The URL can be used to link to this page

Home My WebLink About197-200XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~"~' '~~ File Number of Well History File PAGES TO DELETE 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 vadous kinds Other Complete COMMENTS: Scanned by: Sever~y Mildred Daretha ~owell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 y " Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 4 I 333 West 7 Avenue a, Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) I MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ -05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 ` MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 12 NA 1.2 NA 11.9 8/20/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 64.12' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2179' NSL, 3276' WEL, SEC. 28, T13N, R10E, UM X = 552045, Y = 6014577 MPJ-21 At top of productive interval 9. Permit Number / Approval No. 197-200 1446' NSL, 1502' WEL, SEC. 29, T13N, R10E, UM X = 548547, Y = 6013821 10. APl Number At effective depth 50-029-22825-00 1419' NSL, 1728' WEL, SEC. 29, T13N, R10E, UM X = 548322, Y = 6013792 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 1407' NSL, 1679' WEL, SEC. 29, T13N, R10E, UM X = 548371, Y = 6013780 12. Present well condition summary Total depth: measured 6260 feet Plugs (measured) true vertical 4237 feet Effective depth: measured 6155 feet Junk (measured) Fish (04/03) true vertical 4146 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface Intermediate Production 6212' 7" 1471 sx PF 'E', 258 sx Class 'G' 6242' 4221' Liner Perforation depth: measured 5918'-5938', 5986' - 6006'R F. C E VE D true vertical 3943'- 3960', 4001'- 4018' JUN 0 6 Z003 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 5771'. Alaska 0il & Gas Cons. Commission Anch0ra[~e Packers and SSSV (type and measured depth) N/A '"13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure '~ 4. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: i 5. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true_.~.n~d correct to the best of my knowledge s ? ,- Title Technical Assistant Signed ~~-~-~ ~~ .............. ,, Date ,~% ~ ! ~ ! ~ ~ j~ ~ Prepared By Name/Number: Sondra Stewrnan, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate BP EXPLORATION Page 1 of 2 Operations Summa Report Legal Well Name: MPJ-21 Common Well Name: MPJ-21 Spud Date: Event Name: WORKOVER Start: 4/27/2003 End: 5/1/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/1/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 4/26/2003 13:00 - 14:30 1.50 MOB P PRE Scope and lower Derrick. 14:30 - 15:30 1.00 MOB P PRE Prepare Rig and Equipment for move from DS 17 to MPJ-21 ...47.4 miles. 15:30 - 00:00 8.50 MOB P PRE 'Move Rig and Equipment off DS 17...cross Sag River on ice road with no problems. Continue rig move to Milne Point. 