 147.58 W 1317.71 9142.45 7769.78 7700.00 3081.69 S 75.53 W 1372.67 9295.60 7869.78 7800.00 3173.93 S 5.21 W 1425.82 9447.32 7969.78 7900.00 3264.67 S 63.96 E 1477.54 9600.39 8069.78 8000.00 3358.18 S 132.42 E 1530.61 59.51 54.96 53.14 51.72 53.07 9755.29 8169.78 8100.00 3453.72 S 202.18 E 1585.51 9910.30 8269.78 8200.00 3548.34 S 273.40 E 1640.52 10069.18 8369.78 8300.00 3646.23 S 348.56 E 1699.40 10232.27 8469.78 8400.00 3747.24 S 428.54 E 1762.49 10393.79 8569.78 8500.00 3846.58 S 507.39 E 1824.01 54.91 55.01 58.88 63.10 61.52 10565.99 8669.78 8600.00 3957.06 S 593.65 E 1896.21 10751.39 8769.78 8700.00 4085.49 S 681.61 E 1981.61 11003.27 8869.78 8800.00 4303.36 S 756.23 E 2133.49 11225.16 8969.78 8900.00 4496.33 S 800.82 E 2255.38 11512.71 9069.78 9000.00 4761.39 S 831.94 E 2442.93 72.20 85.40 151.88 121.89 187.55 11539.78 9072.18 9002.40 4788.35 S 832.41 E 2467.60 24.67 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPF' "f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/17-04A 500292049801 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 041896 MWD SURVEY JOB NUMBER: AK-MM-960313 KELLY BUSHING ELEV. = 69.78 FT. OPERATOR: ARCO ALASKA INC 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. 11310.65 9008.15 8938.37 11343.42 9021.16 8951.38 11375.15 9030.75 8960.97 11394.48 9034.36 8964.58 11425.97 9037.78 8968.00 64 68 76 82 85 47 26 21 7 24 S 9.40 E .00 4570.93S 817.71E S 3.70 E 19.46 4600.79S 821.12E S 3.30 E 24.99 4630.96S 822.96E S 1.81 E 30.74 4649.92S 823.80E S .50 E 11.21 4681.21S 824.43E 4570.93 4600.79 4630.96 4649.92 4681.21 11457.17 9040.52 8970.74 11490.36 9043.90 8974.12 11520.67 9046.88 8977.10 11552.04 9049.23 8979.45 11583.27 9050.60 8980.82 84 32 83 46 84 54 86 31 88 27 S 1.03 W 5.61 4712.29S 824.29E S 1.83 W 3.34 4745.29S 823.47E S 2.28 W 4.04 4775.44S 822.39E S 2.12 W 5.16 4806.69S 821.18E S 2.19 W 6.22 4837.86S 820.01E 4712.29 4745.29 4775.44 4806.69 4837.86 11617.19 9051.16 8981.38 11648.37 9051.21 8981.43 11679.44 9051.03 8981.25 11710.92 9050.54 8980.76 11742.41 9049.85 8980.07 89 37 90 10 90 29 91 17 91 13 S 2.10 W 3.46 4871.75S 818.74E S 2.09 W 1.76 4902.91S 817.60E S 2.37 W 1.34 4933.96S 816.39E S 2.90 W 3.05 4965.40S 814.95E S 2.30 W 1.91 4996.85S 813.52E 4871.75 4902.91 4933.96 4965.40 4996.85 11773.12 9049.54 8979.76 11804.31 9049.82 8980.04 11835.10 9050.43 8980.65 11865.97 9051.20 8981.42 11898.80 9052.19 8982.41 89 56 89 0 88 44 88 24 88 9 S 2.22 W 4.21 5027.53S 812.31E S 2.12 W 3.00 5058.70S 811.13E S 1.73 W 1.54 5089.46S 810.09E S 1.96 W 1.33 5120.31S 809.10E S .70 W 3.91 5153.11S 808.34E 5027.53 5058.70 5089.46 5120.31 5153.11 11929.74 9053.23 8983.45 11961.19 9054.36 8984.58 11993.36 9055.68 8985.90 12024.92 9057.11 8987.33 12055.80 9058.32 8988.54 87 58 87 55 87 20 87 28 88 1 S .37 W 1.21 5184.03S 808.05E S 1.06 W 2.20 5215.46S 807.66E S .16 E 4.20 5247.60S 807.40E S .74 W 2.87 5279.13S 807.24E S .97 W 1.96 5309.98S 806.78E 5184.03 5215.46 5247.60 5279.13 5309.98 12086.67 9059.17 8989.39 12118.23 9059.54 8989.76 12149.89 9059.73 8989.95 12175.34 9059.99 8990.21 12210.81 9060.39 8990.61 88 48 89 52 89 24 89 26 89 15 S .50 W 2.92 5340.83S 806.39E S .20 W 3.55 5372.39S 806.20E S .47 E 2.59 5404.05S 806.27E S 1.05 E 2.28 5429.49S 806.61E S 1.47 E 1.30 5464.95S 807.39E 5340.83 5372.39 5404.05 5429.49 5464.95 12243.29 9060.70 8990.92 12275.02 9060.93 8991.15 12305.46 9061.22 8991.44 12337.12 9061.57 8991.79 12368.70 9061.89 8992.11 89 37 89 32 89 20 89 24 89 24 S .78 E 2.41 5497.42S 808.03E S 1.29 E 1.63 5529.15S 808.60E S 1.61 E 1.22 5559.58S 809.37E S 1.13 E 1.53 5591.23S 810.13E S 1.41 E .89 5622.80S 810.83E 5497.42 5529.15 5559.58 5591.23 5622.80 ORIGINAL SPF' Y-SUN DRILLING SERVICES Ai~CHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/17-04A 500292049801 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 041896 MWD SURVEY JOB NUMBER: AK-MM-960313 KELLY BUSHING ELEV. = 69.78 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 12399.08 9062.08 8992.30 89 52 S 2.11 E 2.77 5653.16S 811.76E 12428.14 9061.90 8992.12 90 49 S 2.20 E 3.28 5682.20S 812.85E 12459.92 9061.48 8991.70 90 40 S 2.28 E .53 5713.95S 814.09E 12490.36 9061.12 8991.34 90 40 S 2.33 E .16 5744.36S 815.32E 12522.22 9060.68 8990.90 90 53 S 2.21 E .76 5776.20S 816.58E 5653.16 5682.20 5713.95 5744.36 5776.20 12585.02 9059.71 8989.93 90 53 S 2.74 E .84 5838.93S 819.29E 12616.49 9059.35 8989.57 90 24 S 3.33 E 2.44 5870.35S 820.96E 12647.47 9059.56 8989.78 88 49 S 4.06 E 5.59 5901.26S 822.95E 12678.73 9060.74 8990.96 86 51 S .15 E 14.00 5932.47S 824.10E 12710.61 9062.44 8992.66 87 2 S 4.87 E 14.80 5964.27S 825.49E 5838.93 5870.35 5901.26 5932.47 5964.27 12742.46 9064.11 8994.33 86 55 S 5.41 E 1.74 5995.95S 828.34E 12750.43 9064.51 8994.73 87 20 S 5.14 E 6.37 6003.87S 829.08E 12816.00 9067.54 8997.76 87 20 S 5.14 E .00 6069.11S 834.94E 5995.95 6003.87 6069.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6126.27 FEET AT SOUTH 7 DEG. 49 MIN. EAST AT MD = 12816 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 180.00 DEG. TIE IN POINT 11310.65' INTERPOLATED DEPTH 12816' 'f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SH3kRED SERVICES DRILLING PBU/17-04A 500292049801 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 041896 JOB NTJMBER: AK-MM-960313 KELLY BUSHING ELEV. = 69.78 FT. OPER3kTOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAlqGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11310.65 9008.15 8938.37 12310.65 9061.28 8991.50 12816.00 9067.54 8997.76 4570.93 S 817.71 E 2302.50 5564.76 S 809.51 E 3249.37 946.87 6069.11 S 834.94 E 3748.46 499.09 THE CALCULATION PROCEDURES /kRE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE'~'-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/17-04A 500292049801 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 8/96 DATE OFSURVEY: 041896 JOB NUMBER: AK-MM-960313 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 11310.65 9008.15 8938.37 12816.00 9067.54 8997.76 4570.93 S 817.71 E 2302.50 6069.11 S 834.94 E 3748.46 1445.96 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS f , AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Dear Mr. Grant. Re: Distribution of Survey Data 17-04A May 8, 1996 Enclosed are two hard copies of the above mentioned file(s). q. iF~'33/eil 17-04APB1 MWD survey, tie in point 7,699.78', window point 7,745', interpolated depth 11,561' g.