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Home My WebLink About194-164Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages' [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by~ Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ · m~ mmm ~mmm~ mm mm & LOC.~_TION CLEA_RA_,~CE REPORT State cf A_!aska 0iL & G~ CTN. S~iK~TION CCM/fISSION 1:=--~-'.-_ ar. du_~" -'--- '-~- Yil-=: .:.2i No. Well Name . Review ~e well file, an~-c=mme=: cz=. ptugcJ~-~g, well head . ~lu~s:snanus' ~/~7~~ !oca=i=n c!ea~c~'-~~~ ~ ~~=r~e !o.c. cle~. co~e. Well hea~ =ac o~f: .Har;~er pose er place: Conclusions: 1 . STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMM,,_,SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service .. 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 194-164 301-277 3. Address 8. APl Number P.O. Box 196612,'Anchorage, Alaska 99519-6612 ,~~. 50-029-22535-00 4. Location of well at surface ~~~ 9. Unit or Lease Name 2476'At topNSL'of productive1944' EWL,intervaiSEC. 31, T11N, R13E, UM S.~~ii~i1~ Prudhoe Bay Unit 3559' NSL, 981' WEL, SEC. 35, T11N, R12E, UM At total depth ~ ~¢'~ rr~ 10. Well Number 3603' NSL, 1062' WEL, SEC. 35, T11N, R12E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE - 88.04' ADL 028264 12. Date Spudded 01/08/1995 J 13' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'02/14/1995 10/13/2001 I15' Water depth' if °fish°re N/A MSL I16' N°' °f c°mpleti°ns Zero 17. Total Depth (MD+TVD)J 18. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV setI 21. Thickness of Permafrost' 13102 9214 ETI 12979 9097 FTI [] Yes [] NoI N/A MDI 1900' (Approx.) 22. Type Electric or Other Logs Run DIL / BHCS / GR / TEMP 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# NT-80 30' 3638' 13-1/2" 1046 sx CS III, 375 sx Class 'G' 7-5/8" 29.7# NT95HS 31' 13094' 9-7/8" 265 sx Class 'G' 24. Perforations open to Production (MD+'I-VD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 12618' 12570' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12673' Set Whipstock 12673' =&A with 20 Bbls Class 'G', Sqzd to 950 psi 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not On Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure !CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28.. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or waier. Submit core chips. ECEIVED DEft I ? ZOO/ ¢:it~ka 0il & Gas (Jer~s. fJ0rrunJssi0r, Form 10-407 Rev. 07-01-80 ORIGINAL ~rlc'h°ra~ubmit In Duplicate 29. Geologic Markers 30. Formation Tests , Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 12667' 8801' Shublik 12690' 8822' Sadlerochit 12803' 8929' RECEIVED 31. List of A~aohments: Summaw of Daily Drilling Repo~s 32. I hereby cedi~ that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e ~~ ~ Title TechnioalAssistant Date ~' f~'O/ P-07 194-164 301-277 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. iNSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 ~'~D 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: P-07A Rig Accept: 10/12/01 Field: Prudhoe Bay Unit Rig Spud: 10/15/01 APl: 50-029-22535-01 Rig Release: 10/23/01 Permit: 201-196 Drilling Rig: Nabors 3S PRE-RIG WORK 09/30/01 PPPOT-IC passed, MITOA passed, Wing and master passed, swab passed. 10/06/01 Drift tubing with dummy whipstock. 10/07/01 Pull gas lift valves and set dummy gas lift valves. 10/10/01 Run in hole with Baker whipstock. Log tie-in pass 12720' - 12510'. Tie-in and position whipstock at 12672'. PIP tag at 12682'. Whipstock tray orientation is 13 degrees left of high side. Tag to confirm set. BP EXPLORATION Page 1 ~ Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 10/23/2001 Rig Name: NABORS 3S Rig Number: 3S Date !From_ To HourS !Activity Code NPT Phase Description of Operations 10/12/2001 00:00 o 02:30 2.50 CONS P PRE Prepare grade and remove flowlines on P-07 pad. 02:30 - 08:30 6.00 RIGU P PRE Begin moving rig to P-07. PJU Nabors 3S and DS unit #4. 08:30 - 12:00 3.50 BOPSUF:P DECOMP Accept Rig at 08:30 hrs. N/U BOP stack. Called AOGCC and gave notice of BOP testing. 12:00 - 16:30 4.50 WHSUR 3 DECOMP Move over and r/u upright tanks and other skid mounted units. Install 2-way check in wellhead for bop testing purposes, grease choke manifold valves. 16:30 - 21:25 4.92 BOPSUF ~ DECOMP Pressure test BOP's and test H2S monitors 21:25 - 22:30 1.08 WHSUR 3 DECOMP Pull 2-way check. 22:30 - 23:00 0.50~ STWHIP 3 WEXlT ~Make up BHA and stab on well. 23:00 - 00:00 1.00 STWHIP N SFAL WEXIT Shut-down to repair wellhead pressure read out in coil cab. 10/13/2001 00:00 - 01:10 1.17 STWHIP N SFAL WEXlT Wait on repair of wellhead pressure transducer on coil unit. 01:10 - 01:45 0.58 STWHIP P WEXIT Pressure test hard lines. '01:45 - 02:15 0.50 STWHIP P WEXIT PJSM prior to killing well. 02:15 - 02:40 0.42 STWHIP N SF^L WEXIT Continue to wait on repair of wellhead pressure transducer. Finally found problem to be in the computer board in the coil cab. By-passed bad board and got good wellhead pressure readings on a different display. 02:40 - 03:15 0.58 STWHIP!P WEXIT Displace methanol from the coil to the open top tank. 03:15 - 04:15 1.00 STWHIP P WEXIT Pump 290 barrels of 140 degree seawater at 4.5 BPM to kill the well. Maximum pressure on the coil/tubing annulus was 1,075 psi. Pressure on the wellhead dropped to 0 psi in about 1 minute after shutting down the pumps. 04:15 - 07:00 2.75 STWHIP ~ WEXIT RIH with coil to tag the top of the whipstock at 12,672'. PU 10' and flag coil at 12,662'. Same time r/u cementers. 07:00 - 07:15 0.25 STWHIP 3 WEXIT PJSM covering safety and procedures for cement job. 07:15 - 10:00 2.75 STWHIP 3 WEXIT PT lines to 4000 spi. Pump 5 bbls water ahead then 5 bbls neat crnt followed by 12 bbls w/15ppb aggregrate then 3 bbl neat. Displ w/rig pump hold positve annulus pressure. Squeezed away first 10 bbls having good gradual increase in pressure to 950 psi. Layed in remainder 1:1to 12000'. Pulled to safety, closed choke and walk squeezed 4 bbls holding 950 psi. Cracked open choke and circulate 1:1 hold 100 psi on annulus for 30 min. 10:00 - 13:25 3.42 STWHIPIP WEXIT Dropped 13/16" ball and followed with 35 bbls 2% KCL w/ 1.5ppb bio. Make several passes jetting down WS and up through jewelry in tbg. 13:25 - 13:30 0.08 STWHIP P WEXlT L/D nozzle assembly and p/u swizzle stick to clean bop's. 13:30 - 13:45 0.25 STWHIP 3 WEXIT Wash BOP's 13:45 - 14:45 1.00 S'I'WHIP 3 WEXIT PT MHA 3500 psi 14:45 - 16:45 2.00 STWHIP ~ WEXIT P/U Anadrill TORQ tool and RIH to 130' to test. Performed ,okay for awhile then failed. 16:45 - 17:00 0.25 STWHIP 3 WEXIT L/D TORQ tool. 17:00 - 19:00 2.00 STWHIP 3 WEXlT Wait on Cement. 19:00- 19:20 0.33 STWHIP ~ WEXIT PJSM prior to PU milling BHA. 19:20 - 20:00 0.67 STWHIP, P WEXIT Pick up window milling BHA. (Cement lab called at 19:30 hrs and said that after 8 hours our cement had a compressive strength of 2384 psi. Maximum expected compressive strength for this blend is 2500 psi.) iZ0:00 - ZZ;4~ Z.7§ ~TWHIP P WEXIT RIH with BHA. 22:45 - 23:55 1.17 STWHIP P WEXlT Tag XN nipple at 12,614' CTM (12,602' ELM). Mill through Printed: 11/1/2001 9:39:53 AM bp EXPLORATION Page 2 ~ · Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 10/23/2001 Rig Name: NABORS 3S Rig Number: 3S Date i::i FrOm ~ To' Hours ActiVityCode NPT Phase Description of Operations 10/13/2001 22:45 - 23:55 1.17 STWHIP P WEXIT 3.725" XN nipple. (-12' correction to coil depth). 23:55 - 00:00 0.08 STWHIP P WEXIT 'RIH and tag the whipstock pinch point at 12,699' (the pinch I point on this whipstock is 4' below the top). (-11' coil correction with reference to the wireline corrected XN nipple depth). 10/14/2001 .00:00 - 00:20 0.33 S'I'WHIP P WEXIT Pick up and tag the whipstock again and found the pinch point at 12,699' CTM. Made a -11' correction to coil depth (the -12' correction plus the -11' correction at the whipstock add up to a total correction of-23'). 00:20 - 14:00 13.67~ S TWHIP: P WEXIT Begin milling window at 12,676'. Freespin was 2,750 psi at 2.7 BPM. Added .Sg Bio to system reduced PP and bettered weight transfer. Bleed down IA 1,000>900 psi. Milled down to 12,682' and appears to be drilling on formation but unable to make any hole (mill could be polished off). 14:00 - 18:00 4.00 STWHIPIP WEXIT Swapping over to Fie-Pro prior to TOH to look at mill. TOH laying Fie-Pro. 18:00 - 20:00 2.00 STWHIP P WEXlT Speed mill appears to have crossed casing while cuttting window but is undergauge 3.77" P/U another used speed mill from BP stock which is good shape and in gauge, reamer that is above mill in gauge and shows some wear. We believe window is cut just unable to make a few feet of formation. 20:00 - 21:30 1.50 STWHIP = WEXIT RIH with replacement mill to finish dressing off window. Tie in to coil flag at 12,676'. Made a -27' correction to coil depth. 21:30 - 22:05 0.58 STWHIP = WEXIT : Free spin 2800 psi at 2.7 BPM Work the mill through the window twice with pumps on and once with pumps off. Saw some minor motor work while passing through the window. Drilled to a TD of 12,688'. 22:05 - 00:00 1.92 STWHIPi P WEXIT POOH with milling assembly. 10/15/2001 00:00 - 01:15 1.25 STWHIPi P WEXIT Continue to POOH with window milling assembly. 01:15 - 01:30 0.25 STWHIP P WEXIT PJSM prior to laying down milling BHA and picking up drilling BHA. 01:30 - 02:00 0.50 STWHIP P WEXIT Lay down Window milling BHA. 02:00 - 03:30 1.50 DRILL P PROD1 Make up drilling BHA with 2.77 degree Anadril motor. 