4/27/2003 00:00 - 06:00 6.00 MOB P PRE Continue to move Rig and Equipment to Milne Point J-Pad. 06:00 - 09:30 3.50 RIGU P . PRE Spot Sub Base, Pits, Pipe Shed, and Camp. 09:30 - 11:00 1.50 RIGU P PRE Raise and scope Derrick. Take on Sea Water (140 deg. F.) in Rig Pits. 11:00 - 12:30 1.50 RIGU P 'DECOMP ACCEPT RIG @ 11:00 Hrs. R/U lines to tiger tank & tree. Take on 8.5 ppg seawater. Pull BPV. 12:30 - 13:30 1.00 RIGU P DECOMP Hold Pre-spud mtg w/all hands. Test lines to 3000 psi. 13:30 - 16:00 2.50 KILL P , DECOMP Open well, SlTP 280 psi, SICP 450 psi. Begin killing well. :Pump in @ 3 BPM, 700 psi. Bull headed into formation @ 2 'BPM, 1300 psi. Con't to kill @ 4 BPM, 900 psi. Monitor well. 16:00 - 18:00 2.00 KILL P 'DECOMP ;Well not dead. Circulate @ 5 BPM, 1150 Psi. Monitor well. TP : 170 psi, Cp 150 psi. 18:00 - 20:30 2.50 KILL P DECOMP i Monitor well. Wait on salt to weight up. Bleed off & SI well, ;stabilized @ 50 psi on both sides. 20:30 - 22:00 1.50 KILL P !DECOMP i Weight up to 9+ ppg. Circulate well 5 BPM @ 1250 psi. Pump :1 well volume 220 Bbls until returns were 9+ ppg. 22:00 - 23:00 1.00 KILL P i DECOMP Monitor well, well dead. Set TWC & test same to 1000 psi, Ok. 23:00 - 00:00 1.00 WHSUR P DECOMP N/D X-mas tree & remove from cellar area. 4/28/2003 00:00 - 02:00 2.00 BOPSUF.P DECOMP N/U BOPE. 02:00 - 05:00 3.00 BOPSUF.P DECOMP Test BOPE per BP and AOGCC requirements. 250/2,500 psi...Good test. State's right to witness test waived by C. Sheve. 05:00 - 06:00 1.00 WHSUR P DECOMP PU lubricator. Pull TWC. Monitor well. Well flowing. 06:00 - 08:30 2.50; KILL N FLUD DECOMP Circulat/condition well at 3.5 bpm/700 psi. Monitor well. Slight flow continues. Discuss with production shutting in or reducing injection rate from MPJ17i. 08:30 - 11:00 2.50 KILL N FLUD DECOMP Weight up (9.1) and circulate well over to 9.3 (heavy) brine. Monitor...well dead. 11:00 - 11:30 0.50 WHSUR P DECOMP LD Lubricator. 11:30 - 13:00 1.50 WHSUR P DECOMP PU Landing Jr. BOLDS. Pull Hanger to floor. 48K break back to 45K. 13:00 - 17:30 4.50 PULL P DECOMP Start TOOH wi2 7/8" Tbg, Heat Trace/ESP Assy. 17:30 - 18:00 0.50 PULL P DECOMP Con't to POOH. Pull Heat Trace line over Sheave to spooler. Clear & clean floor. 18:00 - 20:30 2.50 PULL P DECOMP Con't to POOH to ESP. Stand back tbg. Spool up control line. 20:30 - 22:00 1.50 PULL P DECOMP Inspect & LID ESP. Pump had twisted shaft. Recovered lead nodule on top of ESP. Possibly f/an impression block run? 22:00 - 23:00 1.00 PULL P DECOMP Clear & clean floor. Change out equip to P/U Cleanout assy & DP. 23:00 - 00:00 1.00 PULL P DECOMP M/U BHA #1 & RIH. Clean out assy, bit, scraper & junk baskets. 4/29/2003 00:00 - 04:00 4.00 PULL P DECOMP P/U 3 1/2" DP & RIH. Tag up @ 5986'. 04:00 - 06:00 2.00 CLEAN P DECOMP P/U Kelly & wash & rotate down. Then reverse up DP. Recovered chunks of rubber & Formation sand. Also had oil & gas to surface @ bottoms up. Top 30' washed hard. Washed easier as we got deeper. 