{~-5'~Well 17-04A MWD survey, tie in point 11,310.65', interpolated depth at 12,816' 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, f / ../ i /.' ,?./. Sand~a Lufkin Dept. Specialist Attachments. . ,.---~.,a 0il & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 A ~ Industries, Inc. Company APR '~ o '18'96 Alaska Oil & Gas Cons. commiss~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: I:LE: 15 April 1996 Transmittal of Data ECC #: 6642.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: ARCO 17-04& PRUDHOE BAY NORTH SLOPE Enclosed, please find the data as described below: Prints/Films: 1 ZDL FINAL BL+RF Run # 1 DLL/MLL FINAL BL+RF Run # 1 L-~ BH PRO FINAL BL+RF Run # 1 ~-t SSVD FINAL BL+RF Run # 1 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 (907) 563-7803 Date: ALASI~ OIL AND GAS CONSERYATION COMMISSION 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 0 Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit 17-4A ARCO Alaska, Inc. Permit No. 96-50 Sur. Loc. 2795'NSL, 4830'WEL, Sec. 22, T10N, R15E, UM Btmnhole Loc. 1979'NSL, 4533'WEL, Sec. 27, T10N, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtairfing additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention e. quipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. DavidchairmanW. Joh~ BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill E]llb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII 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 3407' NSL, 4070' WEL, SEC. 27, TION, R15E 17-4A U-630610 At total depth 9. Approximate spud date Amount 1979' NSL, 4533' WEL, SEC. 27, TION, R15E 03/06/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 028331 3301 feet No Close Approach feet 2560 12975' MD/9042' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth z99s feet Maximum hole angle s9 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement 'Hole Casing Weight Grade Coupling Length MD -FVD 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 1650' 11325' 9007' 12975' 9042' 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 Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby certify that the ~regoing is true and correct to the best of my knowledge Signed /¢-~,{/,(/ / ~,*"- Title Senior Drilling Engineer Date Commission Use Only Permit Number [APl number Approval d~ate . See cover letter ~'~' -0/'0 150- 0.-~.¢'- -~--0 L/'~¢" o/ ~ ..-'~--,,~"~:~ for other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes ~ No Hydrogen sulfide measures .1~ Yes [] No Directional survey required ~ Yes [] No Required working pr~l~fl~(~.~:t~ :.~I-12M; []3M; ~5M; I-IIOM; I-I15M- Other: David W. Johnston by order of Approved by Commissioner me commission Date~- ~..~'~ Form 10-401 Rev. 12-1-85 Submit in triplicate Well Name'. DS 17-4A DS17-4 L1 Well Plan Summary IType of Well (producer or injector): IProducer I Surface Location: 2795' FSL, 4830' FEL Sec 22 T10N R15E Start of Horizontal Location: End of Horizontal Location: Start of Horizontal Location: End of Horizontal Location: 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: IEstimated Start Date: Iunkn°wn I IMarch 6, 96 IMD#1 I 12975' IMDg2 I12595' Rig: I Nabors 2ES I I Operating days to complete: I rw: 19,042' I I TVD: 34 I }~T-{~L 13o.8' I KBE: 64.05 [8954' lWell Design (conventional, slimhole~ etc.) IHAW, 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: A 9.8 - 10.20 ppg Biozan polymer / KC1 water based mud will be used. lSpecial design considerations [ none DS 17-04A / L-1 Redrill Plan Summary Page 1 Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10 10 15 5 10 10 0 5 to to to to to to to to to Target 10.2 18 30 15 29 5 0 8 Production Mud Properties: Depth Density (PPG) Initial 8.9-9.1 Final 8.9-9.1 Marsh Viscosity 50-60 50-60 I 6" hole section: FIo-Pro Polymer Yield 10 sec 10 min Point gel ~lel 30-40 15-20 18-24 30-40 15-20 18-24 pH Fluid Loss 9.5-10.5 <6 9.5-10.5 <6 Directional: I KOP: 17995' MD / 7039' TVD I Maximum Hole Angle: 89° through the target Close Approach Well: none Casing/Tubing Program: Hole Size Csgt Wt/Ft Grade Con Length Top Btm Tbg O.D. n MDfrVD MDfrVD 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 9.2# L-80 TDS 11100 Surface 11100/8913 Cement Calculations: I Liner Size: I 7" drilling liner Bas :150% open hole excess, 80' shoe joint, 1000' MD above the Sag River. Total Cement Volume: I 3501sxs°fClassGBlend @ l'17ft3/sx(EstimatedV°lume Liner Size: 1 4.5" both production liners is slotted ( NO CEMENT DS 17-04A / L-1 Redrill Plan Summary Well Control: Page 2 Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, 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 ) DS 17-04A / L-1 Redrill Plan Summary Page 3 , 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 Saq 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. RU electric line (multi-conductor cable) unit. 18. PU Baker ML packer and RIH on No. 20 E-4 setting tool (with slow 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') 4-1/2" 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 DS 17-04A / L-1 Redrill Plan Summary Page 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) DS 17-04A / L-1 Redrill Plan Summary Page 5 23. 24. 25. 26. 27. 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. Grind off any excess pin sticking out above the whipstock backside. TIH slowly (_+90 seconds per stand). Avoid any abrupt stops which could cause the pin to shear prematurely. Set the slips cjently 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. 