03:30 - 04:00 0.50 DRILL P PROD1 RIH with BHA stop at 1500', attempt to activate MWD. No luck. RIH to 5,000' and attempt again with greater hydrostatic head on the MWD. 04:00 - 05:00 1.00 DRILL P PROD1 Stop BHA at 5,000' MD and again test MVVD. Got good signal. Tested TORC. Also good test. 05:00 - 06:30 1.50 DRILL ~ PROD1 Continue to RIH. Tie in with BHC Acoustilog Gamma Ray log (run 02/15/1995) at 12,510'- 12,518'. 06:30 - 07:45 1.25 DRILL ~ PROD1 Log tie-in -4' correction. WINDOW: top 12677' bottom 12683' Bit>survey = 20.23' Bit>gr = 29.09' I . . 07:45 - 09:00 1.25 DRILL = PROD1 Orienting TORC tool. First commands not responding. Changed modulation from 90 to 93 and tool started to respond. Orient to 77L. Bleed off IA f/1400 psi to 1190 psi. Will not go any lower with pumps on. Loss of .4 bpm returns while bleeding off. 09:00 - 16:30 7.50' DRILL P PROD1 Drilling build section 77-90L 2850 free-spin 3000 on bottom light web frequent stalling in shales 15-20'/hr. Drilled f/12689' to 12788'. !16:30 - 17:00 0.50 DRILL P PROD1 Wiper trip to window. 17:00 - 23:35 6.58 DRILLP PROD1 Drill build section 2850 free-spin 3100 on bottom 2.6 in / 2.6out 40-60'/hr f/12788' to 12980'. 23:35 - 00:00 0.42 DRILL P PROD1 Wiper trip to window. No problems. Printed: 11/1/2001 9:39:53 AM STATE OF ALASKA ALASK/-, OIL AND GAS CONSERVATION COM~,,,$SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface "'/ -,/' ,.~ 2476' NSL, 1944' EWL, SEC. 31, T11N, R13E, UM At top of productive interval 3559' NSL, 981' WEL, SEC. 35, T11N, R12E, UM At effective depth 3586' NSL, 1029' WEL, SEC. 35, T11N, R12E, UM At total depth 3603' NSL, 1062' WEL, SEC. 35, T11N, R12E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE - 88.04' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number P-07 9. Permit Nu~Cer 194-164 10. APl Number v''/ 50- 029-22535-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner ,/ 13102 feet' Plugs (measured) .,,/ 9214 feet 12979 feet Junk (measured) 9097 feet Length Size Cemented 80' 20" 260 sx Arcticset (Approx.) 3608' 10-3/4" 1046 sx Coldset III, 375 sx Class 'G' 13063' 7-5/8" 265 sx Class 'G' MD TVD 110' 110' 3638' 3249' 13094' 9206' Perforation depth: measured 12803' - 12843' true vertical 8929' - 8967' .- I ' : Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 12618' Packers and SSSV (type and measured depth) 4-1/2" Baker 'SABL-3' packer at 12570'; 4-1/2" HFS SSSV Nipple at 2192' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 4. Estimated date for commencing operation September 28, 2001 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Name of approver Date Approved Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge SignedThomas McCady~~'_~"'/~- ...¢' /d~-~~'tle CT Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness '~.~ O ~ ~',, Plug integrity_ BOP Test ~ Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commission flrioioal Si,q .!~ ~ t GtI~r~/\L.,I commissioner Form 10-403 Rev. 06/15/88 6;m111¥ 0e~lYsli \ Date /('~//~/~/// Submit' In~ripf~c~at~ September 20, 2001 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 bp BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team Attention: Tom Maunder Petroleum Engineer Subject: Well P-07 CTD Sidetrack Prep Well P-07 is scheduled for a through tubing ~ to be drilled with coiled tubing. The following summarizes the procedure required to prep P-07 for drilling and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. ]. Tree wing & master valves to be integrity tested. 2. Using slickline, tbg will be drifted with dummy whipstock assy. 3. Using slickline, gas lift mandrels will be dummied. IA will then be liquid packed & integrity tested 4. Service coil will pump approx. 15bbls of 17ppg cement to P&A the existing perforations. Service coil prep work is expected to commence September 28, 2001. Coil tubing drilling operations, as detailed below will commence October 18, 2001. ]. A 33,4'' sidetrack, -1768' long, will be drilled out of casing in the Sag targeting Zone 4. 2,. The sidetrack will be completed with a 27/8" x 3-3/16" x 3-1/2", solid/uncemented & slotted liner. Thomas McCarty CT Drilling Engineer Tel: 564-5697 Fax: 564-551 0 Cell: 240-8065 mccarttm@bp.com Well File Petrotechnical Data Center Terrie Hubble TREE = 4-1/16" 5M CIW WELLFEAD= 5M FM( ACTUATOR= BAKER KB. ELEV = 88.04' B-F. ELEV = 59.86' KOP = 700' Max An le = ~ ~..611__0' Datum MD = 12759' Datum TVDss= 8800' 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" H 3638' P-07 I SA FEI-Y NOTES 2192' Id4-1/2" HES SSSV NP, ID= 3.813" GAS LIFT MANDRELS JMini,,mum ID =,3.725" @ 12606'I 4-1/2 HES 'XN NIPPLE 12559' 125 70' H4-1/2" HBS 'X' NP, ID= 3.813" I --~7-5/8"x 4-11Z' BKRSABL-3 PKR, ID =3.93" I w/~-22 ANCHOR LATCH 12595' 12606' 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12618' PERFORATION SUtvA4ARY RI~' LOG: BHCS 2/15/95 ANGLEATTOPPERF: 118@ 12803' Note: F~fer to Production DB for historical perf data 3-3/81 6 I 12803-12843 3/29/1995 J PBTD H I 7-5/8" CSG, 29.7#, L-80, ID= 6.875" H 12979' 13093' H4-1/2" HES 'X' NP, ID= 3.813" I DATE REV BY COMkrrJ'4TS 02/18/95 MBO ORIGINAL COIVI~ErlON 03104/01 SIS-SLT CONVERTB) TO CANVAS 03/08/01 SlS-LG FINAL 0~/'13/01 RN/tlh COF~ECTIONS I--[4-1/2" HES 'XN' KIP, ID= 3.725" J 12618' H4-1/2"WLEG, ID= 3.958" 12614' H ELMD 03/"29/95 PRUDHOE BAY UNIT WELL: P-07 PERMIT No: 94-1640 APl No: 50-029-22535-00 Sec. 31, T11N, R12E BP Exploration (Alaska) TREE= 4-1/16" 5M CNV WELLHEAD=- 5M FM( ACTUATOR= BAKER KB. ELEV = 88.04' KOP = Datum MD = 12759' Datum TVDss= 8800' 110-3/4" CSG, 45.5#, NT-80, ID: 9.953" Iff 3638' P-07A J s, ,' NOTES PROPOSED CTD SIDETRACK ./ 2192' Id4-1/2- HES SSSV ID = 3.813" LIFT MANDRELS Minimum ID = 3.725" @ 12606' 4-1/2" HES 'XN' NIPPLE ITop of Cement Id 12575' 12618' (Perf's to be P&A'd prior to PERFORATION SUMMA RY REFLOG: BHCS 2/15/95 ANGLE AT TOP PERF: Note: Refer to Production DB for :al perf data 3-3/8"I 6 I 12803-12843 3/29/1995 IP&A'd w/Cement [ 7-5~8" CSG, 29.7#, L-80, ID= 6.875"I/j-~ 13093' 12559' 12570' 12580' 12595' 12606' 12618' 12614' 12652' Jd4-1/2" HES 'X' NIP, ID= 3.813" I Id 7-5/8" x 4-1/2" BKR SABL-3 PKR, ID = 3.93" / w/K-22 ANCHOR LATCH ]dTop of Proposed 3-3/16" Liner Id4-1/2" HES 'X' NIP, ID= 3.813" J Id4-1/2" HES 'XN' NIP, ID= 3.725" Id4-1/2" WLEG, ID= 3.958"I Iff ELMD 03/29/95 ] 12682' 3-1/2" x 3-3/16" XO J Cement Ramp KOP (TOW) J 12740' J----[ 3-3/16"x 2-7/8" XO ] O O O O O O O O O O O O J I 3-3/4" Open Hole J 12-7/8" L-80 Pre-Drilled Liner I--I ~o'1 12848' 1-~ Hard BTM Tagged 1/9/2001 DATE REV BY COMMENTS 02/18/95 MDO ORIGINAL COMPLETION 03/04/01 SIS-SLT CONVER ~ w_L) TO CANVAS 03/08/01 SIS-LG FINAL 05/13/01 RN/tlh CORRECTIONS 06/13/0.___~._~1 pc~r P-0.___7A Proposed Sidetrack PRUDHOE BAY UNrr WELL: P-07A Proposed ST RERMIT No: 94-1640 APl No: 50-029-22535-01 Sec. 31, T11N, R12E BP Exploration (Alaska) TREE = 4-1/16" 5M CIW WELLHEAD= 5M FMOi BF. ELE'V = 69.80' , KOP = 700' Max Angle = 57 ~_. 6110"_~1 Datum MD = ~ 2759" ~ Datum TVDss= 8800' 110-3/4" CSG, 4~.5#, NT-80, ID -- 9.953" I--J ! P-07A I sA.., PROPOSED CTD SIDETRACK .)TES 2192' l--J4-1/2" HES SSSV NIP, D -- 3.813" I 3638' GAS LIFT MANDRELS Minimum ID = 3.725" @ 12606' 4-1/2" HES 'XN' NIPPLE RECEIVED OCT 0 2 200t Alaska 0il & Gas Cons. Anchorage 4-1/2" TBG, 12.8#, L-80, .0152 bpf, ID = 3,958" td 12618' ITop of Cement Iq 12618'I (Perf's to be P&A'd prior to Sidetrack) PERFORATION SUMMARY REF LOG: BHCS 2/15/95 ANGLEATTOPPERF: [18@ 12803' Note: Refer to Production DB for historical perf data r~TsF~ I~ INTERVAL I o~n/Sqz I DATE 13-3/8'1 6 I 12803'12843 I O I 3/29/1995 [ P&/~'d w/Cement 12559' H4-1/2,, HES 'X' NiP, ID-- 3.813" 12570' j-J7-5/8,, x 4-1/2" BKR SABL-3 PKR, ID -- 3.93" I w/K-22 ANCHOR LATCH 12580' 12595' J--J4-1/2"HES'X'NIP, ID: 3.813" J 12605' J-J4-1/2" HES 'XN' NiP, ID = 3.725" j 12618' I--[4-1/2"WLEG. ID=3.958" J 12614' J--J ELMD 03/29/95 J 12652' J--~ 3-1/2"x3-3/16"XO 12682' J-'--~ Cement Ramp KOP (TOW) 12740' J-----~ 3-3/1e"x 2-7/8"x0 o o o o o o o o o o o J 3-3/4" Open J-i-~Je j 14450' I 2-7/8" L-80 Pre-Drilled Liner J4 .__1 12848' J-~ Hard BTMTagged 1/9/2001 J 7-§/8' CSG,;29.7#, L-80, ID =6,875" Jq 13093' DATE REV!BY COMMENTS " PRUDHOE BAY UNIT 02/18/95 MD~O ORIGINAL COMPLETION ..... WELL: P-07A Proposed ST 03/04/01 SIS-,SLT CONVERIP_L)TO CANVAS PERMIT No: 94-1640 03/08/01 SIS;LC FINAL APl No: 50-029-22535-01 0~i13/01 RNftlh CORRECTIONS Sec, 3'1, Ti 1N, R12E ,., 06/13/01 pcr P-07A Proposed Sidetrack BP ExpIorati°n ,, .~ ................ ON OR B¢FOR¢ ,3R/CCL FINAL ¢~.,h7~ 12L~20-12900 Oh./' J()/'95 9t~- .... 16/~ F'FC/PERF 5sv~ Ar"e dr"v d'¥tch samples ~t,:.is 'the v,/eii eot'ed? yes 'J () ,">/' i (.)//:t~ 5 r" 43 c; ¢ '1' "¢ ¢ ,(;J ']~¢ "/c; ::;1i o (~___~. Iq cq 'J y s ')' :s &. d e s o r' -¥ p i; "l' o n r" ,~ (:: ::: "1 v ::; d '.,: Ar'e weii 'i:es'ts r. equi'r'ed? ,lyes ~,^te i i '¥ s ~i n c o m p 'i '¥ a n c e .... z n 'i 't '¥ a 'i c C,H H E iq T '.5 STATE OF ALASKA A,..,-,SKA OIL AND GAS CONSERVATION COMMISsiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing_ Stimulate __ Plugging__ Perforate__ Alter casing __ Repair well.__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O, Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2476' NSL, 1944' EWL, SEC. 31, T11N, R13E At top of productive interval 3615' NSL, 956' WEL, SEC. 35, T11N, R12E At effective depth 1696' NSL, 1031' WEL, SEC. 35, T11N, R12E At total depth 3660' NSL; 1037' WEL, SEC. 35, T11N, R12E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB=88.04' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number P-07 (42-35-11-12) 9. Permit number/approval number 94-164 / 10. APl number 50- 029-22535 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13102' feet 9228' feet 12979' feet 9111' feet Length Size -. 