06:00 - 08:00 2.00 CLEAN P DECOMP Continue to wash and rotate from 6,106 down to 6,155 (PBTD). Rev circ btms up at 4bpm/700 psi. Formation sand in returns. Printed: 5~5~2003 11:39::35 AM BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: MPJ-21 Common Well Name: MPJ-21 Spud Date: Event Name: WORKOVER Start: 4/27/2003 End: 5/1/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/1/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From-To Hours Task Code NPT Phase Description of Operations 4/29/2003 06:00- 08:00 2.00 CLEAN P DECOMP Rev until clean. 08:00 - 09:00 1.00 CLEAN P DECOMP Cont to Rev. Off-load clean 9.3 heavy brine in pit. Mix 40bbl sweep. 09:00-09:30 0.50 CLEAN P DECOMP SetbackKellyandLD7jts31/2"DP. Bit at 5,915-ft (at top perfs) 09:30 - 11:30 2.00 CLEAN P DECOMP Reverse in with 20 bbl Hi-Vis sweep...20 bbl brine spacer...20 bbl Hi-Vis sweep. Chase with clean 9.3 heavy Brine. Monitor well. 11:30 - 14:30 3.00 CLEAN N DPRB DECOMP Circulate well & weight up to 9.5 ppg brine. Pump in @ 4.5 BPM, 800 Psi. 14:30- 16:00 1.50 CLEAN N DPRB DECOMP POOH & LDDP. Well started flowwing. SI & monitor well pressue. SIDPP 0 Psi, SICP 0 Psi. Open well well started flowing. 16:00 - 18:00 2.00 CLEAN N DPRB DECOMP Circulate bottoms up, 4 BPM @ 700 Psi. SD monitor well, Well flowing. 18:00 - 19:30 1.50 CLEAN N DPRB DECOMP RIH back to bottom. Circulate & weight up to 9.7 ppg. 5 BPM @ 900 psi. 19:30 - 20:30 1.00 CLEAN P DECOMP Monitor well, well dead. POOH & L/D 15 Jts DP. Check well, well dead. Pump dry job. 20:30 - 00:00 3.50 CLEAN P DECOMP POOH & L/D 3 1/2" DP & BHA #1. Recovered broken chisel in Boot basket. 4/30/2003 00:00 - 03:30 3.50 RUNCOkP COMP R/U floor to run completion. PJSM & Pick up / service ESP. Plug in & test same. 03:30 - 04:30 1.00 RUNCOItP COMP RIH w/ESP completion .... 2300' (+-). 04:30 - 05:30 1.00 RUNCOItP COMP PJSM. Rig up to run heat trace. 05:30 - 06:30 1.00 RUNCOItP COMP RIH w/ESP-Heat Trace completion. 06:30 - 08:00 1.50 RUNCOItP COMP Slip & Cut drilling line. 08:00 - 14:30 6.50 RUNCOI~P COMP Continue to RIH w/ESP-Heat Trace completion string, running continuous flat guard on ESP cable. 14:30 - 15:00 0.50 RUNCOI~I~I STUC COMP Stack out @ 3350'. Overpull 22K to 55K, up wt 33K, down wt 25K. Pull free @ 55K & slack off seeing stack out in exactly same spot every time. Work pipe & mix EP lube pill. 15:00 - 16:00 1.00 RUNCOr !~1 STUC COMP Circulate 15 bbl EP lube pill @ lbpm / 2600 psi. Chase with tubing volume, (20 bbls). 16:00 - 00:00 8.00 RUNCOr P COMP Continue in hole w/completion string. See stack out approximately 35' below original stackout point. Pop through & appears we may have rolled junk on top as we are not seeing any more bobbles. Con't to RIH w/completion. Check cable every 1000'. Flush pump, 1 BPM @ 2000 Psi. 5/1/2003 00:00 - 01:00 1.00 RUNCO~/F' COMP Con't to RIH w/2 7/8" ESP-HT completion. Flush pump 1 BPM @ 2000 Psi. TEST every 1000'. 01:00 - 01:30 0.50 RUNCOI~ COMP M/U landing Jt on hanger. R/U to circulate. 01:30 - 05:30 4.00 RUNCOI~ COMP Splice EFT connectors on ESP & HT line. TEST same. Circulate 150 Bbls @ 1 BPM, 2000 PSI to displace EP lube out ;of annulus. 