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. 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. Assure positive "latch up" by PU _+15K over earlier recorded PU weight. Slack off 40-50K at the whipstock to shear bolt. Free rotation of the drillstring will indicate that the pin is sheared. Once sheared from the whipstock, displace well with reconditioned FIo-Pro mud. Window Millino Procedure 28. Begin cutting window using only enough WOB and RPM to cut as smoothly as 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. Aisc, 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 DS 17-04A / L-1 Redrill Plan Summary Page 6 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 original 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 0.00 50 10 3000 1000 0.50 50 15 3000 2000 0.75 50 20 3000 2000 1.00 50 30 3000 2000 1.50 50 35 3000 3000 2.00 50 40 3500 3 - 5K 2.50 80 45 4000 5000 3.00 80 1 hr 10 4000 5 - 6K 4.50 80 1 hr 20 Reaming 5.00 30 1 hr 30 3500 4000 5.25 80 1 hr 45 2500 4000 6.50 80 1 hr 55 3000 4000 7.00 80 2 hr 10 2500 4000 7.75 80 2 hr 20 3000 5000 8.00 100 2 hr 30 3500 5000 8.50 100 2 hr 45 4000 5000 10.0 100 2 hr 55 Reaming 12.0 30 3 hr 10 3500 Formation 14.0 100 3 hr 20 Formation 16.0 100 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. DS 17-04A / L-1 Redrill Plan Summary Page 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 (-I-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,~ ......... , ...... DS 17-04A / L-1 Redrill Plan Summary Page 8 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" slotted (top 1/2) x blank (bottom 1/2) "circulating joint" Baker C-2 setting tool with 6' sleeve extension 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. DS 17-04A / L-1 Redrill Plan Summary Page 9 36. MU Baker C-2 setting tool (installed in the setting sleeve) to 2-1/16" internal 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 unable 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 Page 10 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 casinq 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) DS 17-04A / L-1 Redrill Plan Summary Page 11 3-1/2" DP 5" DP CONTINGENCY TOOLSFOR 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. 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 1/2" WLEG · 3 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint · 3 1/2", L-80 Otis "XN" Nipple (2.725" ID) · 3 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint · 3 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint · 3 1/2", L-80 Otis "X" Nipple (2.813" ID) · 3 1/2", 9.2#, L-80 BUT-MOD full joint · 3 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint · 3 1/2" X 7" Packer · 3 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint · 3 1/2", 9.2#, L-80 BUT-MOD tubing joint · 3 1/2", 9.2#, L-80 BUT-MOD 10 ft pup joint · 3 1/2", 9.2#, L-80 BUT-MOD tubing with GLM's GLM's Depths to be determined later. · 3 1/2", 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 52. 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. DS 17-04A / L-1 Redrill Plan Summary Page 12 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 DS 17-04A / L-1 Redrill Plan Summary Page 13 Ma~-01-96 17:34 Anad~ I DPC 907 r--~.4 2160 P.OS il II I I ii I~i VERTTCAL SECTION VIEW ! Section at: 197.84 ' , TVD Sca]e.' ~ inch = 1200 feet ' J Dep Scale.' ~ inch = 1200 feet , Drawn · 03/01/96 im I .,~ ............ ' ~lna~rJ ]] $£h]u~berger ! ~ i · i -' Marker ~den~if~catJon MD BKB SECTN INCLN i " A) TIE-IN SURVEY 7gB~ ?o~g ~39§ 48.00 B) TOP OF WINDOW 7995 7039 ~407 47.99 m ~ C) KOP CURV£ 7/100 8000 ?04~ 24t! 47.99 ~ ............ ! ........ I ........ D) END 7/~00 CURVE 8660 748~ ~820 53.84 i E) STAFIT CURVE ~§/~00 10938 8826 3796 53.84 " F) END 15/lO0 CURVE 1i033 8878 3847 59.84 G) START CURVE 1§/100 11~42 8933 39t6 59.64 ) -t ' ' H) 7" LINER POINT 11475 9025 4207 89,35 J I) END ~5/100 CURVE 11475 9025 4207 89.35 ,. , ' i J) TARGET (BSL) 1~475 90E5 4~07 89.35 t ..... ~ ................. J K) TD (ESL) i2975 9042 5707 B9.35 ~ I % i,k--~' - ~8(; - -'C ........................ ' - ' - i ! ANAr)RILL AKA-DFiC t ................ ~; ......................................... i · I ~' I ~ i · · · · ................... ti ~ ........ ! ............ · , s-'% : - ' , ..... L ~- ...... ' ......... '..: .......... ---: ' . !, ....... .~ ............ ,-.-: ..... ...... - ~.__: .... .: ..... ' ' - ' ' r ................. ! ....... ¢.- ........... ~'.,:."" -' '~'-'~- '~' ~ -" 'i' ' , / \ '-'"-, '--':'":":'"~" ............ . ..... + ..... ...... .. ...... _,__.,__ 'm 8 I I I I I I I m I I I m I I I I ~ I IIIII ~ ~ I I I I l~Ii II i ~ i~I~ii~ ~ I I I I I I I I I I I I II!II ~i~¢ ~tj.L~'~'~ ~ ~ :::::::::::: ::::::::::::::::::::::::: ::::::::::::::::::::::: .... ::::::,::::::::::: :::::::::::.::::: :~;:::::::::::::: :::: ,~,~.,,~--- :- . ............... ~ .................................. ~ .... ~~ ~?:~: _: .... . .................. , ........ ~ _ ~. q - , ...... ...... ~ .................... ~ .......... ~ ...................... . __~ __ _~ ~ ~- ~ ,.-i 0 600 i200 1800 2400 3000 3600 Section DepartuPe (Ana~ril] Ic)96 ~?04AP3 3.0b.02 ~: 30 PM P) 4200 4800 5400 6000 6GO0 7~00 7800 17;35 Anadri DPC 907 .,~ 2160 P.07 Mar-O1-96 SHARED SERVICES DRILLING Marker Identification MD A) VIE-IN SURVEY 7981 B) TOP OF WINDDW 7995 C) KOP CURVE 7/100 8000 D) END 7/100 CURVE 8660 E) START CURVE 15/100 10938 F) END 15/100 CURVE ~1033 G) START CURVE 15/J00 lJJ42 H) 7" LINER POINT 11475 I) END t5/lO0 CURVE 1~475 J) TARGET (BSL) 11475 K) TD (ESL) 12975 i m mm mlm N/S E/W 2337 S 596 23~40 S 598 W 2799 S 506 4206 S 679 E 4273 S 72<{ E 4358 S 760 E 4667 S 769 E 4667 S 769 E 4667 S 769 E 6095 S 309 E mi m I i m m i I I DS 17-0~A (P3) HA SIDETRACK PLAN VIEW CLOSURE ..... : 6103 feet at Azimuth 177,10 DECLINATION.: +28.66~ (E) SCALE .......: 1 inch = lO00 feet DRAWN .......: 03/01/96 I /~nadrj ]] Sch]umberger II 2000 1500 lOOO 500 0 500 JO00 i500 2000 2500 3000 3500 <- ~EST' EAST -> IIIILI SHARED i i SERVICES DR' "LLIN¢' iiii _ i i ,4nadr'j ]] $ch]u,'/;berger iiiiii ii iii ii iii ii ell I II I DS 7-04A (P3) MULTI-LAT VERTICAL SECTION VIEW Section at: t66.68 ,: ~ '[VD Scale 1 inch = 200 feet ,, :, I~ JDep Scale · 1 inch = 200 feet ......i. _[.'; ., . ................... , ; . i,, IIDra~n .... '03/01/915 · j ANADi~ILL /~KA-DP' . , ~LL tDS17-~AL1 IMULTI I i ~AR~ ~)1 ~D MD ACCO. ............... i ......... ~ 111~' 11195' CURVE40.0'/100', J TO AZ lS6.2S', FRM 8914' WD TO 8933' WD B i j jNJ JlAL.