110' 20" 3610' 10-3/4" 13066' 7-5/8" measured 12803'- 12843' Plugs (measured) Junk (measured) Cemented 260 sx Arcticset 106 sx CS 111/375 sx "G" 265 sx Class "G" Measured depth 138' 3638' 13O94' True vertical depth BKB 138' 3249' 9206' true vertical subsea 8943'-8981' Tubing (size, grade, and measured depth) 4-1/2", L-80 to 12618' Packers and SSSV (type and measured depth) Packer @ 12570 SSSV @ 2194' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 665 2144 0 0 1656 1136 150 2070 Tubing Pressure 361 330 15. Attachments J 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Opera/tieRs ,.*, I Oil __X__ Gas__ Suspended__ 17. I hereb~e~ that/the fo{ea~ing is true cr~ Correct to the best of my knowledge. · ,:.:,,.;.' ,, I/ · . . Signed ',_.f.Z/¢"~, .._ ,'/.~ ,//¢"~¢ ,_ _~_,./¢~,-~ ,~,,~/ ~,.~:'*?-,,.-¢.~J.,~.., T tie Techmca/Asszstant III Form 10-404 Rev 06/15/88 Service SUBMIT IN DUPLICATE WELL P-07 (42-35-11-12) FRAC 4/27/95 Performed a fluids: Ivishak/Data Fracture using the following FLUIDS PUMPED DOWNHOLE Establish rate with 40~ gel 66/0 81 Stage l ppg16 /20 CL 32/0 113 Stage2ppg 3225 45 lppg on perfs " 77 2 ppg on perfs " 82 3 ppg on perfs 90 4 ppg on perfs " 10 t 5 ppg on perfs 3315 116 6ppgonperfs 3383 134 7ppgonperfs 3444 153 8 ppg onperfs 3436 176 9ppg onperfs " 200 lOppg on perfs 6000+ 68.5 570.5 SO. Pumps tripped out. Monitor WHP. Si well. Bleed IAP to 500. Freeze protect and Flush lines/pumps with dsl. FLUIDS PUMPED DOWNHOLE -- INJ TEST: 417 Bbls 40~ Gel DATA FRAC: 20 Bbls 409 Gel Prepad To Establish Rate 140Bbls 40# X-Link Gel Pad 200Bbls 10# Gel Data Frac Flush FRAC: 15 Bbls 40~ Gel Prepad To Establish Rate 66Bbls 40# X-Link Gel Pad 3 2 Dirty 1 Ppg 23 8 Ppg 25 9 Ppg 265 -10 Ppg 68.5 20,9 Linear Gel Flush LOAD VOLUME: 1347.5 (TOTAL FLUIDS PUMPED DOWN HOLE) 100 bbls Diesel used to flush pumps STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,ELL COMPLETION OR RI=COMP L£TION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 94-164 3. Address B. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 5 o- 029-22535 4. Location of well at surface 9. Unit or Lease Name 2476' NSL, 1944' EWL, SEC. 31, T11N, R13E~' . ~ :..i~:~-. :~i-~:~ ~'¢ Prudhoe Bay Unit At Top Producing Interval At Total Depth } ~;i:¢;-; ;i''uu~ l l.PrudhoeField and Pool Pool 3660' NSL, 1037' WEL, SEC. 35, T11N, R12E' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 88.04' ADL 28264 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [15. Water Depth, if offshore [16. No. of Completions 1/8/95 2/14/95 3/29/95 N/A feet MSL J One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set J21. Thickness of Permafrost 13102'MD/9228'TVD 12979'MD/9111'TVD YES [] NO [] 2194'feet MD [ 1900'(Approx.) 22. 'Type Electric or Other Logs Run DIL/BHCS/GR/TEMP 23. CASING, LINER AND CEMENTING RECORD SE'Fl-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-r'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 110' 30" 260 sx Arcticset (Approx.) 10-3/4" 45.5# NT-80 30' 3638' 13-1/2" 1046 sx CS 111/375 sx "G" 7-5/8" 29. 7# NT95HS 31' 13094' 9-7/8" 265 sx Class "G" ~24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 4-1/2", L-80 12618' 12570' MD TVD 12803'- 12843' 8943'-8981' '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 3/29/95 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core ch_ips~_......~,.~ ECEIVbU APR - 5 1995 Alaska 0il & 6as Cons. Commission Anchora o Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 12667' 8725' Shublik 12756' 8747' Sadlerochit 12802' 8853' RECEIVED APR - 5 199,5 /~t~sk~ 0il & Gas Cons. Commission Anchora, 31. LIST OF A'FI-ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢~/ I ~ TitleDrillino_En¢itleorSu.ocrvi$(2r Date ¢/- ~''-?~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate .which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 26: If no cores taken, indicate "none". Form 10-407 .~AI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P-7 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 18E 01/07/95 ( 1) TD: 110 PB: 110 01/08/95 (2) TD: 780 PB: 780 01/09/95 (3) TD: 3025'(3025) 01/10/95 ( 4) TD: 3650' ( 625) MIRU MW: 0.0 BLOW DOWN RIG AND PREPARE FOR MOVE FROM J-PAD TO P-PAD. MOVE COMPLEXES AND SUBBASE OFF JX-02 AND TRANSPORT PIPE SHED AND PITS TO P-PAD. MOVE IN WHEELS ON SUB AND TRANSPORT SAME TO P-PAD ALONG W/ MOTORS AND BOILER COMPLEX. BROKE "I" ON FRONT GOOSE NECK ON SUB. WELD AND REPAIR SAME. REPOSITION WHEELS ON SUB AND READY SUB TO MOVE OVER HOLE. SPREAD HERCULITE. SPOT AND LEVEL SUB AND PIT COMPLEX. DRILLING MW: 0.0 REMOVE SUPPORT BRACE AND REAR JACKING UNIT FORM PIT. SPOT REMAINING COMPLEXES. CONNECT STEAM, WATER, ELECTRICAL, AND LAY OUT ANTI SKID WALKWAY OVER HERCULITE. RU FLOOR. NU 20" DIVERTER AND FLOWLINE. ACCEPT RIG @ 1300 HRS ON 01/07/95. TAKE ON WATER, MIX SPUD MUD. THAW OUT MUD MOTOR AND STRAP BHA. FUNCTION TEST DIVERTER. PU BIT AND MOTOR. CODUCTOR FULL OF ICE. DRLG ICE OUT OF CONDUCTOR F/ 30 - 110'. BLOW DOWN AND SET BACK KELLY. PU MWD. RESET ADJUSTABLE MOTOR AND ORIENT TOOLS. DRLG 13 1/2" SURFACE HOLE F/ 110 - 780' DRILLING MW: 0.0 VIS: 0 DRLG 13 1/2" SURFACE HOLE F/ 780 - 1205'. SHORT TRIP TO DC'S. NO PROBLEM. WASH 30' TO BTM AND SURVEY. DRLG 13 1/2" SURFACE HOLE F/ 1205 - 2123'. MADE 10 STD SHORT TRIP. NO PROBLEMS. WASHED 40' TO BTM. NO FILL. DRLG 13 1/2" SURFACE HOLE F/ 2123 - 3025'. RUN 10 3/4" CSG MW: 0.0 VIS: 0 DRLG F/ 3025 - 3140' MADE 11 STD SHORT TRIP TO 2100' HOLE IN GOOD SHAPE. DRLG 13 1/2" HOLE F/ 3140 - 3650' CIRC BOTTMS UP. SHORT TRIP TO HWDP. SLM. NO CORRECTION. HOLE IN GOOD SHAPE. CIRC BTTMS UP TWO TIMES. CONDITION MUD AND HOLE. POH TO RUN 10 3/4" SURFACE CSG. LD BHA. RU CASERS. RUN IN HOLE W/ 76 JTS 10 3/4" 45.5# LT80 BUTT CSG. APR - 5 '~995 0ii & Gas Cons. Commission Anchora ~ ,, · P-7 _~ERATION: RIG : NABORS 18E PAGE: 2 01/11/95 ( 5) TD: 3650' ( 0) 01/12/95 (6) TD: 3650' ( 0) POH LD DP MW: 0.0 VIS: 0 FINISH RIH W/ TOTAL 90 JTS 10 3/4" 45.5# NT80 BUTT CSG. PU HANGER AND LANDING JT AND RUN CSG TO BOTTOM @ 3637'. CIRC AND CONDITION MUD AND HOLE FOR CMT JOB. RECIPROCATE PIPE AND THIN MUD. TEST LINES. BJ CMT'D 10 3/4" CSG W/ SHOE @ 3637' AND FC @ 3554' PUMPED 75 BBLS WATER, 1046 SX COLD SET 3. DISPLACED WITH RIG PUMPS. BUMPED PLUG, FULL RETURNS, RECIPROCATED, NO CMT TO SURFACE, FLOATS HELD. RAN 1" TO 80' AND RU TO DO TOP JOB. BJ PUMPED 25 BBLS WATER AND 103 SX COLD SET 2. CIRC GOOD 14.5 PPG CMT TO SURFACE. RD CMT AND CSG TOOLS. ND DIVERTER. INSTALL 13 5/8" 5M SSH. TEST TO 1000 PSI AND INSTALL TEST PLUG. NU 13 5/8" 5M BOPS. TEST BOPS. FULL BODY TEST ON BOPS AND CHOKE MANIFOLD. PULLED TEST PLUG AND SET WEAR BUSHING. PU 9 7/8" BIT, 2 - 6 1/4" DC'S, JARS, XO, 15 HWDP. CUT DRLG LINE. RIH, TAGGED FC @ 3552'. RU TO TEVERSE CIRC. CIRC BOTTOMS UP. DISPLACE HOLE W/ FRESH WATER. TEST CSG. BREAK KELLY. POH LD DP. RELEASE RIG MW: 0.0 VIS: 0 RELEASED RIG TO STANDBY OPERATIONS ON 01/11/95 0600 HRS. 02/05/95 (7) TD: 3650'( 0) 02/06/95 ( 8) TD: 3650'( 0) 02/07/95 (9) TD: 5184' (1534) MOVING RIG MW: 0.0 VIS: 0 MOVED RIG OFF DS A-42. L/D DERRICK. MOVING RIG ON ROAD TO P-07. RIG ALMOST TO P PAD. MADE UP BHA #1 MW: 0.0 VIS: 0 FINISHED MOVING RIG TO P-07. SPOT RIG OVER HOLE. RAISE DERRICK. SLIDE FLOOR. SPOT MUD PITS. R/U FLOOR. RIG ACCEPTED @ 1530 HRS ON 02/06/95. TAKE ON MUD SAVED FROM DS 1-42. REMOVED XMAS TREE. NU BOP STACK. RIGGED UP BOP STACK. BOP STACK IN POSITION. REMOVED HANGER PLUG. RETRIEVED LANDING STRING. PULLED TBG HANGER AND 1 JT 4 1/2" TBG. MAKE UP KELLY, SAVER SUB, KELLY COCK. TESTED PIPE RAMS, BLIND RAMS, CHOKE AND KILL LINE VALVES, FLOOR SAFETY VALVES AND CHOKE MANIFOLD. TESTED ANNULAR. MADE UP BHA #1. DRILLING MW: 0.0 VIS: 0 MADE UP BHA #1. P/U AND ORIENT BHA. RIH TO 2200' P/U SINGLES AND RIH. CIRCULATED. CIRC 211 BBLS DIESEL FREEZE PROTECT OUT OF WELL. SALVAGED 145 BBLS FREEZE PROTECT. OBTAINED CLEAN RETURNS. RIH TO 3561' P/U 5" DP. TAGGED FLOAT EQ @ 3561'. TESTED CASING. DRILLED FLOAT EQUIPMENT, CMT, AND 15' NEW HOLE. CIRCULATED @ 3665' OBTAINED BOTTOMS UP. PERFORMED FORMATION INTEGRITY TEST. OBTAINED LEAK OFF. DRILLED TO 4709' CIRCULATED. OBTAINED BOTTOMS UP. POH TO 3638' RIH TO 4709'. DRILLED TO 5184' APR -'5 ]995 (iii & Gas Cons. Commission Anchora" : P-7 JERATION: RIG : NABORS 18E PAGE: 3 02/08/95 (10) TD: 6742' (1558) 02/09/95 (11) TD: 6742' ( 0) 02/10/95 (12) TD: 9510' (2768) 02/11/95 (13) TD:10645' (1135) 02/12/95 (14) TD:11625' ( 980) 02/13/95 (15) TD:12520' ( 895) 02/14/95 (16) TD: 12715' ( 195) 02/15/95 (17) TD:13102' ( 387) RIH TO 1890' MW: 0.0 VIS: 0 DRILLED TO 5860'. CIRCULATED. OBTAINED BOTTOMS UP. POH TO 4318'_ RIH TO 5860'. NO HOLE PROBLEMS. DRILLED TO 6043'. CIRCUALTE. GUZZLER BROKE DOWN. WAIT ON GUZZLERS TO EMPTY CUTTINGS TANK. DRILLED TO 6742'. BIT QUIT. CIRCULATED @ 3092'. HOLE SWEPT WITH SLUG. POH. 7 3/4" F2000S 1.0 DEG BH MOTOR, DS59H BIT. CHANGE OUT BIT AND MWD PROBE. INSTALLED WEAR BUSHING. SERVICED WEAR BUSHING. RIH TO 1890' DRILLING MW: 0.0 VIS: 0 RIH TO 1890'. BEGAN PRECAUTIONARY MEASURES. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 6667' NO HOLE PROBLEMS. REAMED TO 6742' DRILLED TO 7942'. CIRCULATED. OBTAINED CLEAN RETURNS. POH TO 6699'. GOOD HOLE, NO PROBLEMS RIH TO 7942' BENCHMARK SURVEY @ 6806' OK. NO · , FILL. DRILLED TO 8350' DRILLING MW: 0.0 VIS: 0 DRILLED TO 9261' STARTED SCHEDULED WIPER TRIP. o CIRCULATED @ 9261' OBTAINED CLEAN RETURNS. POH TO 7837' NO HOLE PROBLEMS. RIH TO 9261'. NO FILL AND BENCHMARK SURVEY @ 7868'. OK. DRILLED TO 9510' DRILLING MW: 0.0 VIS: 0 DRILLED TO 10390'. POH TO 8445' PULL 20 STDS. NO PROBLEMS. RIH TO 10390' NO FILL, BENCHMARK MWD @ 8694' DRILLED TO 10645' DRILLING MW: 0.0 VIS: 0 DRILLED TO 11439'. CIRCULATED. OBTAINED BOTTOMS UP. POH TO 10005' RIH TO 11439' NO FILL, BENCHMARK MWD, OK. DRILLED TO 11625'. DRILLING MW: 0.0 VIS: 0 DRILLED TO 12488'. CIRCULATED. OBTAINED BOTTOMS UP. POH TO 10571'. RIH TO 12488'. NO FILL, MWD BENCHMARK @ 10771', OK. DRILLED TO 12520'. DRILLING MW: 0.0 VIS: 0 DRILLING TO 12523'. CBU. POH. CHANGE MOTOR. TEST BOPE AND SWR. RIH TO SHOE @ 3637'. SLIP AND CUT DRLG LINE. RIH TO 12453'. WASH AND REAM F/ 12453 - 12523' CBU. DRILLING F/ 12523 - 12715' WIRELINE WORK MW: 0.0 VIS: 0 DRILLED TO 13021' DRILLFLOOR/DERRICK FAILED, CIRCULATE. REPAIRED ROTARY TABLE. ELECTRIC MOTOR ON RT. DRILLED TO 13102'. CIRCULATE. CBU AND CONDITION THE MUD· POH TO 11700' RIH TO 13102' SPOT LCM PILL ON BOTTOM. POH TO 825'. PULLED BHA. WIRELINE WORK. AF'~. -' 5 1995 Gas Cons. Oommis~m~ Anchor~ ' : P-7 FERATION: RIG : NABORS 18E PAGE: 4 02/16/95 (18) TD:13102' ( 0) 02/17/95 (19) TD:13102' ( 0) 02/18/95 (20) TD:13102' ( 0) PULLED BHA MW: 0.0 VIS: 0 CONDUCT BRAIDED CABLE OPERATIONS - 7/32 SIZE CABLE. RUN DIL/BHC/GR/TEMP. COMPLETED RUN WITH GR FROM 13102-11500' MADE UP BHA #4. BHA #4 MADE UP. RIH TO 13102' BEGAN PRECAUTIONARY MEASURES. REAMED TO 13102'. ON BOTTOM. CIRC AT 13102'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). SPOT 15 BBLS LCM PILL. LAID DOWN DP TO 813.87'. PULLED BHA. AT BHA. RU SLICK LINE UNIT MW: 0.0 VIS: 0 CHANGE RAMS, PULL WR, TEST BOP DOORS. RU CSG EQUIP. PRE JOB SAFETY MEETING. RUN 7-5/8" CSG. MU LJ, LAND 7-5/8" CSG. CIRC & COND MUD. BATCH MIX 75 BBL CMT, PUMP 5 BBLS 6XO TEST CMT LINES TO 3500 PSI, PUMP 15 BBLS HWO @ 3.5 BPM - 400 PSI, 70 BBLS MCS -4 10.8 PPG @ 3.5-4 BPM 700-750 PSI, DROP BTM PLUG, PUMP 75 BBLS CMT. "G" 15.7 PPG DROP TOP PLUG, 5 BBLS FRESH H20 & DISPLACED CMT W/593.5 BBLS H20. DID NO BUMP PLUG. @ 10 BPM 1100 PSI. RD CSG EQUPI & CLEAR FLOOR. RUN 7-5/8" PACKOFF & TEST TO 5000 PSI FOR 15 MIN. CHANGE RAMS TO 3-1/2" - TEST DOORS IWR. RU SLICK LINE UNIT & RIH W/#1 RUN. (5" IMPRESSION BLOCK). INSTALLED HANGER PLUG MW: 0.0 VIS: 0 CONDUCTED SLICKLINE OPERATIONS. RIH W/5' IMPRESSION BLOCK WL TD @12979'_ PERFORM INTEGRITY TEST. TESTED CSG. TEST 7-5/8" CSG TO 3500 PSI. FUNCTION TEST COMPLETED SATISFACTORILY. RUN 298 JTS 12.6# L-80 NSCT TBG. RAN TBG TO 12617'. TEST CONTROL LINES TO 5000 PSI. OK. HANGER LANDED. RIGGED DOWN TBG HANDLING EQUIP. CLEAR FLOOR, L/D LJ & RILDS. EQUIP WORK COMPLETED. RIGGED DOWN BOP STACK. EQUIP WORK COMPLETED. TEST XMAS TREE TO 5000 PSI. INSTALLED XMAS TREE. RETRIEVED XMAS TREE PRIMARY COMPONENTS. INSTALL LUBRICATOR & REMOVED TWC. EQUIP WORK COMPLETED. SETTING PACKER AT 12570' SET PACKER W/4000 PSI, TEST F/30 MIN. TEST BACK SIDE TO 3500 PSI F/30 MIN. SHEAR RPV. PACKER SET AT 12570' RU & FREEZE PROTECT WELL W/96 BBLS 50/50 - U TUBE & FREEZE PROTECT 10-3/4" ANN. W/100 BBLS. FREEZE PROTECT WELL - 100 BBL OF OIL. 50/50 MIX. INSTALLED HANGER PLUG. INSTALL BPV. EQUIP WORK COMPLETED. SIGNATURE: (drilling superintendent) DATE: BP EXPLORATION (Ataska) Inc. Pad P 7 slot #7 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <0-3650'> Our ref : svy4535 License : Date printed : 8-Mar-95 Date created : 16-Jan-95 Last revised : 8-Mar-95 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on nTO 15 25.530,w148 57 17.061,3 Slot location is nTO 15 49.889,w148 56 20.484 Slot Grid coordinates are N 5947202.994, E 631227.985 Slot local coordinates are 2477.02 N 1944.11E Reference North is True North RECEIVED BP EXPLORATION (Ataska) Inc. SURVEY LISTING Page 1 Pad P,7 Your ref : PMSS <0-3650'> Prudhoe Bay,North Slope, Alaska Last revised : 8-Mar-95 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.30 280.20 100.00 0.05 N 0.26 W 0.30 0.25 196.00 0.10 6.70 196.00 0.17 N 0.50 W 0.32 0.52 288.00 0.40 344.20 288.00 0.56 N 0.57 ~ 0.34 0.78 380.00 0.30 4.90 380.00 1.11 N 0.64 g 0.17 1.11 472.00 0.30 34.10 472.00 1.55 N 0.48 W 0.16 1.20 564.00 0.60 15.80 563.99 2.21 N 0.22 ~ 0.36 1.30 656.00 0.80 0.00 655.98 3.32 N 0.09 ~ 0.30 1.74 749.00 1.90 304.00 748.96 4.83 N 1.36 W 1.72 3.60 840.00 3.60 288.60 839.85 6.59 N 5.32 ~ 2.02 7.90 932.00 4.70 287.60 931.61 8.65 N 11.65 ~ 1.20 14.42 1026.00 6.00 279.10 1025.20 10.59 N 20.18 ~ 1.62 22.T7 1120.00 6.60 269.30 1118.64 11.30 N 30.43 W 1.31 32.00 1211.00 8.60 270.40 1208.83 11.28 N 42.46 ~ 2.20 42.42 1303.00 10.40 268.60 1299.57 11.13 N 57.64 ~ 1.98 55.49 1393.00 12.30 271.80 1387.80 11.23 N 75.35 W 2.22 70.87 1485.00 14.50 272.10 1477.29 11.96 N 96.66 ~ 2.39 89.69 157'/.00 16.80 271.10 1565.88 12.64 N 121.46 ~ 2.52 111.51 1668.00 17.60 269.60 1652.81 12.80 N 148.37 ~ 1.00 134.89 1761.00 20.70 268.90 1740.65 12.38 N 178.87 ~ 3.34 161.10 1852.00 23.40 269.60 1824.99 11.95 N 213.03 W 2.98 190.46 1946.00 22.70 268.90 1911.48 11.47 N 249.83 ~ 0.80 222.09 2038.00 21.40 268.20 1996.75 10.60 N 284.35 ~ 1.44 251.56 2132.00 23.40 269.30 2083.65 9.83 N 320.16 ~ 2.17 282.18 2224.00 26.00 272.10 2167.23 10.35 N 358.59 ~ 3.10 315.72 2316.00 27.20 273.90 2249.49 12.52 N 399.72 ~ 1.57 352.43 2409.00 27.90 276.00 2331.95 16.24 N 442.57 W 1.29 391.39 2501.00 30.00 276.30 2412.45 21.01 N 486.84 ~ 2.29 432.12 2594.00 32.40 276.00 2491.99 26.17 N 534.74 ~ 2.59 476.18 2686.00 34.40 277.40 2568.80 32.09 N 585.03 ~ 2.33 522.70 2779.00 36.10 276.00 2644.74 38.34 N 638.33 ~ 2.02 571.98 2871.00 37.80 276.00 2718.26 44.12 N 693.33 ~ 1.85 622.50 2963.00 39.40 275.60 2790.16 49.92 N 750.43 W 1.76 674.85 3055.00 41.10 277.00 2860.38 56.45 N 809.51 ~ 2.09 729.28 3146.00 43.10 276.30 2927.89 63.51 N 870.10 ~ 2.26 785.29 3238.00 45.00 276.00 2994.01 70.36 N 933.70 ~ 2.08 843.79 3330.00 47.10 274.90 3057.86 76.64 N 999.63 W 2.44 904.02 3423.00 49.40 276.00 3119.79 83.24 N 1068.69 ~ 2.62 967.13 3515.00 52.20 276.30 3177.93 90.88 N 1139.57 ~ 3.05 1032.34 3565.00 53.60 276.00 3208.09 95.15 N 1179.22 W 2.84 1068.81 3650.00 53.60 276.00 3258.53 102.30 N 1247.26 ~ 0.00 1131.31 Projected Data - NO SURVEY At[ data fs in feet untess otherwise stated Coordinates from slot #7 and TVD from RKB (84.44 Ft above mean sea [ever). Vertical section is from wellhead on azin~Jth 300.00 degrees. Declination is 0.00 degrees, Convergence is 0.98 degrees. Catcu[ation uses the minimum curvature method. Presented by Baker Hughes [NTEQ BP EXPLORATION (Alaska) Inc. SURVEY LISTING Page 2 Pad P,7 Your ref : PNSS <0-3650~> Prudhoe Bay, North Slope, Alaska Last revised : 8-Mar-95 Co~ents in we[[path MD TVD Rectangular Coords. Comment 3650.00 3258.53 102.30 N 1247.26 W Projected Data - NO SURVEY Ali data is in feet un[ess otherwise stated Coordinates from slot #7 and TVD from RKB (84.44 Ft above mean sea [eve[). Bottom hole distance is 1251.45 on azimuth 274.69 degrees from we[[head. Vertfca[ sectfon fs from we[[head on azimuth 300.00 degrees. Declination is 0.00 degrees, Convergence fs 0.98 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ S~,,~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING PBU/P- 7 500292253500 NORTH SLOPE COMPUTATION DATE: 2/17/95 DATE OF SURVEY: 021495 MWD SURVEY JOB NUMBER: AK-MW-50011 KELLY BUSHING ELEV. = 88.04 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3570 3213.95 3125.91 3684 3281.42 3193.38 3780 3338.84 3250.80 3875 3395.90 3307.86 3971 3453.41 3365.37 53 35 N 84.00 W .00 95.16N 1179.23W 53 24 N 83.90 W .19 104.77N 1269.90W 53 0 N 85.20 W 1.16 112.06N 1346.31W 53 5 N 83.20 W 1.69 119.73N 1421.77W 53 17 N 83.50 W .33 128.63N 1498.13W 1068.82 1152.15 1221.97 1291.15 1361.73 4065 3509.46 3421.42 4160 3566.59 3478.55 4256 3623.46 3535.42 4350 3677.86 3589.82 4445 3732.74 3644.70 53 30 N 83.70 W .27 137.04N 1573.13W 53 0 N 82.80 W .92 146.03N 1649.09W 54 24 N 82.30 W 1.52 156.07N 1725.86W 54 47 N 81.10 W 1.13 167.12N 1801.60W 54 35 N 81.80 W .64 178.65N 1878.25W 1430.89 1501.17 1572.67 1643.79 1715.94 4540 3788.07 3700.03 4637 3844.73 3756.69 4731 3900.12 3812.08 4826 3956.15 3868.11 4920 4011.15 3923.11 54 12 N 81.80 W .42 189.67N 1954.74W 54 0 N 81.20 W .54 201.24N 2032.15W 54 0 N 80.40 W .69 213.43N 2107.41W 53 54 N 80.90 W .44 225.94N 2183.36W 54 17 N 79.80 W 1.04 238.67N 2258.26W 1787.69 1860.51 1931.79 2003.82 2075.05 5016 4067.04 3979.00 5113 4122.76 4034.72 5208 4176.73 4088.69 5303 4230.72 4142.68 5398 4284.41 4196.37 5493 4338.00 4249-.96 5588 4391.95 4303.91 5682 4444.85 4356.81 5777 4498.74 4410.70 5872 4552.05 4464.01 5968 4605.24 4517.20 6061 4656.10 4568.06 6158 4710.25 4622.21 6253 4764.35 4676.31 6348 4818.63 4730.59 6443 4872.80 4784.76 6540 4928.16 4840.12 6628 4978.38 4890.34 6733 5038.40 4950.35 6826 5092.29 5004.25 54 35 N 79.00 W .75 253.06N 2335.14W 55 12 N 80.70 W 1.56 267.03N 2413.17W 55 17 N 80.50 W .20 279.73N 2489.93W 55 47 N 81.60 W 1.09 291.97N 2567.67W 55 30 N 81.20 W .47 303.72N 2645.35W 55 42 N 82.10 W .81 315.08N 2722.77W 55 12 N 82.60 W .68 325.52N 2800.43W 55 54 N 83.00 W .83 335.18N 2876.93W 55 30 N 82.50 W .60 345.15N 2955.31W 55 54 N 84.00 W 1.38 354.33N 3032.90W 56 47 N 84.90 W 1.22 362.06N 3112.43W 57 0 N 84.20 W .67 369.47N 3190.10W 55 24 N 84.00 W 1.65 377.78N 3270.56W 55 0 N 85.30 W 1.20 385.04N 3348.06W 55 17 N 84.00 W 1.17 392.31N 3425.67W 55 12 N 83.20 W .70 401.01N 3503.26W 55 0 N 83.20 W .21 410.41N 3582.05W 55 17 N 82.50 W .74 