05:30 - 07:00 1.50 RUNCOI~ COMP ' Land completion. RILDS. P/U 45K, S/O 37K. Set & test TVVC. 07:00 - 08:30 1.50 BOPSUF.P COMP PJSM. N/D BOPE 08:30 - 11:00 2.50 WHSUR ~ COMP PJSM. N/U tree & test @ 5000 psi / 30 minutes, OK. Set BPV & secure well. Rig released @ 11:00 hrs 05/01/2003. Printed: 5/5/2003 11:39:35 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 64.12' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2179' NSL, 3276' WEL, SEC. 28, T13N, R10E, UM MPJ-21 At top of productive interval 9. Permit Number / Approval No. 197-200 1446' NSL, 1502' WEL, SEC. 29, T13N, R10E, UM 10. APl Number At effective depth 50-029-22825-00 1418' NSL, 1627' WEL, SEC. 29, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 1406' NSL, 1679' WEL, SEC. 29, T13N, R10E, UM 12. Present well condition summary Total depth: measured 6260 feet Plugs (measured) true vertical 4237 feet Effective depth: measured 6155 feet Junk (measured) true vertical 4146 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface Intermediate Production 6212' 7" 1471 sx PF 'E', 258 sx Class 'G' 6242' 4221' Liner Perforation depth: measured 5918'- 5938', 5986'- 6006'RECEIVED true vertical 3943'- 3960', 4001'- 4018' ~PJ~ 1 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 5774'. Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that t~ng is true a~n~correct to the best of my knowledge Signed Sondra Stew~~.~L~----'~:~%~ Technical Assistant Date :?~ ~?~'~..~. ~ ~'~ ~:. ~, ~ .ere. ~.~ red By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate ~LORATION Page1 of 1 mmary Report Legal Well Name: MPJ-21 Common Well Name: MPJ-21 Spud Date: Event Name: WORKOVER Start: 4/1/2002 End: 4/2/2002 Contractor Name: NABORS Rig Release: 4/2/2002 Rig Name: NABORS 4ES Rig Number: 4 ~ours Activity Code ~PT?Phase ~: Description of Operations 3/31/2002 15:00 - 19:30 4.50 RIGD N POST WAIT ON TRUCKS 19:30 - 00:00 4.50 MOB P PRE MI/RU & SAFE OUT EQUIPMENT. RIG ACCEPT@ 00:01 HRS. 4/1/2002 4/1/2002 00:00 - 00:30 0.50 KILL P DECOMP RIG LUBRICATOR & PULL BPV. 00:30 - 02:30 2.00 KILL !P DECOMP RIG LINES TO TREE & TIGER TANK & TEST TO 3500 & TAKE ON SEA WATER. 02:30 - 05:30 3.00 KILL P DECOMP CIRCULATE INFLUX FROM WELL BORE & MONITOR WELL. 05:30 - 06:00 0.50 KILL ~ DECOMP SET TWC.& TEST. 06:00 - 07:00 1.00 WHSUR ~ DECOMP NIPPLE DN TREE. 07:00- 09:00 2.00 BOPSUF P DECOMP NIPPLE UP BOP 09:00 - 10:00 1.00 BOPSUF P DECOMP TEST BOP TO 3500 PSI. (BODY TEST ONLY) TEST WAIVED BY JOHN CRISP WITH AOGC.) 10:00 - 11:00 1.00 BOPSUF ~ DECOMP RIG LUBRICATOR & PULL 'rwc. 11:00 - 12:00 1.00 PULL ~ DECOMP MAKE UP LANDING JT. & PULL HANGER TO FLOOR & TEST HEAT TRACE (OK) AND ESP CABLE. & LAY DN HANGER. 12:00 - 13:00 1.00 PULL ~ DECOMP RIG BAKER & RAYCHEM SPOOLING EQUIPMENT. 13:00 - 20:00 7.00 PULL ~ DECOMP TOH WITH ESP ASSY. REMOVING HEAT TRACE & BAKER SENSOR WIRE. 20:00 - 22:00 2.00 PULL P DECOMP LAY DN ESP ASSY. 22:00 - 23:00 1.00 PULL P DECOMP RIG DN PULLING EQUIPMENT FOR HEAT TRACE & BAKER SENSOR WIRE. 23:00 - 00:00 1.00 RUNCO~ P COMP MAKE UP ESP ASSY. 4/2/2002 00:00 - 01:00 1.00 RUNCO~~P COMP MAKE UP ESP ASSY. 01:00 - 03:30 2.50 RUNCO~ COMP RIH WITH ESP ASSY TO 2265' 03:30 - 04:30 1.00 RUNCO~P COMP RIG UP EQUIMENT TO RUN HEAT TRACE. 