~~ ..... ~. 11195' 11227' DRILL TANGENT TO CURVE POINT. HOLD INC 95.91% ON AZ 156.26°, B J j 11227' 11259' CURVE 40.0'1t00,. ..... j ...... j ............. j FRM IN6 95.91' fO INC 88.89% FRM AZ lB J : . i J , 11259' 12595' PRILL HIGH ABGLE MULTI-~T. .... ._.__. i , - i ¢ '~o~' ~ : - . 'r~m-~m'' TA~nq- -2_ "- . j ~ ........... . I i~ J ,,, ,. I:::i~ J '" ~.: .;:~ . ' ............· ~ 'L~ .L..: ,.~ I ':' ' , ."' '-' i ~ ; : : ' i:'.. i ~ ,' Z;' - ~ .... ~ ~ ~ .............. . . :.'.~-; - ............................................... . "L~...::~ . ~ · . . I . I ...... ~ ___ 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 ~ 5300 5400 ~00 ~00 5700 ~00 5900 6000 Section (~a~rill (C)~ /704ALP3 3.0b,02 ~ 42 ON P) Ji Ma~-O1-96 17:41 AnadY'i 'i I DPC 907 ~. ,- 2160 P. 16 SHARED SERVICES Marker Identification MD' N/S A) TIE-IN CURVE 40/100 li104 4329 S B) END 40/100 CURVE 1t195 4408 S C) CURVE 40/100 tt227 4438 S D) END 40/300 CURVE 11259 4468 S E) TARGET 11259 4468 S F) lO 12595 5767 S E/W 782 795 ~ . 805 805'E 3113 E DRIL.....NGLI . . _ ,, DS' 1_7.-04A (P3) MULT I-LAT PLAN VIEW i i CLOSURE. · 5874 feet at Azimuth 1§9.08 DECLINATZON.' +28.661 (E) SCALE · 1 inch = 1000 feet DRAWN · 03/01/96 ~nadri l ] Schlumberger 3 - --') KB _ _ , / · · , ./ AN/~DRILL AKA-f)PC ' / ,t 1- ~ ~ ~ ) j J , , , ~ ...... ..........................._~' ~ ' ................ 1 ....... : it~ I · , 3500 ~n~ ,~ 2000 1500 1000 500 0 500 t000 1500 2000 2500 3000 3500 <- ~ffSl' EASI-> flnad~ill fr)~ ~Tfl~ q nh ~3 ~ ao n~ n~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Alter casing ~ Change approved program ~ Suspend ~ Operation Shutdown Repair well Plugging x 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Pull tubing ~ Vadance ~ 4. Location of well at surface 2486' FNL, 450' F1/VL, Section 22, TION, R15E, UM 5. Type of Well: Development Exploratory Stratigraphic Service Re-enter suspended well ~ Time extension Stimulate Pedorate~ Other x Plug Back for Sidetrack 6. Datum elevation (DF or KB) KB = 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 17-4 At top of productive interval ~ 9. Permit number 1753' FNL, 1040' FEL, Section 28, TION, R15E, UM ~ 80-85 At ~e, ff, ective depth - ~ J JD / ~ J"' A "~J~' 1~~ 2176 FNL, 1351'FEL, Section28, T10N, R15E, UM tJUlLi l,,,/"-~ [ ~ 50- 029-20498 At t.o, tal depth 2176 FNL, 1351' FEL, Section 28, TION, R15E, UM ~ ) Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured 11955 feet /Plug? (measured) Fill a~ 111 ¢4' MD (6/94) true vertical 9653 feet J / ' , Effective depth: measured 11004 feet / kJ/k (measured) Casing kenCh Size Cemented- Mea¢~red depth lrue vertical depth Conductor 80',- 2~"/ ~ 390 sx ASI' / 110 /i 110 S ace / Intermediate 10644 9-5~' 8001CI~'&3OOsxPFC / 10680' / 8685' ro uo io. /_-. \ J ,, / , , , Liner 1528' / 7" \ I 550 sx CIG /10360 - 11950:- ,Z/ .. ~ ~ ~.~ ~;~,50 Perforation depth: measured 11f9-11045',1i140X}~/O' · , , , , true vert,ca18~'-8958, 9029-f44 / Tubing (size, grade, and measured ddt__th 4-1/2", 12 , L-8O, PCTat40'M; 13. Attachments Description summary of proposal ~ Detaile¢ op~ons program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: March 1, 1996 16. If proposal was verbally approved Oil x GaS Name of approver Date approved Service 17. i hereby c/~. that. the for~o~g~,~ue and correct to the best of my knowledge. 7/ Signed /,~_(~.~~~~, Title Senior Drillin~ Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Date ~' / J~'~' Approval No.~ (F' O z//~ Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST FIELD POOL PROGRAM: exp [] dev [] UNI # redrll~ serv [ ON/OFF SHORE -- ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............ 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR DATE 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... Y~ N 19. Casing designs adequate for C, T, B & permafrost .... ~J 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 50~ 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 N N J 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 .......... y N /~/, ,~ e N/ -- -' 33. Seabed condition survey (if off-shor ) ........ ~/~ N ' 34. Contact name/phone for weekly progress reports . . . ~. Y N [exploratory only] ~ REMARKS GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN . -x~", ~ D,.~_ TAB { /':' ~'~'- '~' Comments / I nstruction~: HOW/Ijb - A:\FORMS\cheklist rev 11/95 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subf'ile 2 is type: TAPE HEADER PRUDHOE BAY I/NIT NELL NAME: OPERATOR: ,-, ?