419.38N 3653.61W 55 0 N 85.00 W 1.97 428.77N 3739.27W 54 35 N 85.80 W .82 434.90N 3815.43W 2148.82 2223.38 2296.21 2369.65 2442.80 2515.53 2588.00 2659.09 2731.95 2803.73 2876.47 2947.44 3021.27 3092.02 3162.87 3234.42 3307.35 3373.82 3452.69 3521.71 RECEIVED Anchor~ S~,,.RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING, PBU/P-7 500292253500 NORTH SLOPE COMPUTATION DATE: 2/17/95 DATE OF SURVEY: 021495 MWD SURVEY JOB NUMBER: AK-MW-50011 KELLY BUSHING ELEV. = 88.04 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORD NORTH/SOUTH EAST INATE S /WEST VERT. SECT. 6922 5147.28 5059.24 7016 5200.75 5112.71 7111 5254.53 5166.49 7204 5307.20 5219.16 7296 5359.25 5271.21 55 0 N 85.30 W .60 55 24 N 85.40 W .44 55 42 N 85.30 W .33 56 0 N 84.90 W .48 54 47 N 85.10 W 1.32 440.95N 3893.14W 447.18N 3969.82W 453.54N 4047.97W 460.17N 4125.32W 466.75N 4200.50W 3592.03 3661.56 3732.41 3802.72 3871.11 7392 5414.66 5326.62 7487 5469.61 5381.57 7584 5525.21 5437.17 7680 5581.19 5493.15 7774 5637.54 5549,50 54 30 N 85.30 W .36 54 47 N 85.10 W .36 55 5 N 84.80 W .40 53 35 N 84.60 W 1.57 53 5 N 84.60 W .53 473,29N 4278.34W 479.77N 4355.52W 486.74N 4434.47W 493.95N 4512.19W 501.08N 4587.59W 3941.79 4011.88 4083.74 4154.65 4223.51 7868 5693.70 5605.66 7965 5751.38 5663.34 8058 5806.74 5718.70 8154 5863.38 5775.34 8246 5917.74 5829.70 53 17 N 84.40 W .27 53 30 N 83.90 W .46 53 42 N 84.20 W .34 53 54 N 84.40 W .27 53 54 N 84.40 W .02 508.28N 4662.31W 516.19N 4739.57W 523.97N 4814.25W 531.66N 4891.26W 538.94N 4965.45W 4291.82 4362.68 4431.25 4501.78 4569.68 8340 5973.57 5885.53 8436 6030.60 5942.56 8529 6086.20 5998.16 8622 6142.17 6054.13 8716 6198.05 6110.01 53 35 N 84.20 W .36 53 17 N 84.20 W .31 53 12 N 83.90 W .28 53 0 N 84.00 W .23 53 54 N 82.50 W 1.60 546.50N 5041.21W 554.27N 5117.76W 561.99N 5191.81W 569.85N 5265.94W 578.71N 5340.80W 4639.07 4709.24 4777.24 4845.36 4914.62 8811 6253.87 6165.83 8905 6309.00 6220.96 8998 6363.94 6275.90 9092 6418.53 6330.49 9186 6472.52 6384.48 54 0 N 82.10 W .36 53 42 N 81.90 W .36 54 30 N 81.80 W .86 54 42 N 81.40 W .41 54 42 N 81.60 W .17 588.99N 5416.79W 599.49N 5491.52W 610.25N 5566.65W 621.47N 5642.63W 632.74N 5718.05W 4985.57 5055.54 5125.99 5197.40 5268.35 9281 6527.46 6439.42 9376 6582.59 6494.55 9468 6635.5'2 6547.48 9560 6688.57 6600.53 9653 6742.51 6654.47 54 47 N 81.10 W .44 54 30 N 81.40 W .41 54 47 N 81.10 W .42 54 47 N 80.70 W .36 54 47 N 80.50 W .18 644.43N 5794.91W 656.26N 5871.72W 667.61N 5945.48W 679.50N 6019.73W 691.99N 6095.17W 5340.75 5413.19 5482.74 5552.99 5624.56 9750 6797.93 6709.89 9841 6850.60 6762.56 9935 6904.99 6816.95 10029 6958.76 6870.72 10125 7013.75 6925.71 54 47 N 80.50 W .02 54 47 N 80.50 W .02 54 54 N 80.40 W .14 55 0 N 80.00 W .37 55 12 N 80.20 W .27 704.96N 717.28N 730. i0N 743 . 14N 756.70N 6172.65W 6246.29W 6322.47W 6397.99W 6475.65W 5698.15 5768.08 5840.47 5912.39 5986.43 S~_ARY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/P-7 500292253500 NORTH SLOPE COMPUTATION DATE: 2/17/9 DATE OF SURVEY: 021495 MWD SURVEY JOB NUMBER: AK-MW-50011 KELLY BUSHING ELEV. = 88.04 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10221 7068.37 6980.33 55 17 N 80.20 W .10 770.10N 6553.24W 10317 7122.92 7034.88 55 17 N 79.50 W .60 783.98N 6630.78W 10412 7176.86 7088.82 55 17 N 79.60 W .09 798.11N 6707.39W 10508 7231.71 7143.67 55 5 N 80.20 W .55 811.95N 6785.08W 10604 7286.52 7198.48 55 12 N 80.70 W .44 825.01N 6862.70W 6060.32 6134.42 6207.83 6282.03 6355.78 10699 7341.23 7253.19 55 5 N 80.70 W .10 837.71N 6940.25W 10795 7396.11 7308.07 54 54 N 80.50 W .27 850.50N 7017.56W 10890 7450.84 7362.80 54 47 N 79.50 W .87 864.00N 7094.11W 10985 7505.55 7417.51 54 42 N 79.10 W .36 878.37N 7170.18W 11081 7561.58 7473.54 53 47 N 79.30 W .95 892.96N 7246.62W 6429.28 6502.64 6575.68 6648.74 6722.24 11177 7619.74 7531.70 51 42 N 79.80 W 2.22 906.83N 7321.84W 11272 7679.02 7590.98 50 42 N 80.00 W 1.07 919.77N 7394.42W 11366 7740.24 7652.20 49 0 N 80.50 W 1.83 932.06N 7465.95W 11462 7803.95 7715.91 47 17 N 80.00 W 1.82 944.10N 7536.05W 11558 7871.19 7783.15 43 35 N 80.50 W 3.88 955.68N 7603.37W 6794.31 6863.64 6931.73 6998.46 7062.55 11654 7943.09 7855.05 39 47 N 81.60 W 4.02 965.67N 7666.64W 11748 8016.04 7928.00 38 12 N 79.10 W 2.39 975.54N 7724.87W 11844 8092.71 8004.67 36 0 N 76.00 W 3.00 988.00N 7781.48W 11939 8170.06 8082.02 35 12 N 73.20 W 1.91 1002.69N 7834.86W 12036 8249.60 8161.56 34 42 N 72.40 W .70 1019.13N 7887.96W 7122.34 7177.71 7232.96 7286.53 7340.74 12131 8327.86 8239-.82 33 0 N 71.60 W 1.86 1035.34N 7937.88W 12222 8405.89 8317.85 30 6 N 70.20 W 3.27 1050.99N 7983.16W 12319 8491.53 8403.49 26 30 N 69.10 W 3.74 1067.00N 8026.41W 12414 8577.13 8489.09 22 42 N 66.50 W 4.20 1081.75N 8062.71W 12444 8605.40 8517.36 21 53 N 68.40 W 3.52 1086.20N 8073.41W 7392.08 7439.12 7484.57 7523.38 7534.88 12535 8689.92 8601.88 20 6 N 63.70 W 2.72 1099.30N 8103.06W 12631 8780.87 8692.83 19 6 N 64.50 W 1.07 1113.46N 8132.19W 12726 8870.18 8782.14 18 36 N 62.10 W .98 1127.15N 8159.43W 12819 8958.31 8870.27 18 30 N 58.90 W 1.10 1141.70N 8185.16W 12912 9047.20 8959.16 18 0 N 60.80 W .83 1156.43N 8210.49W 7567.11 7599.41 7629.84 7659.40 7688.71 13008 9138.20 9050.16 17 47 N 61.80 W .38 1170.54N 8236.27W 13021 9151.14 9063.10 17 30 N 62.50. W 2.71 1172.47N 8239.91W 13102 9227.55 9139.51 17 30 N 62.50 W .02 1183.59N 8261.28W 7718.09 7722.21 7746.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8345.64 FEET AT NORTH 81 DEG. 50 MIN. WEST AT MD = 13102 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 300.00 DEG. SP-,~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/P- 7 500292253500 NORTH SLOPE COMPUTATION DATE: 2/17/95 DATE OF SURVEY: 021495 JOB NUMBER: AK-MW-50011 KELLY BUSHING ELEV. = 88.04 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATE S NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3570 3213.95 3125.91 95.16 N 1179.23 W 4570 3805.79 3717.75 193.18 N 1979.06 W 5570 4381.75 4293.71 323.63 N 2785.87 W 6570 4945.55 4857.51 413.35 N 3606.72 W 7570 5517.60 5429.56 485.76 N 4423.61 W 356.91 765.07 408.16 1189.11 424.04 1625.31 436.20 2053.26 427.95 8570 6110.87 6022.83 565.49 N 5224.60 W 9570 6694.60 6606.56 680.88 N 6028.16 W 10570 7267.53 7179.49 820.59 N 6835.74 W 11570 7880.29 7792.25 957.09 N 7611.84 W 12570 8723.41 8635.37 1104.74 N 8114.04 W 2459.99 406.73 2876.26 416.27 3303.33 427.07 3690.57 387.24 3847.45 156.88 13102 9227.55 9139.51 1183.59 N 8261.28 W 3874.45 27.00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. St ~RRY-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE SHARED SERVICES DRILLING PBU/P-7 500292253500 NORTH SLOPE COMPUTATION DATE: 2/17/95 DATE OF SURVEY: 021495 JOB NUMBER: AK-MW-50011 KELLY BUSHING ELEV. = 88.04 OPERATOR: BP EXPLORATION 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 VERTICAL DIFFERENCE CORRECTION 3570 3213.95 3125.91 3695 3288.04 3200.00 3861 3388.04 3300.00 4029 3488.04 3400.00 95.16 N 1179.23 W 105.72 N 1278.77 W 118.49 N 1411.37 W 133.86 N 1544.35 W 356.91 407.35 50.44 473.94 66.59 541.04 67.10 4196 3588.04 3500.00 4368 3688.04 3600.00 4540 3788.04 3700.00 4710 3888.04 3800.00 4880 3988.04 3900.00 149.61 N 1677.36 W 169.36 N 1815.86 W 189.67 N 1954.70 W 210.66 N 2091.02 W 233.00 N 2226.63 W 608.19 67.15 680.17 71.98 752.48 72.31 822.84 70.36 892.81 69.97 5052 4088.04 4000.00 5228 4188.04 4100.00 5405 4288.04 4200.00 5581 4388.04 4300.00 5758 4488.04 4400.00 258.69 N 2364.16 W 282.43 N 2506.03 W 304.53 N 2650.56 W 324.79 N 2794.85 W 343.12 N 2939.87 W 964.79 71.98 1039.98 75.20 1117.12 77.14 1193.84 76.73 1270.95 77.11 5937 4588.04 4500.00 6119 4688.04 4600.00 6295 4788.04 4700.00 6470 4888.04 4800.00 6645 4988.04 4900.00 359.72 N 3086.25 W 374.41 N 3238.54 W 387.85 N 3381.79 W 403.61 N 3525.03 W 421.21 N 3667.45 W 1349.02 78.07 1431.81 82.78 1507.03 75.23 1582.44 75.41 1657.35 74.91 6819 5088.04 5000.00 6993 5188.04 5100.00 7170 5288.04 5200.00 7346 5388.04 5300.00 7519 5488.04 5400.00 434.46 N 3809.46 W 445.71 N 3951.46 W 457.65 N 4097.03 W 470.22 N 4241.11 W 482.00 N 4381.55 W 1731.57 74.22 1805.61 74.04 1882.63 77.02 1958.47 75.84 2031.28 72.81 7691 5588.04 5500.00 7858 5688.04 5600.00 8026 5788.04 5700.00 8196 5888.04 5800.00 8365 5988.04 5900.00 494.83 N 4521.44 W 507.53 N 4654.76 W 521.40 N 4788.93 W 534.96 N 4924.92 W 548.48 N 5060.75 W 2103.72 72.44 2170.86 67.14 2238.78 67.92 2308.12 69.34 2377.33 69.21 8532 6088.04 6000.00 8699 6188.04 6100.00 8869 6288.04 6200.00 9040 6388.04 6300.00 9213 6488.04 6400.00 562.25 N 5194.26 W 576.92 N 5327.18 W 595.47 N 5463.27 W 615.08 N 5600.10 W 635.94 N 5739.74 W 2444.71 67.38 2511.70 66.99 2581.59 69.89 2652.21 70.62 2725.23 73.01 9386 6588.04 6500.00 657.40 N 5879.28 W 2798.23 73.01 Sb.