04:30 - 14:30 10.00 RUNCOI~ COMP RIH WITH ESP ASSY. INSTALLING HEAT TRACE. TO 5775' 14:30 - 18:00 3.50 RUNCOI~ COMP MAKE UP HANGER & MAKE CONNECTION FOR ESP CABLE & HEAT TRACE & TEST & LAND HANGER. 18:00 - 18:30 0.50 RUNCOI~ COMP SET TWC & TEST TO 2500 PSI. 18:30 - 20:00 1.50 BOPSUF.P COMP NIPPLE DN BOP 20:00 - 21:00 1.00 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. 21:00 - 22:00 1.00 WHSUR P COMP RIG LUB & PULL TWC & SET BPV. & SECURE TREE AREA. Printed: 4~8~2002 8:35:56AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~:-~.~ ~ ~.-..~\¥-~ Commissioner - ..~,.~ ~om. Maunder, i. Supe~isor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: April 22, 2001 Safety valve Tests Milne Point Unit J &~i Pads Sunday April 22, 20.01.' I traveled to BPXs MPU J & ! Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work w~th. I also inspected the well houses on these pads during the SVS testing. All the wellhouses were very clean and the equipment appeared to be in excellent condition. Summary: I witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 11 wells 22 components 0 failures MPU I Pad 6 wells 12 components Ofailures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: ~ Chuck SCheve Date: Field/Unit/Pad: Milne Point / MPU / I Pad Separator psi: LPS 140 HPS 4/22/01 Well Permit Separ Set L/P Test Test Test Date oil, WAG, GIN J, Number Number PSI ,. PSI i, T,ri'p Code Code Code Passed GAS or CYCLE 1-01 190'6~i~0 ........... I'02 1900910 140 100 95 P 'i) ..... OiL! 1-05 1900920 140' 100 95 P P ..... OILi 1-04 1900930 140 100 95 P P OIL 1-06 1971950 140 100 95 P e OIL f-07 '1'9515i0 ' 140 100 9~" e ' 'i~ " 'OiL 1-08 ' ' 1971~920 " '140 100 95 P P " ~¥L Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% I:]o0 Day Remarks: RJF 1/16/01 Page 1 ofl SVS MPUI Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Pep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Milne Point / MPU / J Pad Separator psi: LPS 140 HPS 4/22/01 "Well .... Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE J-01A 1991110 1~0 ' 10'0 95 "e e ..... OIL J'03 1900970 140 100 95 P e " 0ii~ ~-04 ' 1900980 140 100 95 e P .... OiL J-05 1910950 140 100 ' 95: 'e P ..... oi'L '~-06 i940950 140 100 125i P P .......... OIL '~'_07 I ..................... 1910970 140 100 951 P P OIL J-08A 1991170 140 100 95 P' ' P ' " OIL ~'09A 1991140 "'i40 " ' 100 1101 .... e ' e ..... OILi J-10 1941100 140 100 95! P .... p , , OIL j.l'l ' 1941'140 .... J-12 1941180 J-18 1972200 J-19A 1951700 j-20' ' 19'72150 ...... : '~-21 1972000 1'40 ..... 100 " 95i P P ' ' ' 0IL j-22 1981240 " 140 ' 100 '9~ P 'P .... o~L J-23 2001200 , Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% F1 ~o var Remarks: RJF 1/16/01 Page 1 ofl SVS MPU JPad 4-22-01 CS Well complianCe RepOrt File on Left side of folder _ _ 197-200-0 MD 06260 Microfilm Roll MILtN~OINT UNIT SB J-21 50- 029-22825-00 BP~, ~,T~-EXPLOR~TION (A~ASK TVD _04237__ C~mpletion Date: 8/11/98 Completed Status: 1-OIL Current: / - Roll 2 / -- Name Interval L DEPTH REF Fllq"AL 5390-6158 L DGR/EWR4-MD ,2/ 2562-6265 i[/IO/~ OH L DGR/EWR4-TVD ~ 2346-4241 ~" OH L PERF /.