~ %1;\ ,ossiN GOB DATA ~ RUN GOB NUMBER: AK-lV~i- 960313 LOGGING ENGINEER: W. ALLEN OPERATOR WITNESS: J. CARLILE 17-04A 500292049801 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 22-JAN- 97 MWD RUN 5 W. ALLEN J. CARLILE MWD RUN 7 W. ALLEN E. VAUGHN MWD RUN 10 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 J. PANTER E. VAUGHN MWD RUN 11 J. PANTER E. VAUGHN 22 i0N 15E 2795 4830 69.78 68.38 28.65 MWD RUN 12 J. PANTER E. VAUGHN OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.625 7550.0 3RD STRING 8.500 7.000 11311.0 PRODUCTION STRING 6.000 12816.0 REMARKS: MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. WELL 17-04A IS REPRESENTED BY RUNS 1-5, 7, AND 10-12. RUNS 1-3 ARE DIRECTIONAL ONLY AND NO DATA IS PRESENTED. RUNS 4, 5, 7, AND 10 ARE DIRECTIONAL WITH GAMMA RAY (SGRD). RUNS 11 AND 12 ARE DIRECTIONAL WITH GAMMA RAY (SGRC), AND ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4). GAMMA RAY DATA FROM 10494' TO 11370' ACQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTOR, AND IS DENOTED AS NGP/SGRD. GAMMA RAY DATA FROM 11370' TO 12774' ACQUIRED WITH DUAL GAMMA RAY, GEIGER MULLER TYPE DETECTORS, AND IS DENOTED AS DGR/SGRC. A MEASURED AFTER DRILLING (MAD) PASS WAS PERFORMED FROM 11373' TO 12783', AFTER DRILLING THE WELL TO TD DURING Mk RUN 12. WELL 17-04A HAS BEEN DEPTH SHIFTED. WELL 17-04A WAS KICKED-OFF FROM WELL 17-04A PB1 AT 11311'. WELL 17-04A WAS DRILLED TO TD AT 12816'. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10495.0 RP 11370.0 $ BASELINE CURVE CURVE SHIFT DATA FOR SHIFTS: GR (WALS, (MEASURED DEPTH) BASELINE DEPTH GR 10495.0 10494.0 10537.5 10536.5 10552.0 10552.0 10559.0 10559.0 10570.0 10570.0 10581.5 10580.5 10584.0 10583.5 10600.5 10602.0 10621.5 10623.0 10627.0 10628.5 10721.0 10722.5 10730.0 10731.5 10749.5 10751.5 10759.5 10761.5 10910.0 10909.5 10952.5 10950.5 10994.5 10993.5 11058.5 11057.0 11080.0 11077.5 11106.5 11105.0 11155.5 11156.0 11161.0 11160.5 11167.5 11166.0 11210.0 11211.5 11217.0 11218.5 11236.0 11239.0 11245.5 11249.5 11257.5 11263.0 11259.5 11265.0 11262.5 11268.5 11266.5 11273.0 11288.5 11287.5 11294.5 11293.0 11298.5 11297.0 11309.5 11306.0 12819.5 12816.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD all bit runs merged. STOP DEPTH 12778.0 12785.0 Open Hole, 08-Apr-96.) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 4 10560.0 11230.0 5 11230.0 11298.0 7 11298.0 11311.0 REMARKS: 10 11311.0 11417.0 11 11417.0 12234.0 12 12234.0 12816.0 MERGED MAIN PASS. CN WN FN COUN STAT /??SHIFT.OUT $ : ARCO ALASKA, INC. : 17-04A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 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 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 151 Tape File Start Depth = 12820.000000 Tape File End Depth = 10494.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 37225 datums Tape Subfile: 2 291 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: Li~ FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: CN WN FN COUN STAT START DEPTH 11377.0 11384.0 STOP DEPTH 12779.0 12787.0 MAD RUN NO. MAD PASS NO. MERGE TOP 12 1 11377.0 MERGED MAD. $ MERGE BASE 12816.0 : ARCO ALASKA, INC. : 17-04A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 ROP MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 94 Tape File Start Depth = 12820.000000 Tape File End Depth = 11365.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet ~$~Xq 866 :M~6u~I p~oo~ mnmTx~M s~Xq ~9 :M~6u~I p~oo~ mnmTuTM smn~p 68~£E 89 :~poo d~ :X~mmns 6uTpoo~p @poo uo~e~u~ss~ds~ SI~ 0 0' : (NI) ,4,~OfIN-~fdlS ~IOO,L 000 ' 00' : (NI) NOILDZ~OD Z~OH :XLISNZ~ XI~itfI4 :XI~L~fN ~00~ NO~LflZN O· 0' S'8ST 0' 000 ' 000 ' 000 ' 000 ' 0'9 000~£ L'6 0'8£ 00'0T %t,WNX~IOd ~ID)t 0'0SS£ 00S'8 : (i~) HId~G ONIS~ S,~H%%IEG : (NI) ~ZIS ~I~ HqOH N~dO ~ DNIS~D ~N~ ~OH~O~ 0II d©N E~MflN ~O0~ E'OL 0 0'0£ETT 0'09SOI 0'0£ETI X~ON~N E~0'E 'I~0'E dHG ~£'l DSN 96-~d~-E0 (MO,I,,T,O~ O,T, dO,T,) DNIE,I,S ~IO0,T, 0'S9IIT H~G dOIS 'S~lT~ sq~z~dss UT un~ qlq qo~s zo~ eqep zsp~sq 5oi pu~ ~CSf~H ~I~ S~% :sd/iq sT ~ SIT~qns CN WN FN COUN STAT : ARCO ALASKA, INC. : 17-04A : 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: 18 Tape File Start Depth = 11240.000000 Tape File End Depth = 10494.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE ~TRAILER **** LIS representation code decoding summary: Rep Code: 68 41705 datums Tape Subfile: 4 81 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 0' :(ZH) : (NI) ,~,~OfIN-lf, T,S 000 ' 00' :(MI) NOIID~OD ~OH :X~ISN~G XIHilfI4 :XIHIRf~4 qOOi MOHiCaN , 0' I'0SI 0' 000 ' 000 ' 000 ' 000 ' 000E£ 9'6 0'£9 0E'0I 0'0SS£ 00~'8 : (i,~) H,T, dZG ©NIS~fD S ,%tZqqI%t~ : (NI) ZZIS LI~ ZqOH NZdO ~fi~f~ DNIStfD GN%f ZqOHZ%tO~ 0II ZdXi ~IO0,T, Z(IOD ~IO0,T, %~OGNZA (NO£LO~t O,T, dOi) DNI%~£S ~O0,T. I'£9 0'£9 0 0'86gII 0'0£gII 0'86EII gP0'g 'IP0'g dZ~ g£'I DS~ 96-~d~-P0 0'8~EII HLdZ~ dOiS QMM ~ZQ~ZH ZqI.~ s~q PIOI s~q E9 :q~BusI pxoosx mnmixeM :q~BusI pxoo~x mnmiuiN · ''spxoo~x £9 S :eIT~qns ede£ 89 :~poD dsH :Xx~mmns BuTPoosp spoo uoT~uss~xd~x SI% O0000S'O = 5uTo~dS T~% ~TT~ 000000'SPITZ = q~d~G puH ~IT~ 000000'S0£II = q~dsG ~P~S ~TTZ :sp~oo~M ~G I~Oi I0 018 06 P I0 0I£ 06 P Idtflf I 89 (IMI4 ~D I pon SlO ctKi clXi q~Bus% SzTS s~luQ S~ldm~S ~poD Tool sm~N :s~A~nD g ~ :Gl q~d~p IfXS~ : HdO%S HJZIOM : Xlf~t HOHflfl%Id : tfP0-LI : · DbII 'tf){S~ OOMtf : NflOO NM ND Tape Subfile 6 is type: LAS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11237.0 $ 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 11297.0 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 7. 06-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 11311.0 11298.0 11311.0 0 63.1 63.1 TOOL NUMBER NGP 110 8.50O 7550.0 KCL POLYMER 10.20 72.0 9.5 33000 5.8 .000 .000 .000 .000 .0 150.1 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. 17-04A 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: Tape File Start Depth = 11320.000000 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 42249 datums Tape Subfile: 6 66 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 O' : (ZH) AONMflO,WM,~ : (MI) ,~,~OQN%fLS ~IO0,T. 000 ' 00' : (MI) NOI£DZMMOD Z~OH :XLISNZ~ XIML~q4 :XIML~4 ~OOi MOMJJ1ZM . O' g' ££I O' 000 ' 000 ' 000 ' 000 ' S'£ 000IP /.'8 0'S9 00'6 OEd - 0~I,4 0'II£II 000'9 : (i,~) HidZ(I ©MIS~fD S .MZ~I~II%IG : (MI) ZZIS iI~{ Z~IOH M.~dO %f,T,~f(I DNIS%fD GN-~f Z~IOHZ~O~t ~ZSNflN ~OOL P'9L 8'P9 0 O'LIPII O'II£II O'£IPII gPO'g 'IPO'g dZG g£'I DSM 96-Ed~-SI 0'I££II HLdZG dOLS ZdX,I. ~IO0,T. ZGOD ~OO.T, EOQMZA (NO,T,,T,OM O,T, dOi) DMIELS ~IOOL 'SSIT~ sqexedss uT un~ qTq qo~ xo~ eqep xsp~sq 6oi pue seA. nD EZCDgZH M~I~ s~Aq ~IOI s~Aq ~9 :M~Bu~I p~oo~ mnm~xeM :M~Bu~i p~oo~ mnmTuTM · ''sp~oms~ £9 £ :sI~qns sd~i 89 : ~poD ds%{ :A~mmns Buipoosp spoo uoy~e~usss~d~ O0000S'O = Bu!o~dS I~AS% sI!