~RRY-SUN DRILLING SERVICES ANC~tORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/P- 7 500292253500 NORTH SLOPE COMPUTATION DATE: 2/17/95 DATE OF SURVEY: 021495 JOB NIJMBER: AK-MW-50011 KELLY BUSHING ELEV. = 88.04 FT. OPERATOR: BP EXPLORATION 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 VERTICAL DIFFERENCE CORRECTION 9559 6688.04 6600.00 679.38 N 6018.99 W 2871.44 73.21 9732 6788.04 6700.00 702.64 N 6158.82 W 2944.92 73.48 9906 6888.04 6800.00 726.07 N 6298.69 W 3018.45 73.52 10080 6988.04 6900.00 750.39 N 6439.22 W 3092.64 74.19 10256 7088.04 7000.00 774.93 N 6581.23 W 3168.05 75.41 10431 7188.04 7100.00 801.02 N 6723.27 W 3243.71 75.66 10606 7288.04 7200.00 825.36 N 6864.86 W 3318.76 75.05 10781 7388.04 7300.00 848.61 N 7006.24 W 3393.48 74.72 10955 7488.04 7400.00 873.70 N 7145.89 W 3467.07 73.59 11126 7588.04 7500.00 899.65 N 7282.08 W 3538.02 70.95 11286 7688.04 7600.00 921.68 N 7405.28 W 3598.23 60.20 11439 7788.04 7700.00 941.11 N 7519.08 W 3650.98 52.76 11581 7888.04 7800.00 958.24 N 7618.91 W 3693.37 42.39 11712 7988.04 7900.00 971.38 N 7703.24 W 3724.87 31.50 11838 8088.04 8000.00 987.19 N 7778.16 W 3750.84 25.97 11961 8188.04 8100.00 1006.36 N 7847.00 W 3773.76 22.92 12083 8288.04 8200.00 1027.16 N 7913.17 W 3795.47 21.71 12201 8388.04 8300.00 1047.47 N 7973.26 W 3813.90 18.43 12316 8488.04 8400.00 1066.38 N 8024.74 W 3827.98 14.08 12425 8588.04 8500.00 1083.55 N 8066.88 W 3837.88 9.89 12533 8688.04 8600.00 1099.00 N 8102.44 W 3845.15 7.28 12639 8788.04 8700.00 1114.53 N 8134.43 W 3851.29 6.14 12744 8888.04 8800.00 1129.96 N 8164.74 W 3856.92 5.63 12850 8988.04 8900.00 1146.84 N 8193.67 W 3862.39 5.47 12955 9088.04 9000.00 1162.89 N 8222.08 W 3867.57 5.19 13060 9188.04 9100.00 1177.84 N 8250.23 W 3872.53 4.96 13102 9227.55, 9139.51 1183.59 N 8261.28 W 3874.45 1.92 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED FEB Alaska 0il & Gas Cons. Commission ~.ARR~ ~RANT Anchorage Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP P-07 (42-35-11-12) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Date: RE: 21 February 1995 Transmittal of Data ECC #: 6367.00 Sent by: ANCH.EXPRESS Data: OH-LDWG Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 February 1995 RE: Transmittal of Data ECC #: 6367.00 Sent by: ANCH.EXPRESS Data: OH-LDWG Dear Sir/Madam, - Reference: P-07 (42-35-11-12) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: DIFL/GR FINA~ BL+RF BHC-AC FINAL BL+RF SS VTD FINAL BL+RF WAT. SAT. FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please ~i~.~.-r.., smd ~a~ 0il & Gas Cons. ~mmisslon ~chorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISE~FO~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown x Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate ~ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration Development x KBE = 82.94 Exploratory __ 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service __ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2476' SNL, 1944' EWL, SEC. 31, T11N, R13E At top of productive interval N/A At effective depth N/A At total depth 2374' SNL, 697' EWL, SEC. 31, T11N, R13E ORI61NAL P-7 (42-35-11-12) 9. Permit number 94-164 10. APl number 50- 029-22535 11. Field/Pool Prudhoe Bay Field/Oil Pool feet 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 80' 3608' measured None 3650 3258 Size 20" 10-3/4" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None feet Plugs (measured) feet feet Junk (measured) feet Cemented 260 sx AS (Approx.) 1046 sx CS 111/375 sx "G"/ Measured depth True vertical depth 110' 3638' 110' 3251' RECEIVED JA[~ 2 4- 1995 Anchor~ - 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 1/11/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service Signed Title Drilling Engineer Supervisor Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative ma_~tne..,Ss---...~ I Approval No. ~ ,~ ,,,~, ~ Plug integrity ? ~_BE)P-~~----------------~'~'L~clear~'rf~ ,-~, _ ~Dp, over OO[yp 7o - ~- ~ Mechanical Int~~ ~quen~ requ~ed 1~ ~ ~- ~ d F~ 10 40JRev 06/15/88A roved b order of the Commission ~'- G°~mis~i°ner ~ ~ ~~~IT IN TRIPLIOATE ~ P-7 WELL OPERATION SHUTDOWN PROCEDURE Subject: Operation shutdown P-7 at Surface Casing Point in order that Rig N18E may be moved to Exploration. The well will be completed with Rig N28E in February, 1995. PROCEDURE 1. Notify AOGCC of intent to suspend well after performing surface casing test. 2. After displacing surface cement job, bump plug with 2000 psi. Perform top job if necessary. 3. Make up Universal starter and tubing heads. 4. Nipple up 13 5/8" BOP. Pressure test BOP body to 5000 psi. 5. Install bowl protector and run in hole with open ended drill pipe to TD. 6. Displace hole to sea or fresh water. Pressure test casing to 3000 psi and hold for 30 minutes. 7. POH to 2200' and displace to diesel for freeze protection. 8. POH and install a joint of 4 1/2" tubing and 4" tubing hanger with TWC. 9. ND BOP and NU tubing head adapter and tree. Test tree to 3000 psi. 10. Pull TWC and set BPV. Test casing and BPV to 1000 psi through tubing head. 11. Commence PVT mods. RECEIVED Gas Cons. C0mrn[ssi0n Anchon .~. WELL: m-7 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 01/07/95 01:00 SPUD: RELEASE: 01/11/95 06:00 OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 01/07/95 ( 1) TD: 110 PB: 110 01/08/95 (2) TD: 780 PB: 780 01/09/95 (3) TD: 3025' ( 0) 01/10/95 ( 4) TD: 3650'( 625) MIRU MW: 0.0 BLOW DOWN RIG AND PREPARE FOR MOVE FROM J-PAD TO P-PAD. MOVE COMPLEXES AND SUBBASE OFF JX-02 AND TRANSPORT PIPE SHED AND PITS TO P-PAD. MOVE IN WHEELS ON SUB AND TRANSPORT SAME TO P-PAD ALONG W/ MOTORS AND BOILER COMPLEX. BROKE "I" ON FRONT GOOSE NECK ON SUB. WELD AND REPAIR SAME. REPOSITION WHEELS ON SUB AND READY SUB TO MOVE OVER HOLE. SPREAD HERCULITE. SPOT AND LEVEL SUB AND PIT COMPLEX. DRILLING MW: 0.0 REMOVE SUPPORT BRACE AND REAR JACKING UNIT FORM PIT. SPOT REMAINING COMPLEXES. CONNECT STEAM, WATER, ELECTRICAL, AND LAY OUT ANTI SKID WALKWAY OVER HERCULITE. RU FLOOR. NU 20" DIVERTER AND FLOWLINE. ACCEPT RIG @ 1300 HRS ON 01/07/95. TAKE ON WATER, MIX SPUD MUD. THAW OUT MUD MOTOR AND STRAP BHA. FUNCTION TEST DIVERTER. PU BIT AND MOTOR. CODUCTOR FULL OF ICE. DRLG ICE OUT OF CONDUCTOR F/ 30 - 110' BLOW DOWN AND SET BACK KELLY. PU MWD. RESET ADJUSTABLE MOTOR AND ORIENT TOOLS. DRLG 13 1/2" SURFACE HOLE F/ 110 - 780'. DRILLING MW: 0.0 VIS: 0 DRLG 13 1/2" SURFACE HOLE F/ 780 - 1205'. SHORT TRIP TO DC'S. NO PROBLEM. WASH 30' TO BTM AND SURVEY. DRLG 13 1/2" SURFACE HOLE F/ 1205 - 2123' MADE 10 STD SHORT TRIP. NO PROBLEMS. WASHED 40' TO BTM. NO FILL. DRLG 13 1/2" SURFACE HOLE F/ 2123 - 3025'. RUN 10 3/4" CSG MW: 0.0 VIS: 0 DRLG F/ 3025 - 3140' MADE 11 STD SHORT TRIP TO 2100'. HOLE IN GOOD SHAPE. DRLG 13 1/2" HOLE F/ 3140 - 3650' CIRC BOTTMS UP. SHORT TRIP TO HWDP. SLM. NO CORRECTION. HOLE IN GOOD SHAPE. CIRC BTTMS UP TWO TIMES. CONDITION MUD AND HOLE. POH TO RUN 10 3/4" SURFACE CSG. LD BHA. RU CASERS. RUN IN HOLE W/ 76 JTS 10 3/4" 45.5# LT80 BUTT CSG. RECEIVED JAN 2 -'I. 1995 .oii.& (~as Cons. urommission Anchor~ -. RIG NABORS 18E PAGE: 2 01/11/95 ( 5) TD: 3650' ( 0) 01/12/95 ( 6) TD: 3650' ( 0) POH LD DP MW: 0.0 VIS: 0 FINISH RIH W/ TOTAL 90 JTS 10 3/4" 45.5# NT80 BUTT CSG. PU HANGER AND LANDING JT AND RUN CSG TO BOTTOM @ 3637'_ CIRC AND CONDITION MUD AND HOLE FOR CMT JOB. RECIPROCATE PIPE AND THIN MUD. TEST LINES. BJ CMT'D 10 3/4" CSG W/ SHOE @ 3637' AND FC @ 3554' PUMPED 75 BBLS WATER, 1046 SX COLD SET 3. DISPLACED WITH RIG PUMPS. BUMPED PLUG, FULL RETURNS, RECIPROCATED, NO CMT TO SURFACE, FLOATS HELD. RAN 1" TO 80' AND RU TO DO TOP JOB. BJ PUMPED 25 BBLS WATER AND 103 SX COLD SET 2. CIRC GOOD 14.5 PPG CMT TO SURFACE. RD CMT AND CSG TOOLS. ND DIVERTER. INSTALL 13 5/8" 5M SSH. TEST TO 1000 PSI AND INSTALL TEST PLUG. NU 13 5/8" 5M BOPS. TEST BOPS. FULL BODY TEST ON BOPS AND CHOKE MANIFOLD. PULLED TEST PLUG AND SET WEAR BUSHING. PU 9 7/8" BIT, 2 - 6 1/4" DC'S, JARS, XO, 15 HWDP. CUT DRLG LINE. RIH, TAGGED FC @ 3552'. RU TO TEVERSE CIRC. CIRC BOTTOMS UP. DISPLACE HOLE W/ FRESH WATER. TEST CSG. BREAK KELLY. POH LD DP. RELEASE RIG MW: 0.0 VIS: 0 RELEASED RIG TO STANDBY OPERATIONS ON 01/11/95 0600 HRS. SIGNATURE: (drilling superintendent) DATE: RECEIVED ]J 0-0 :\ ~ ~.~,~ ,'t ~, ~,~!~,, .0,'~ .& Gas Cons. Commission : ;Anchor~ - AI~SKA OIL AND GAS ~ CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 22, 1994 Terry Jordan, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit P-7 BP Exploration (Alaska) Inc 94-164 2476'NSL, 1944'EWL, Sec 31, T11 N, R13E, UM 3667'NSL, 4267'EWL, Sec 35, T11 N, R12E, UM Dear Mr Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the.Nodh Slope pager at 659-3607. David W nston Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 r...v r~* v ~._~.~. v v v la. Type of work Drill [] Redrill I-lllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 83.2 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28264 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2476' NSL, 1944' EWL, SEC. 31, T11N, R13E Prudhoe Bay Unit At top of productive interval '8. Well number Number 3626' NSL, 4339' EWL, SEC. 35, T11N, R12E P-7 (42-35-11-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 3667' NSL, 4267' EWL, SEC. 35, T11N, R12E 12/26/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa, dTVD) propert line ~DL 28265-3667 feet No close approach feet 2560 13114' MD/9209' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^AC 25.035 (e)(2)) Kickoff depth zoo feet Maximum hole an~lle 55 0 Maximum surface 3330 psig At total depth (TVD) ~800'/4390 psig Setting Depth 18. Casing program Specifications s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NT8OLHE Butt 4002' 29' 29' 4031' 3494' ~340 sx CS 111/375 sx "G"/250 sx CS II 9-7/8" 7-5/8" 29. 7# NT95HS NSCC 12674' 28' 28' 12702' 8821' 270 sx Class "G" 6-3/4" 5-1/2" 17# 13CR8O NSCC 562' 12552' 8682' 13114' 9209' 105 sx Class "G" 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 ConductorRECEIVED Surface Intermediate DEC 'l 6 1994 Production Liner AlaSka 0il & Gas Cons. Commission Perforation depth: measured Anchora true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify that ,~e fo~o~n_~ i..s true and correct to the best of my knowledge i~ Izl,,Ih~ Date )2~,//~/ Signed ;//~/,~/ .