~4N'AL 6128-6159 8/6/98 CH 5 L PERF t..--'F~4AL 5773-5920 8/7/98 CH 5 R MWD SRVY ~.$fI~ERRY 0-6260 OH T 8685 (_J/ SCHLUM PDC/GR CH Daily Well Ops /)//5-/~ 7? .q/T Jif? Are Dry Ditch Samples Required? yes Was the well cored? yes no Analysis Description Received? yes no Sent Received T/C/D ~/(~/~ ~ CH ~- ..... 8/20/98 ---8/24/98 ............ no 10/28/98 10/28/98 10/28/98 10/28/98 8/20/98 8/24/98 8/20/98 8/24/98 10/22/98 10/27/98 10/12/98 10/15/98 And Received? yes no Sample Set it _ r. Tuesday, August 01, 2000 Page 1 of 1 STATE OF ALASKA ECE V'Ed ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status ofWell Classification,o.r.~5.e. rvfc. e~ .V~.C.~,..~n~Ai~dih~b,~,,,,,.,,- [~Oil E~ Gas I~ Suspended [--] Abandoned I~Service ~., , ~. 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-200 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22825 4. Location of well at surface i ~"'~ 9. Unit or Lease Name 2179' NSL, 3276' WEL, SEC. 28, T13N, R10E, UM i ii".,;?:::. ',' ',~ii~"i~~! Milne Point Unit · ~'.~.'./~/;~.¢'~. ? t~, i 10. Well Number At top of productive interval i .. ~l~~ [ MPJ-21 1447' NSL, 1500' WEL, SEC. 29, T13N, R10E, UM i .... At total depth ,~.~_-__~__-. ...... 11. Field and Pool 1407' NSL, 1677' WEL, SEC. 29, T13N, R10E, UM -' ' ..... Milne Point Unit /Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 64.12'I ADL 025517 12. Date Spudded11/6/97 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 116' NO' °f COmpletiOns11/10/97 8/11/98 N/A MSL, One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set i21 · Thickness of Permafrost 6260 4237 FT 6155 4146 FTI [~Yes I--]No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 SX Arcticset I (Approx.) 7" 26# L-80 30' 6242' 9-7/8" 1471 sx PF 'E', 258 sx Class 'G' !24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 5790' MD TVD MD TVD 5918'-5938' 3943'-3960' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5986'-6006' 4001 '-4018' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 75 bbls diesel Proplok Frac, 5986'-6006' 100620# 12/20 Ottawa Sand behind pipe Proplok Frac, 5918'-5938' 120500# 12/20 Ottawa Sand behind pipe 27. PRODUCTION TEST ~ ~ ! ~ ! ~ I ~ I Date First Production I Method of Operation (Flowing, gas lift, etc.) U I% I ~I 5 L September 20, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL :GAs-MCF WATER-DEL OIL GRAWTY-API (CORR) :ress. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate -.. 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSBD 5906' 3932' TSBC 5946' 3967' TSBB 5981' 3997' 31. List of Attachments Summary of Daily Drilling Reports, Surveys ~t~~eg u~'"",~c best of my 32. I hereby certify t oing is tr orrect tot1~ knowledge S, n d T. itle Drilling Engineering Supervisor Date - 97-200 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS G£NERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. I'rEl~ 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. [rEM §: 