~ O00000'09EII = q~ds~ puz sII~ 000000'SE~II = q~d~G ~S ~II~ I0 018 06 ~ I0 0I£ 06 ~ Id~c-~f I 89 (IMM HD poM sIO clKi clKi q2Bu@~ szys s~Tufl ssIdm~S spoD IOOi sm~M :S~A~nD E ~f~ S~F¢ : ZdO~IS HJ,HOM : X~f~ ZOHQ/1Hd : %fP0- LI : ' OMI '~Q{S~F~ OO%I%f : NiIOD NM ND Tape Subfile 8 is type: LiS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11361.0 EWR4 11366.0 $ 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 12193.0 12200.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 17-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 12234.0 11417.0 12234.0 0 83.8 91.3 TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 11311.0 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 9.00 63.0 8.4 41000 6.0 .090 .040 .060 .150 78.0 150.0 78.0 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 s~Aq 866 :q~BusI p~oos~ mnmix~M ss~Aq E9 :q~6u~I p~oo~ mnmyuIM smn~ep 8L~9~ 89 :~poD :A~mmns 6u~poosp ~poo uo~j~u~s~ds~ SI~ 00000E'0 = 5u~omds ISA~ ~I7~ 000000'0~£II = q2d~G puz ~I~ 000000'~E~I = q2d~G 2~2S ~I~ ~d~L 866 (0 #ZdXL) G~ODZ~ ~ ~ 8~ I0 018 06 5 I0 08I 06 5 9~ 0~I 06 5 9~ 0EI 06 5 9~ 0EI 06 5 9~ 0EI 06 ~ I0 0I£ 06 ~ poM SlD dXL dKi qq6u~q ~zIs s~u~ ssidm~S spoD IOO£ :soA~nD L (~9 #~cIXJ~) GHOD,W'~ ,T,~$4HO,q' .~ ~S~-~f : ~dO~S HLHON : X~ ~OHCK1Hd : ~0-LI : 'DNI '~ZS~f OD%Df : NiIOD NM : SM~ZH 0 0' : (ZH) XOixI,wfl~),wg~ gMZ : (NZ) ,~OnN-V~S qO0~ 000 ' 00' : (MI) NOI~OZ~OO :X~ISNZ~ qOOi 0'08 0'08 O' 0'08 0EI ' 090 ' 050 ' 080 ' 0'9 000I~ 9'8 0'09 0I'6 ogd - OTZ 0'II£II 000'9 : (i.~) HLdZ~ ~NIS~fD $ ,%tZT~IIg(I : (~II) ZZIS iI~t .~TOH NZdO ~fi~f~ ~NIS~fD ~N~f ZTOHZgO~ ~dSE0fi0d ~S~0~0d TOOL 6'06 6'98 0 0'918EI 0'5£EEI 0'918EI E~0'E 'I~0'E dZG ~£'I DS~ 96-gd~-6I ~ ' $I szg ' D~O~LDZ~IZ ~gMZ ZdX.L ~IO0.1. ZQOD ~lOOJ. gOQNZA (MOLLO~t OJ. dOi) ~1qIgiS TOO.L 0'IS£EI HLdZG dOLS 'ssI!~ ~xwd@s u! unx ~7q qoes zo~ ~ep xspmsq 6oI pue s~Axno 8 :gZ~qD_~I ZTI~ gZfSfZH Z~I~ SIT :sclKq s! 6 aIl~qns adeL REMARKS: CN WN FN COUN STAT MWD RUN 12. $ : ARCO ALASKA, INC. : 17-04A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 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 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 41 Tape File Start Depth = 12816.000000 Tape File End Depth = 12185.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35352 datums Tape Subfile: 9 Minimum record length: Maximum record length: 106 records... 62 bytes 998 bytes Tape Subfile 10 is type: ~S FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 12 MAD PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11373 . 0 12775 . 0 EWR4 11380 . 0 12784 . 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: 19-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 12816.0 11373.0 12816.0 0 86.9 90.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. 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S,q,T,X~ 866 ( 0 #,galA,T,) G%IOD,q%{ lf, T,tfG . 66 966 66 966 66 S66 96 66 ~66 ~6 66 966 96 66 ~66 ~6 66 S66 S6 po~ SlO ctKi clKi q~Bu@% azys :S~A~nD L (P9 #,gdX,T,) GEOD,~M J~O,~ ~ IC¢ Stfq~ : ,qdO~IS H,T.%IOM : Xlf~ ,qOHClfl%Id : lfP0- LI : · OMI '~IgSlfllf ODMIf : blflOO MM $ H~OH HHdl ,~0 dlflO OblIddI%IJ, H~IIHM GHkrMO.4HHd 'SStfd C :(ZH) ADMMflO,q.MM MM.q . · spuomss 9£'E = ~mT~ UOT~nm~xs pssd~I~ d9I:S L6 NtfP EE PsM :uoT~nosxs ~o ss~Xq E£I :q~BusI pxom~ mnmTx~ s@~Aq ~£I :q~BusI p~oDs~ mnmTu~ · ''sp~oo~x E IT :sIy~qns I0 I0 0'I9SII 00S'8 0'0SS£ S~9'6 (L,~) HLdZ~ (MI) aZIS (MI) ZZIS LIS SEZ~IE~ DMIS~fD Z~OH NZdO S9'8E 8['89 8£'69 MH~fltfA · Z EZLN-~fd ' .g :~ZAZ~ :EO0~ ~DI%F~tZ~ :©MIHS~S (0 ~SM MOE~ L~)NOIL~AZ~Z :~M~ :qZ~ :%S~ :~N~ :ZDN~f~ :dIHSNMOL :MOIL~ZS MOIL~DO~ ZD~EflS :EZZMIDMZ :EZSNflN SOP 8 N fiE (IMM NHDD~fA · Z MZ~Iq~f ' M L NflE (IMM Z~ii~iEtfD · £ MZ~Iqlf ' M S NflE OMW L6-NIfD-gE SZDIAEZS DMI%qIE~ Ni1S-XEEZdS 'DMI'tf){Stfq~ ODR-~f 0£86~0~6~00S ISd ~0-£I Z~II~IEIfD MZ~Iq-f II [096-BIM-)t~f Nile :SSZNLIM :EZSMFI6I SOD :edX~ ST 5 eIT~qns .@del FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10495.0 $ BASELINE CURVE FOR SHIFTS: UNKNOWN CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 10495.0 10494.0 10537.5 10536.5 10552.0 10552.0 10559.0 10559.0 10570.0 10570.0 10581.5 10580.5 10584.0 10583.5 10600.5 10602.0 10621.5 10623.0 10627.0 10628.5 10721.0 10722.5 10730.0 10731.5 10749.5 10751.5 1075915 10761.5 10910.0 10909.5 10952.5 10950.5 10994.5 10993.5 11058.5, 11057.0 11080.0 11077.5 11106.5 11105.0 11155.5 11156.0 11161.0 11160.5 11167.5 11166.0 11210.0 11211.5 11217.0 11218.5 11236.0 11239.0 11245.5 11249.5 11257.5 11263.0 11259.5 11265.0 11262.5 11268.5 11266.5 11273.0 11288.5 11287.5 11294.5 11293.0 11298.5 11297.0 11309.5 11306.0 11328.0 11329.0 11342.5 11345.0 11351.5 11353.5 11360.0 11362.0 11383.0 11382.0 11393.5 11392.5 11408.5 11409.0 11424.5 11427.0 11432.0 11431.5 all bit runs merged. STOP DEPTH 11511.0 EQUIVALENT UNSHIFTED DEPTH smn~p 00~9 89 :spoD :X~mmmns 6uypoosp spoo uoy~usss~ds~ SI~ 00000S'0 = 6uIm~ds ISASq SlI~ 000000'~6~0I = q~dsG pu~ sIY~ sd~i 000000'09SII = q~da~ ~S ~I~ 9~ :splotch e~eG Ie~ol ~ S~IA~ 9IOI (0 ~HdXi) GHOD~H ~i~G , IO 018 06 ~ IO 0I£ 06 ~ P I~tflf I 89 JM~ H© I pox slo clA£ clAi q~Bua% az!s :s~A~no E ~ :GI q~d~p sd~i tf~S~ : .~dO~IS HA%tON : AtfS MOHChqHd : ISd lfP0-/.I : · DMI 'tfMS~f%lf OD%Ill : ,l,flO ' ,l,.~ IHS 6 6/ ~IS NnOO NM 0'I9SII 0'ISPII 0'9S£II 0'86~II 0'0£gII MSiM Tape-Shbfile: 2 167 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE StIMMARY VENDOR TOOL CODE START DEPTH GR 10494.0 $ 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 11165.0 02-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 11230.0 10560.0 11230.0 0 54.7 70.