~~ Title Drillin~EnEineerSupervisor Commission Use Only Permit Number IAPI number IApproval date See cover letter ~.Sz,_,//~ ~ 150. O.~..,~_.P_. 2_ .5'-3~'I for other requirements Conditions of approval Samples required [] Yes l::ifl No Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required Eil Yes [] NO Required working pressure for BOPE [] 2M; CI3M; ~[5M; I-I10M; I-I15M; Other: by order of Approved by Commissioner me commission Date ~,,kr,ni~ in frinllr,~f, :orm 10-401 Rev. 12-1-85 n I Well Plan Summary I Well Name: I P-7 PBU Type of Well (producer or injector): Producer ISurface Location: Target Location: Bottom Hole Location: 2476' FSL 1944' FWL Sec31 T11N R13E UM 3626' FSL 4339' FWL Sec35 T11N R12E UM 3667' FSL 4267' FWL Sec 35 T11N R12E UM I AFL Number: I 4P0616 I Estimated Start Date: I Dec 26, 1994 I I Mg: i 13114' IITvD: Well Design (conventionalr slimhole~ etc.): Rig: I Nabors 18-E Operating days to complete: I 20 J 9209' I IRT-GL J KBE: I29.5' 83.2' J Slimhole producer Formation Markers: Formation Tops MD 'I'VD (BKB) Base Permafrost 1909' 1883' Ugnu Zone 4A 4535' 3783' Top Seabee (CM3) 7673' 5583' Kuparuk/Put River Absent Absent IKRU/LCU 10811' 7383' Top Sag River 12680' 8801' Top Shublik 12702' 8821' Top Sadlerochit 12809' 8922' Target 12874' 8983' Total Depth 13114' 9209' Casinq/Tubinc Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/'rVD 30" 20" 91.5# H-40 Weld 80' 30'/30' 110'/110' 13-1/2" 10-3/4" 45.5# NT80LHE Butt 4002' 29'/29' 4031'/3494' 9-7/8" 7-5/8" 29.7# NT95HS NSCC 12674' 28'/28' 12702'/8821' 6-3/4" 5 1/2" 17# 13Cr-80 NSCC 562' 12552'/8682' 13114'/9209' Tubing 4 1/2" 12.6 13Cr-80 NSCT 12475' 27'/27' 12475'/8612' Well Plan Summary Gas Cons. (;0remiss'ton Anchora e Logging Program: Open Hole Logs: 13 1/2" Hole 9 7/8" Hole 6 3/4" Hole Cased Hole Logs: 7 5/8" Casing 5 1/2" Liner None None GR/DIL/BHCS None Optional SBT and Gyro Mud Program: Special design considerations None Surface Mud Properties: I SPUD Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 9 15 to to to to to to to 9.5 400+ 60 60 80 10 25 Intermediate Mud Properties: I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 5 to to to to to to to 10.0 50 15 10 20 10 10 Production Mud Properties: I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel qel Loss 8.8 30 8 3 7 8 6 to to to to to to to 9.2 45 13 10 15 9 8 NOTE'. Keep annular velocities around drill pipe at or above 220 ft/min wherever possible Directional: I KOP: I zoo' I Maximum Hole Angle: I 55.0 degrees Close Approach Well: None The above listed wells will be secured during the close approach. Well Control: 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 drilling fluid system schematics on file with AOGCC. Well Plan Summary DEC 1 6 1994. ~!~k~ Oii & 6as Cons. C0mmissi0n Anch0ra PROPOSED DRILLING AND COMPLETION PROGRAM WELL P-7 [ 42-35-11-12 ] PBU 1. MIRU. NU diverter and function test same. 2. Drill 13-1/2" hole. Run and cement 10-3/4", 45.5#, NT-80 Buttress casing to sudace. . Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Function test BOPE to 5000/250 psi. . Test 10-3/4" casing to 3000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 10-3/4" shoe. . Directionally drill 9-7/8" hole to Shublik Formation (12702' MD/8821' 'I-VD). Run a 7-5/8", 29.7#, NT-95 NSCC casing string and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dry crude. Bump plug. Test casing to 3500 psi. , Drill out of 7-5/8" casing with a mud weight of at least 0.5 ppg over the highest anticipated mud weight to used while drilling 6-3/4" hole for formation integrity test. Directionally drill the 6-3/4" hole to TD. Run 5-1/2", 17#, 13 Cr-80 NSCC liner from TD to 150' inside 7-5/8" casing shoe and cement using Class G cement. . Clean out to 5-1/2" float equipment. Change over to filtered seawater completion fluid. Test casing and lap to 3500 psi. , Run 7-5/8" production packer on the 4-1/2", 12.6~, L-80 NSCT tubing. A subsudace safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with diesel from sudace to 2100' TVDBKB. Set and test packer. 10. The well will be pedorated after the rig has been released. Fluids incidental to the drilling of a well will be injected down CC-2A. Tubing Size' 4-1/2", 12.6~, L-80 tubing with 6 GLM's. Anticipated BHP Planned Completion Fluid 3750 psi @ 8800 TVDss 8.5 ppg Seawater Notes: a. b. C. d. The drilling program and surface system will conform to the regulations set forth in 20AAC25.003. Maximum surface pressure is based on BHP and a full column of gas to TD (0.1 psi/ft). Based on previous logs on P Pad, no potential productive zones are anticipated above Sag River (8713' TVDss). No potential hazardous levels of H2S are anticipated in this well. _DDril!Ln,q Hazards: · Fault, 325' NE of target location with 150' throw. · Faults, medium to small faults surround target location about 300' away. · Sag River/Shublik formations may be slightly over pressured. P-09 experienced similar problems. · Gas hydrates may be present below the permafrost. R E C ~ ~V E D Well Plan Summary DEC 1 6 1994 0il & Gas Cons. Commission Anchor 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE' 10-3/4" CIRC. TEMP' 38°F PREFLUSH: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: COLD SET III ADDITIVES: retarder WEIGHT: 12.2 ppg APPROX. # SACKS: 1340 YIELD: 1.92 ft3/sx MIX WATER: 10.53 gps THICKENING TIME- Greater than 4 hrs. @ 50°F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% A-7 +1 ghs FP-6L WEIGHT: 15.8ppg YIELD: 1.15ft3/sx APPROX. # SACKS: 375 MIX WATER: 4.95 gps THICKENING TIME: Greater than 3-1/2 hrs @ 50°F TOP JOB CEMENT TYPE: COLD SET II ADDITIVES: WEIGHT: 14.5 ppg APPROX. # SACKS: 250 CENTRALIZER PLACEMENT: 1. Run 1 bow type centralizer per joint for the first 15 joints. 2. Place the centralizers in the middle of each joint with a stop collar. CEMENT VOLUME: 1. Lead slurry from TD to sudace w/100% excess (less the tail slurry volume). 2. Tail slurry volume 375 sx (to cover 500' of casing shoe w/100% excess). 3. Top job volume 250 sx. YIELD' 0.96 ft3/sx MIX WATER: 3.89 gps THICKENING TIME: Greater than 2 hrs @ 50°F Well Plan Summary R£C£1¥£D DEC ~ 6 1994 ,,~aska 0il & Gas Cons. Commission Anchora : 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 7-5/8" PREFLUSH: 20 bbls fresh water SPACER: 70 bbls BJ MCS-4 Spacer weighted at mud weight. CIRC. TEMP: 140°F TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0,1% A-2 + 1 ghs FP-6L WEIGHT: 15.8 ppg YIELD: 1.14 ft3/sx MIX WATER: 4.85 gps APPROX.# SACKS' 270 THICKENING TIME: 3-1/2 to 4-1/2 hrs FLUID LOSS' 100-150 cc/30 minutes FREE WATER' 0 cc CENTRALIZER PLACEMENT: 1. Run 2 Turbulators per joint to 300' MD above top of Sadlerochit. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix tail slurry on the fly. CEMENT VOLUME: 1. Tail slurry to 1000' MD above top of Sag River with 30% excess. 2. 80' MD 7-5/8", 29.7# capacity for float joints. Note: No hydrocarbon bearing zones are identified in the Ugnu and Sag River intervals, Well Plan Summary Gas Con~. Commission Anchor[ 5-1/2" PRODUCTION LINER CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140° F BHST: 220° F at 8800' TVDSS. PREFLUSH: 20 bbls fresh water SPACER: 70 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. CEMENT TYPE: CLASS G ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + 0.5% gel + 2 ghs FP-10L WEIGHT: 15.7 ppg YIELD: 1.17 ft3/sx MIX WATER: 3.58 gps APPROX. # SACKS: 105 THICKENING TIME: 45 min. @ Sudace + 3-4 hrs @ 140°F FLUID LOSS: less than 50 cc/30 minutes @ 140°F FREE WATER: 0 cc at 45° angle. NOTE: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencies ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: 1. Run 2 right hand turbolators per joint in open hole, 2. Run I right hand turbulator per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 50 cc/30 min. or less. Report actual fluid loss on morning report. Displace @ 6-8 bpm. LINER CEMENT VOLUME: 1. Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper Icg is run and it indicates severe washouts). 2. 5-1/2", 17# casing capacity below landing collar (80'). 3. 150' liner lap (6.875"x 5-1/2") 4. 200' of cement on top of the liner in the 7-5/8" casing. RECEIVED DEC 1 6 !99 Ai~$k~ Oil & Gas Cons. Commission Anchor~. ~ Well Plan Summary ? wothoe Bo.y Unit P-PAD P-07 (P-P) PRELIMINARY ELLPLAN HALLIBURTON I I I I I I I I I I I I I _1_ .2_ ._L_ __1 .... VERTICAL ~ SCALE 50O ~t. / DMSI~ TV]] REF, VT1 I I-EAD VERrFICAL S2]CTI[N RE]:-: _ M~ 1nc AZL TV'D N.~ o ~ ~7~00 0 ON OE 700 000 ET~O0 ~ O N 0 E B~72 .mm 1121 ~O/100 F~ Ig00 1800 27'~O0 1880 7 N 1B7 ECI~6 ICZ]0 ~ ~ BN ~W ~ ~ ~ ~ ~ N 1121 1~11 ~ ~ ~ ~ N G~ 11~ ~ ~ ~ ~ N 71~ t1~ ~,~ ~,14 ~ ~ N ~ 11~ ~,~ ~.14 81~ ~ N ~ 1~ ~ ~ ~ 11~1 N 8114 I~ ~ ~ ~4 11~ N 81~ K-lO DEC 1 6 ! 94 Oil & Gas Cons. Commission Anchor~: ' 13114 0 ~CO 1000 1500 ~ ~ 3030 3503 4C03 4500 50gO 5500 6gl]D ~ 7000 I I I EV G~d X Cz, id Y JTomqe-t No~e TV]] Tomg~ 8980 i150 N 8165 W 6c~3045 5g~8~15 ~ P[IINT ]]4TA Fm MIl Inc ~ 1-VI) 10 3/4 In 4;331 55J30 ;~z7~ZI] 3~200 IE~o N 147B 7 5/8 In IEYO~ EqZ1Z~] 3OOZ]O 88E7 11Pl N 8114 TVI) MD 13114,42. VS N,/S 1191,~ E./W 8EY~,63 WELLPLAN FEASIBILITY STUDY This plan is for feasibility purposes only, it has not yet been certified. R~ udtnoe Bay D~illin g ~ P~udhoe Bay Un i-t; ~. P-PAD P-O? (P-P) Wp5 PRF-LIMINARY WELLPLAN 0 t HALL~BOqT[N -15 240 ;310 150 180 ~[D Inc Az~. ~ TIE IN 0 OEI3 ~F2~)O 0 ~ / START 7IX] O, O0 878J30 700 1~50/1C0 Pt 84c~ ~ EF2DO ~371 N/S E/V ON OE ON OE 7N 187'V 8N 886V 13N 325V 3~ 55~ ~77JC0 3248 82 N 1 i21 7673 55ED 877~]0 5589 489 N 4439 i08tl 5~ ~rT~CO 7389 80~ N GggO ilO05 55~]0 ~zTED 7500 8~ N 7i48 118[I~ 3~,~0 E~13,14 ~ ~ N ~ V 11955 37.40 E~;O.14 817~ 978 N ~ V 12964 20Z13 3[]0/]O gQ74 Note: These error factors represent Alaska BP Wolff & deWardt tool code settings DEC ~,'~s~ Oki & Gas Goos. Gom~ls~o~ WELLPLAN FEASIBILI~ S~DY ~chor~ ~is pI~ is for f~ibiliW p~scs only, it h~ not yet ~cn ~~. ! 