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. ITEI~I 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEI~I 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'. ORIGINAL Form 10-407 Rev. 07-01-80 Facility Date/Time 05 Nov 97 06 Nov 97 07 Nov 97 08 Nov 97 09 Nov 97 10 Nov 97 11 Nov 97 M Pt J Pad Progress Report Well MPJ-21 Rig Nabors'~,~ Page Date 01:00-02:00 Duration Activity 1 hr Rig moved 10.00 % 02:00-04:30 04:30-06:00 06:00-13:00 13:00-16:00 16:00-22:00 22:00-04:00 04:00-06:00 06:00-09:00 09:00-16:00 16:00-19:00 19:00-19:30 19:30-20:00 20:00-21:00 21:00-22:00 22:00-23:30 23:30-01:30 01:30-02:00 02:00-04:30 04:30-05:00 05:00-06:00 06:00-22:00 22:00-23:30 23:30-01:30 01:30-03:00 03:00-04:00 04:00-06:00 06:00-13:00 13:00-14:30 14:30-17:30 17:30-18:00 18:00-22:00 22:00-06:00 06:00-07:30 07:30-08:30 08:30-11:30 11:30-12:30 12:30-14:00 14:00-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-07:00 07:00-11:00 11:00-13:00 13:00-14:30 14:30-15:00 15:00-20:00 20:00-23:30 23:30-00:00 00:00-02:00 02:00-05:30 05:30-06:00 06:00-07:30 2-1/2 hr 1-1/2 hr 7hr 3 hr 6hr 6 hr 2 hr 3 hr 7 hr 3 hr 1/2 hr 1/2 hr 1 hr lhr 1-1/2 hr 2 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr 16hr 1-1/2 hr 2 hr 1-1/2 hr 1 hr 2 hr 7 hr 1-1/2 hr 3hr 1/2 hr 4hr 8 hr 1-1/2 hr 1 hr 3hr 1 hr 1-1/2 hr 12hr 1-1/2 hr 1-1/2 hr lhr 1 hr 4 hr 2 hr 1-1/2 hr 1/2 hr 5 hr 3-1/2 hr 1/2 hr 2 hr 3-1/2 hr 1/2 hr 1-1/2 hr Rig moved 50.00 % Rig moved 75.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Rigged up Divertor R.I.H. to 0.0 ft R.I.H. to 0.0 ft Held safety meeting Tested Divertor Serviced Block line Serviced Top drive Made up BHA no. 1 Drilled to 207.0 ft Pumped out of hole to 112.0 ft Made up BHA no. 1 Drilled to 280.0 ft Circulated at 280.0 ft Drilled to 2564.0 ft Circulated at 2564.0 ft Pulled out of hole to 0.0 ft Downloaded MWD tool Serviced Top drive R.I.H. to 2564.0 ft Drilled to 3868.0 ft Circulated at 3868.0 ft Pulled out of hole to 1750.0 ft Serviced Top drive R.I.H. to 3868.0 ft Drilled to 4990.0 ft Drilled to 5180.0 ft Circulated at 5180.0 ft Pulled out of hole to 920.0 ft Serviced Top drive R.I.H. to 5180.0 ft Drilled to 6260.0 ft Circulated at 6260.0 ft Pulled out of hole to 4835.0 ft Circulated at 6260.0 ft Circulated at 6260.0 ft Pulled out of hole to 920.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 6241.0 ft (7in OD) Circulated at 6241.0 ft Held safety meeting Mixed and pumped slurry - 295.500 bbl Circulated at 2112.0 ft Mixed and pumped slurry - 0.000 bbl Mixed and pumped slurry - 367.000 bbl 1 20 October 98 Facility Date/Time Progress Report M Pt J Pad Well MPJ-21 Rig Nabors ~$z).