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 110 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 7550.0 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: KCL POLYMER 10.00 78.0 9.7 32000 6.0 .000 .000 .000 .000 .0 158.5 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 4. s~Aq ~IOI :M;Bu~I p~oo~ mnmTxeN s~;Aq ~9 :M;bu~I p~oo~ mnmTuTN smn~ep 08~ 89 :~poD :A~mmns BuTpoo~p ~poD uoT~u~s~d~ 000000'~6~0I = qqde~ puz eITf edei 000000'05EII · = q~d~ 2~2S sI~ :sp~oosM ~G Ie~OL I0 018 06 P I0 0I£ 06 P P Id~f I 89 GMM ~© I pox sIO clKL clKi q~Bu@~ sz!s IdW IdV Id~ IdW s~!u~ ssIdm~S spoo IOOL :S~A~nO g ~Ot S~f~ : ZdO~IS Hi%tON : X~f~t ,qOH(Ifl%Id : I~d ~fP0-LI : · OMI 'k-ZS~l~g OOM~f : NflOD NM ND 0 0' : (ZH) XON~Wfl~),wH,~ lima : (NI) ~.~O(INtfdlS rIOOJ. 000 ' 00' : (MI) NOIID~wIIHOD ,W~IOH : X,I, ISN,WfI XI%I,LIfI4 : ~IO0,T, . 0' I'0~T 0' 000 ' 000 ' 000 ' 000 ' 8'S 000~£ 9'6 0'£9 0g'0I %{.WWJJIOd 0'0~£ 00~'8 : (MI) ZZIS iI~ Z~0H NZdO ~i~ DNIS~D ~Ntf Z~OHZ~O~ 0II dON I'£9 0'£9 0 0'86EII 0'0£EII 0'86~II A~ONZN ~0'~ 'I~0'E dZG E£'I DSN ZdX.T, ~IO0,T. Z(~OD ~IO0,T, %tOC[5IZA (NOLLO~ O,T, dOi) DNI~LS ~IO0.T. 0'8~EII HLdZG dOiS 'SSlT~ sq~d@s uT un~ qTq qo~ ~o~ ~q~p ~sp~sq 5oi pu~ S~A~nO ~ZESfZH Z~I~ SI~ :sclXq sT ~ SlT~qns sdei CN WN FN COUN ST~T : ARCO ALASKA, INC. : 17-04A PB1 : 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: Tape File Start Depth = 11305.000000 Tape File End Depth = 11145.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7364 datums Tape Subfile: 4 67 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 O' :(ZH) xD~,wnO~w~a ~Ms : (~z) ,~,~o~as ~O0.T. 000 ' 00' : (MI) NOIIO~HHOD ~OH :X~ISN~ XI~hq4 qO0£ MOHJ~i~N . O' I'0fiI O' 000 ' 000 ' 000 ' 000 ' 000££ 0'E£ 0E'0I 0'0~£ 00~'8 : (iM) H~MQ DNIS~D S,MM~IMG :(MI) MZIS ~IM M~OH MMdO ~ ©MIS~D ~Nlf ~OH~O~ 0II dDN .WdX.l. ~IO0.1. .qfIOD ~I00£ MOGNZA (NO.L.I.O~ O.L dO.L) ©MI%{.I.S ~IO0.1. I'£9 I'£9 0 0'9S£II 0'86gII 0'9S£II EP0'E 'IP0'E dMG g£'I DSN 96-E~-90 0'L6EII H£d~G dO~S STq :aclKq ST S sIT~qns s@~Xq ~IOI :q~6usI p~oos~ mnm!xeM ss~Xq E9 :q~BusI p~oos~ mnmyuiM · ''sp~oos~ £9 S :sIY~qns smn~p 56~S 89 :~poD d~ :J~mmns 6u~poo~p ~poo uo~u~s~d~ SI~ 00000S'0 = 5u~oedS IS~ sIT~ 000000'0£~II = q~d~ pu~ 000000'~9£II = q~d~ ~S ~I7~ :sp~oosH ~eG Ie~Oi I0 018 06 ~ I0 0I£ 06 ~ P HHd~ I 89 GMM dOE E P Id~r~f I 89 g/vK4 H~ I poM sID clX£ dXi q~6us~ szTs sqTuO ssIdmes epoD IOOi ~meM :S~A~nD ~ M :~I q2d~p Zk~ HZd HLdZG ~r~ S~r-itf : ZdO~IS H,T,%ION : X~f~ ZOHC~I%Id : I~d ~fP0-LI : 'OMI '~r)tS~ OO~%f : NnOD Tape Subfile 6 is type: FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11273.0 $ 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 11402.0 07-APR-96 MSC 1.32 DEP 2.041, 2.042 MEMORY 11451.0 11356.0 11451.0 0 64.8 69.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 110 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 7550.0 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: KCL POLYMER 10.20 71.0 9.6 33000 5.8 .000 .000 .000 .000 .0 141.6 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 8. s~qAq 9IOI s~qAq ~9 :q~6usI p~oosz mnmixeM :q~BusI p~oos~ mnmiuTH · ''sp~oms~ 89 9 :sIY~qns ~d~i smn~p 8£S8 89 :spoD ds~ :X~mmns Bu!poosp spoo uoy~usssxds~ SIq 00000S'0 = 5uIm~dS ISASq sIIS 000000'~9~II = q~d~G pu~ ~II~ 000000'09~II = q~d~Q ~S ~I7~ I0 018 06 ~ I0 0I£ 06 5 P HHd~ I 89 ~MI4 dOH ~ poM sIO clKL clKL q~6ua% azTs A~D A~D 5o% Id~ Id~ IdV Id~ s~Iu~ ssIdm~s ~poo IOOL sm~M :S~A~nD ~ lf~ St~f : ZdO~IS H,L%ION : Xlf~ ZOHf[fl%Id : I~td tfP0-LI : 'DNI 'IQ{StFI~ OOk~f : ND. OD N~ ND 000 ' 00' . O' 9 O' 000 ' 000 ' 000 ' 000 ' 0'0 000££ 9'6 0'g£ 0g'0T HZI, qA~IO4 ~ID>I 0'055L 005'8 0 0'I9SII 0'T5~II 0'I95II E~0'E 'I~0'g 4~Q ~£'I DS~ 96-~d~-80 · 6 Nfl%{ (IMM : (MI) .4,~O(INIf. I.S : (MI) NOI£DMMMOD M%OH :XIISMMG XIM£t~4 :XIMitfM ~oom MOMiflMM (~D~) ~Iflllf~l~d~Hi £Y (MMHO) AilAIISIS~ : (£O) SSO~ ~Iflq~ : (~d) S~I~OqH$ ~ :Hd flflM : (S) XIISODSIA C21M :~4A~ (IflbI SNOI&ICINOD ~%OH~O~ : (LM) HidZ~ ©NISVD :(MI) ZZIS iI~ Z%OH MZdO ~i~ ©NIS~D ~N-~ Z%OHZMO~ ZdX,l, ~I00,1, ZGOD ~IOOJ. %tOC~ZA (MOLLO~ OJ, dOi) DMIMLS ~IOOJ, O'EISII HLdZG dO£S CN WN FN COUN STAT ARCO ALASKA, INC. 17-04A PB1 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: 5 Tape File Start Depth = 11560.000000 Tape File End Depth = 11360.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6498 datums Tape Subfile: 7 68 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 8 is type: LIS 9?/ 1/ 9 01 **** REEL TRAILER **** 97/ 1/22 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 22 JAN 97 5:02p Elapsed execution time = 0.99 seconds. SYSTEM RETURN CODE = 0 'q~/~ SIHI ~0~ ~DN~E~ HA~G ~Hi ~Htf SOOq ~0 i~S SIHI '96-~-£E ~0 qI~5~-~ (ODH%f) SN~MO NDIG E~d 0'I9~II 00S'8 O'OOt£ S~9'6 (3..~) H3.d.~G (NI) .~ZIS (NI) ,~ZIS .~.I~ SHH~I~IIH~ ONIS%fD .~IOH N.~O 00'0£ 00' 8L'69 98~E N0I SNH~f~ .~.~S AH%fS.~ 00'E999 I N/1H 96-D~-SE SMDIAHHS DNIDDO~ SIUI~NMMISMM 'DNI tOISlfT~ OOM%f I08690E6E00S ~90-£I 'S'~ DNIH~S NOI~DQ~OHd DNIMIS fF6~ ~NI~AS fINE ~NIHZS iSI S' :~clK~ s! ~ siigqns AS PER CL TS REQUEST, ENVIRONMENTAI TORNADO C~IART CORRECTIONS WERE APPLIED TO DLL/MLL DATA. THE MLL WAS CORRECTED FOR THE EFFECTS OF MUD CAKE & AN "RXO" CURVE WAS OUTPUT. THE DLL DATA WAS CORRECTED FOR BOREHOLE EFFECTS. THE CORRECTED DLL DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RXO = RESISTIVITY OF FLUSHED ZONE RT = TRUE FORMATION RESISTIVITY DI = DEPT~ OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DLL SDN $ depth shifted and clipped curves; .5000 START DEPTH STOP DEPT~ 10505.0 11525.0 10523.0 11546.0 10491.0 11480.0 GR (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MLL LLD RHOB 10584.0 10584.5 10584.5 10584.0 10599.5 10599.5 10599.5 10673.0 10673.5 10695.0 10695.5 10703.5 10703.0 10704.0 10708.0 10708.5 10710.0 10710.0 10720.5 10720.5 10720.5 10720.0 10730.0 10730.0 10745.5 10745.5 10745.0 10749.0 10748.5 10749.5 10749.5 10759.5 10759.0 10804.5 10804.0 10852.0 10852.0 10896.0 10897.0 10895.5 10909.5 10909.5 10910.0 10910.0 10915.5 10915.5 10924.0 10924.0 10942.0 10941.5 10949.0 10948.5 10948.5 10952.5 10952.5 10951.5 10970.5 10971.0 10991.0 10991.0 10998.0 10997.5 11003.5 11004.0 11004.0 11003.0 11008.0 11007.5 11008.0 11008.0 11030.5 11030.5 11076.0 11076.5 11080.0 11080.0 11079.5 11106.5 11107.0 11138.0 11138.0 11160.5 11161.0 11159.5 11160.5 11216.5 11216.0 11217.5 11217.5 11220.5 11221.0 11228.0 11227.0 11236.0 11235.5 11235.5 all runs merged; no case · O~II kr/~ : ,~O~IS H,T,~ON : X~f~ .