1 t6 N 810~ ! 117 N 8108 1181 N 8114 l13g N 8146 1150 N 8165 ~/ t!6~ N 81~ W _ 8114 W ~ 1lEi 8c~ tI50 N 8165 W 6c23045 5~i5 WELL PERMIT CHECKLIST WELL NAME GEOL ARF_~ UNIT# PROGRAM: exp [] dev~( redrll [] serv [] ON/OFF SHORE O/%J ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING ., GEOLOGY 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate . Y N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~-~ psig. N 27. Choke manifold complies w/A~I RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ _ 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ......... ~ N 34. Contact name/phone for weekly progress reports .... /Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: O HOW/jo - A:%'=ORMS%cl~eklist rev 03194 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. P- 07 e/~~//~~ PRUD~~ BAY ~~' qq Run 1' 15 - February - 1995 DIFL/ACIGR 115OO 13O8O WESTERN JL-H ATLAS · t~ts_ l./~/o( Atlas Wireline Services Tape Subfile 2 is type: LIS · · TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6367.00 BRAD ESARY SEE REMARKS P - 07 (42-35-11-12) 500292253500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 20-FEB-95 RUN 2 RUN 3 31 liN 13E 2476 1944 88.04 86.54 53.74 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 REMARKS: DIFL/AC/GR. 10.750 3637.0 13102.0 CIRCULATION STOPPED AT 2330, 14-FEB-95. LOGS WITNESSED BY: M. FERNANDEZ & H. HAYWOOD. TOOL HAD DIFFICULTY FALLING FROM 7100' TO 11200' DUE IN PART TO DEVIATION & HEAVY MUD CAKE BUILD UP ON TOOL. TAGGED TD AT 13083' ON REPEAT, & 13081' ON MAIN PASS. BOTTOM OF HOLE WAS STICKY. RIG PUMPED LCM PILL PRIOR TO POOH. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (9.875"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. ON ACOUSTIC MAIN PASS, REPLACED AC SIGNAL WITH REPEAT AC SIGNAL FROM 12962' TO 13008' DUE TO TRANSMITTER / · RECEIVER ERROR. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL $ depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 11500.0 13031.0 11500.0 13050.0 11500.0 13078.0 GR (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH LL8 11508.5 11541.0 11541.5 11571.0 11575.0 11576.0 11590.5 11591.0 11592.0 11600.0 11601.5 11666.5 11667.0 11675.0 11683.0 11689.5 11719.0 11721.5 11735.5 11736.0 11755.0 11775.5 11776.0 11824.0 11840.5 11841.0 11844.0 11849.0 11870.5 11883.5 11888.0 11892.5 11925.0 11930.0 11958.5 11974.0 12003.0 12003.5 12011.0 12011.5 12012.5 11666.5 11683.0 11690.0 11735.5 11776.0 11840.0 11869.5 11893.0 11925.5 11958.5 12011.5 all runs merged; no case EQUIVALENT UNSHIFTED DEPTH ILD DT 11509.0 11541.0 11541.5 11571.5 11575.5 11576.0 11590.5 11591.5 11592.5 11601.0 11601.5 11666.5 11675.0 11683.0 11689.5 11718.5 11721.5 11736.0 11755.0 11776.5 11824.0 11839.5 11840.0 11843.0 11849.0 11870.5 11883.5 11888.5 11892.5 11925.5 11929.5 11974.5 12002.5 12003.5 12011.5 12012.5 12024.0 12026.8 12042.5 12050.5 12077.5 12120.5 12127.0 12162.0 12190.0 12233.0 12233.5 12243.5 12244.0 12271.0 12274.0 12282.5 12293.0 12295.5 12304.5 12311.0 12315.5 12331.0 12332.0 12345.5 12363.0 12369.0 12372.0 12381.5 12383.0 12388.5 12393.0 12393.5 12414.5 12421.0 12431.5 12432.5 12443.5 12453.5 12470.5 12472.5 12477.0 12480.0 12480.5 12507.5 12508.5 12512.5 12515.0 12517.0 12524.5 12531.0 12559.5 12577.5 12586.0 12627.0 12639.5 12648.0 12653.0 12654.5 12666.0 12672.0 12050.0 12126.5 12233.0 12271.0 12296.0 12304.5 12310.5 12383.0 12414.5 12454.0 12512.5 12513.5 12515.5 12559.5 12672.0 12024.0 12027.0 12050.5 12120.5 12127.5 12190.0 12242.5 12243.0 12331.0 12344.5 12372.0 12381.5 12388.0 12393.5 12413.5 12431.0 12432.0 12471.5 12473.5 12480.0 12507.0 12508.0 12523.5 12530.0 12577.0 12586.0 12627.0 12653.5 12666.0 12043.0 12050.5 12078.0 12126.5 12160.5 12232.5 12274.0 12282.0 12294.0 12316.0 12332.0 12345.0 12363.5 12369.0 12393.0 12414.0 12420.0 12442.5 12477.0 12480.0 12512.5 12517.0 12559.5 12639.5 12648.0 12654.5 12671.5 12672.5 12686.5 12690.0 12690.5 12702.5 12708.5 12709.0 12709.5 12710.5 12711.0 12713.0 12720.0 12722.5 12726.5 12729.0 12731.0 12734.0 12739.5 12740.5 12741.0 12745.0 12745.5 12757.0 12760.5 12762.0 12773.0 12777.0 12779.0 12796.5 12805.5 12818.5 12826.0 12828.5 12833.0 12848.0 12852.0 12866.0 12866.5 12879.5 12893.5 12896.5 12901.0 12907.5 12909.5 12916.5 12936.0 12945.0 12946.5 12947.5 12974.0 12985.5 12990.0 13008.5 13010.5 13019.5 13024.0 l~O~l,O 13041.5 13073.0 $ 12689.5 12702.5 12709.5 12713.0 12726.5 12731.0 12745.5 12761.5 12778.5 12797.0 12818.5 12833.0 12865.5 12896.0 12907.0 12936.0 12946.0 12947.5 13008.0 13010.0 12673.5 12684.5 12689.0 12707.5 12708.5 12709.0 12722.0 12734.0 12739.5 12740.5 12741.5 12746.0 12758.0 12764.0 12773.0 12777.5 12806.0 12829.0 12847.5 12865.0 12946.0 12989.5 13010.0 13041.5 13073.0 12690.0 12702.5 12711.0 12719.5 12726.5 12728.5 12731.0 12745.5 12760.0 12762.0 12779.0 12796.0 12826.5 12833.0 12851.5 12866.5 12879.5 12893.0 12901.5 12906.5 12909.0 12916.0 12945.0 12973.5 12985.5 13019.0 13024.5 13041.0 MERGED DATA SOURCE PBU TOOL CODE GR BCS DIL $ REMARKS: RUN NO. PASS NO. MERGE TOP 1 5 11500.0 1 5 11500.0 1 5 11500.0 MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, DI, & SP WERE SHIFTED WITH ILD. MERGE BASE 13031.0 13050.0 13078.0 CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3 .OUT $ : BP EXPLORATION (ALASKA) : P- 07 (42-35-11-12) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL8 DIL 68 1 OHMI~ 4 6 ILM DIL 68 1 OHMM 4 7 ILD DIL 68 1 OHMM 4 8 RT DIL 68 1 OHMM 4 9 DI DIL 68 1 IN 4 10 SP DIL 68 1 MV 4 11 MTEM DIL 68 1 DEGF 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 152 Tape File Start Depth = 13090.000000 Tape File End Depth = 11498.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38221 datums Tape Subfile: 2 416 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS 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: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 5 .2500 VENDOR TOOL CODE START DEPTH GR 11500.0 AC 11500.0 DIFL 11500.0 $ 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 13060.0 13078.0 13089.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 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: 15-FEB-95 FSYS JlV2 BTEA RELEASE 4 2330 14-FEB-95 1236 15-FEB-95 13102.0 13083.0 11500.0 13080.0 1500.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 9.875 3637.0 .0 LSND + LCM PILL 9.70 54.0 9.2 2.5 190.1 3.360 56.0 1. 070 190.1 2.760 56.0 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 : BP EXPLORATION (ALASKA) : P - 07 (42-35-11-12) : PRUDHOE BAY : NORTH SLOPE : ALASKA .000 .0 3.980 56.0 .000 .0 .00 .000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 CHT AC 68 1 LB 5 TTEN AC 68 1 LB 6 SPD AC 68 1 F/MN 7 RFOC DIFL 68 1 OHMM 8 RILM DIFL 68 1 OHMM 9 RILD DIFL 68 1 OHMM 10 RT DIFL 68 1 OHMM 11 DI DIFL 68 1 IN 12 CFOC DIFL 68 1 MMHO 13 CILM DIFL 68 1 MMHO 14 CILD DIFL 68 1 MMHO 15 VILM DIFL 68 1 MV 16 VILD DIFL 68 1 MV 17 SP DIFL 68 1 MV 18 TEMP DIFL 68 1 DEGF 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 06 213 78 0 4 4 72 155 24 6 4 4 33 393 51 6 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 490 Tape File Start Depth = 13090.000000 Tape File End Depth = 11498.000000 Tape~File~Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 121012 datums Tape Subfile: 3 566 records... Minimum record length: 62 bytes Maximum record length: 994 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 4 .250O VENDOR TOOL CODE START DEPTH GR 12616.0 AC 12616.0 DIFL 12616.0 $ 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 13060.0 13077.0 13089.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 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: 15-FEB-95 FSYS JlV2 BTEA RELEASE 4 2330 14-FEB-95 1206 15-FEB-95 13102.0 13083.0 11500.0 13080.0 1500.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 9.875 3637.0 .0 LSND + LCM PILL 9.70 54.0 9.2 2.5 190.1 3.360 56.0 1.070 190.1 2.760 56.0 .000 .0 3.980 56.0 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 : BP EXPLORATION (ALASKA) : P - 07 (42-35-11-12) : PRUDHOE BAY : NORTH SLOPE : ALASKA .000 .00 .000 1.5 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 CHT AC 68 1 LB 5 TTEN AC 68 1 LB 6 SPD AC 68 1 F/MN 7 RFOC DIFL 68 1 OHMM 8 RILM DIFL 68 1 OHMM 9 RILD DIFL 68 1 OHMM 10 RT DIFL 68 1 OHMM 11 DI DIFL 68 1 IN 12 CFOC DIFL 68 1 MMHO 13 CILM DIFL 68 1 MMHO 14 CILD DIFL 68 1 MMHO 15 VILM DIFL 68 1 MV 16 VILD DIFL 68 1 MV 17 SP DIFL 68 1 MV 18 TEMP DIFL 68 1 DEGF API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 72 155 24 6 4 4 33 393 51 6 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 72 * DATA RECORD (TYPE# 0) Total Data Records: 156 994 BYTES * Tape File Start Depth = 13117.000000 Tape File End Depth = 12613.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 76545 datums Tape Subfile: 4 230 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile ~5 is type:-LIS 95/ 2/20 01 **** REEL TRAILER **** 95/ 2/21 O1 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 21 FEB 95 8:07a Elapsed execution time = 12.42 seconds. SYSTEM RETURN CODE = 0