~OHOfl~ld : %f50-£I 'S'CI : 'kCE~ OOHlf : JJlO' IHD,T,kn~& 6 / NnOO ND S'£S£II S'SS£II S'£S£II S'OSEII O'SgEII S'E££II 0'EE£II 0'9IgII 0'80£II S'90EII S'~9gII S'09gII S'SPEII 0'9E£II S'60EII S'98~II S'09CII S'E9EII S'/.SEII 0'9SEII 0'E£EII 0'0I£II S'98EII 0'SSEII 0 ' 9L£Ii 0 ' 99EII S'LS~II 0'9SEII S'SS£II O'~SEZZ S ' '[S£'['[ 0'S~£II S'S£EII S'EEEII S'EE£II S'9I£II 0'0 0'6 S'9 S'9 S'S O'I S'8 S'9 O'S S'O I£II 0EII 0EII 9~II 9EII * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 LL3 DLL 68 1 OHMM 4 3 LLD DLL 68 1 OHMM 4 4 MLL DLL 68 1 OHMM 4 5 RXO DLL 68 1 OHMM 4 6 RT DLL 68 1 OHMM 4 7 DI DLL 68 1 IN 4 8 CALl DLL 68 1 IN 4 9 SP DLL 68 1 MV 4 10 MTEM DLL 68 1 DEGF 4 11 TEND DLL 68 1 LB 4 12 TENS DLL 68 1 LB 4 13 RHOB SDN 68 1 G/C3 4 14 DRHO SDN 68 1 G/C3 4 15 PEF SDN 68 1 BN/E 4 16 CALl SDN 68 1 IN 4 17 RB SDN 68 1 DEG 4 4 17 310 01 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 158 Tape File Start Depth = 11548.000000 Tape File End Depth = 10444.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet' **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 39763 datums Tape Subfile: 2 348 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 4 .2500 VENDOR TOOL CODE START DEPTH GR 10504.5 MLL 10554.0 DLL 10523.0 ZDL 10490.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ISO BRIDLE ISOLATOR ISO BRIDLE ISOLATOR KNJT KNUCKLE JOINT SWIV SWIVEL SUB CHT CABLEHEAD TENSION MODL MODAL SUB ZDL Z-DENSITY TEMP TEMPERATURE PCM PULSE CODE MODULATOR RB RB-SUB KNJT KNUCKLE JOINT MIS MASS ISOLATION SUB DLL DUAL LATEROLOG GR GAMMA RAY MIS MASS ISOLATION SUB KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT MLL MICRO LATEROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT) : STOP DEPTH 11525.0 11546.0 11514.0 11480.0 08-APR-96 FSYS REV. J001 VER. 1.1 2000 07-APR-96 1325 08-APR-96 11561.0 11557.0 10452.0 11553.0 1500.0 TOOL NUMBER 3997XA 3997XA 3921XA 3944XA 3974XA 3517NA 2222EA/2222MA 2806XA 3506XA 3975XA 3921XA 3967XA 1229EA/1229MA 1309XA 3967XA 3921XA 3921XA 1233XA 8.500 7700.0 .0 BOREHOLE COND I T IONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 17-04A : PRUDHOE BAY : NORTH SLOPE : ALASKA KCL POLYMER 10.20 71.0 9.6 5.2 191.0 .182 .070 .123 .000 .228 .000 69.3 191.0 69.3 .0 69.3 .0 2.65 .000 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Name Tool Code Samples Units GR MLL 68 1 GAPI C24 MLL 68 1 IN RXO MLL 68 1 OHMM CMLL MLL 68 1 MMHO RMLL MLL 68 1 OHMM RS DLL 68 1 OHMM RD DLL 68 1 OHMM RT DLL 68 1 OHMM DI DLL 68 1 IN SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN ZDEN ZDL 68 1 G/C3 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 20 310 01 1 4 20 280 24 1 4 20 935 02 1 4 20 260 04 1 4 20 270 03 1 4 17 220 09 1 4 17 220 10 1 4 17 120 46 1 4 17 120 44 1 4 17 010 01 1 4 17 660 99 1 4 17 635 99 1 4 17 635 99 1 4 17 636 99 1 4 46 350 01 1 16 ZCOR ZDL 68 1 17 PE ZDL 68 1 18 C13 ZDL 68 1 19 RB ZDL 68 1 * DATA RECORD (TYPE# 0 ) Total Data Records: 369 G/C3 4 BN/E 4 IN 4 DEG 4 966 BYTES * 76 46 356 99 4 46 358 01 4 46 280 13 4 46 631 01 Tape File Start Depth = 11548.000000 Tape File End Depth = 10444.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 88341 datums Tape Subfile: 3 457 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH GR 11312.0 MLL 11361.0 DLL 11330.0 ZDL 11298.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 11533.0 11553.0 11522.0 11488.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ISO ISO KNJT SWIV CHT MODL ZDL TEMP PCM RB KNJT MIS DLL GR MIS KNJT KNJT MLL $ BRIDLE ISOLATOR BRIDLE ISOLATOR KNUCKLE JOINT SWIVEL SUB CABLEHEAD TENSION MODAL SUB Z-DENSITY TEMPERATURE PULSE CODE MODULATOR RB- SUB KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB KNUCKLE JOINT KNUCKLE JOINT MICRO LATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 08-APR-96 FSYS REV. J001 VER. 1.1 2000 07-APR-96 1249 08-APR-96 11561.0 11557.0 10452.0 11553.0 1200.0 TOOL NI3MBER 3997XA 3997XA 3921XA 3944XA 3974XA 3517NA 2222EA/2222MA 2806XA 3506XA 3975XA 3921XA 3967XA 1229EA/1229MA 1309XA 3967XA 3921XA 3921XA 1233XA 8.500 7700.0 .0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: -MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 17-04A : PRUDHOE BAY : NORTH SLOPE KC POLYMER 10. ~.0 71.0 9.6 5.2 191.0 .182 .070 .123 .000 .228 .000 69.3 191.0 69.3 .0 69.3 .0 2.65 .000 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Name Tool Code Samples Units GR MLL 68 1 GAPI C24 MLL 68 1 IN RXO MLL 68 1 OHMM CMLL MLL 68 1 MMHO RMLL MLL 68 1 OHMM RS DLL 68 1 OHMM RD DLL 68 1 OHMM RT DLL 68 1 OHMM DI DLL 68 1 IN SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTENDLL 68 1 LB SPD DLL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 20 310 01 1 4 20 280 24 1 4 20 935 02 1 4 20 260 04 1 4 20 270 03 1 4 17 220 09 1 4 17 220 10 1 4 17 120 46 1 4 17 120 44 1 4 17 010 01 1 4 17 660 99 1 4 17 635 99 1 4 17 635 99 1 4 17 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 s~Xq 996 s~Xq E9 :q~Bu~I p~oD~ mnm!xw~ :q~Bu~I p~om~ mnm!u!~ · ''sp~oD~ 88I smn~p p0IP9 89 :spoD :Xa~mmns BuIpoo~p ~poo uoI~u~s~d~ SI% O000Sg'O = 6uIo~ds I~A~ ~I7~ ~d~ 000000'gS~II = q3d~G pu~ ~I7~ ~d~ 000000'9SSII = q~d~G ~S ~I!M I0 £I I£9 9~ 08~ 9~ 9£ 996 ~0I (0 :sp~osa~ e~eG Ie~O£ ~ D~G I 89 %GZ ~H 6I 9 NI I 99 q~Z ElD Tape Subfile 5 is type: biS 96/ 8/28 01 **** REEL TRAILER **** 96/ 8/28 01 Tape Subfile: 5 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes End of execution: Wed 28 AUG 96 4:22p Elapsed execution time = 2.52 seconds. SYSTEM RETURN CODE = 0