-'&~ Page Date 07:30-08:00 08:00-08:30 08:30-10:00 10:00-16:00 16:00-19:00 Duration 1/2 hr 1/2 hr 1-1/2 hr 6 hr 3 hr Activity Cleared Flowline Rigged down Casing handling equipment Rigged down Divertor Installed Xmas tree Cleared Sand traps 2 20 October 98 Facility Date/Time 03 Aug 98 04 Aug 98 05 Aug 98 06 Aug 98 07 Aug 98 M Pt J Pad Progress Report Well MPJ-21 Rig Nabors ;~ Lfi&-,~ Page Date Duration Activity 22:00-22:15 22:15-23:30 23:30-02:30 02:30-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:15 06:15-06:30 06:30-09:30 09:30-11:30 11:30-11:45 11:45-12:15 12:15-12:30 12:30-13:30 13:30-16:00 16:00-16:30 16:30-21:00 21:00-21:30 21:30-22:00 22:00-23:00 23:00-23:30 23:30-00:00 00:00-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:00-09:00 09:00-10:00 10:00-12:00 12:00-15:00 15:00-15:30 15:30-18:00 18:00-20:30 20:30-21:00 21:00-22:00 22:00-00:00 00:00-00:30 00:30-02:30 02:30-04:30 04:30-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-13:00 13:00-15:30 15:30-17:00 17:00-18:30 18:30-19:30 19:30-21:30 21:30-06:00 06:00-07:00 07:00-08:00 08:00-11:00 1/4 hr 1-i/4 hr 3hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1/4 hr 1/4 hr 3 hr 2 hr 1/4 hr 1/2 hr 1/4 hr 1 hr 2-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr lhr 1 hr 2-1/2 hr 1-1/2 hr 3 hr 1 hr 2 hr 3hr 1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1 hr 2 hr 1/2 hr 2 hr 2 hr 1/2 hr 1 hr 2 hr 1 hr 4 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 2 hr 8-1/2 hr 1 hr lhr 3 hr Held safety meeting Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Retrieved Hanger plug Installed Hanger plug Removed Xmas tree Removed Xmas tree (cont...) Held safety meeting Installed BOP stack Tested All functions Retrieved Hanger plug Retrieved Tubing hanger Installed Wear bushing Made up BHA no. 1 Singled in drill pipe to 2112.0 ft Circulated at 2112.0 ft Drilled installed equipment - Cement retainer Circulated at 2115.0 ft Tested Casing - Via string Pulled out of hole to 198.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 2125.0 ft Singled in drill pipe to 2955.0 ft Washed to 3171.0 ft Singled in drill pipe to 4009.0 ft Singled in drill pipe to 6155.0 ft Tested Casing - Via string Reverse circulated at 6155.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 3 R.I.H. to 6155.0 ft Reverse circulated at 6155.0 ft Laid down 150.0 ft of 3-1/2in OD drill pipe Serviced Block line Pulled out of hole to 0.0 ft Held safety meeting Worked on BOP - Lubricator Conducted electric cable operations Held safety meeting Perforated Perforated from 5986.0 ft to 6006.0 ft Worked on BOP - Lubricator Ran Tubing to 5713.0 ft (3-1/2in OD) Rigged up High pressure lines Injectivity test - 75.000 bbl injected at 1913.0 psi FRAC job - 150.000 bbl injected at 3181.0 psi Injectivity test - 23.000 bbl injected at 2348.0 psi FRAC job - 644.000 bbl injected at 3525.0 psi Monitor wellbore pressures Monitor wellbore pressures Reverse circulated at 5713.0 ft Ran Tubing to 5950.0 ft (3-1/2in OD) 1 20 October 98 Facility Date/Time 08 Aug 98 09 Aug 98 10 Aug 98 11 Aug 98 M Pt J Pad Progress Report Well MPJ-21 Page Rig Nabors ~$~/~-~ Date Duration Activity 11:00-15:00 15:00-16:30 16:30-19:30 19:30-22:30 22:30-00:30 00:30-03:30 03:30-06:00 06:00-17:00 17:00-18:00 18:00-23:00 23:00-23:30 23:30-01:30 01:30-02:30 02:30-06:00 06:00-10:30 10:30-12:00 12:00-13:00 13:00-21:30 21:30-06:00 06:00-01:00 01:00-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-12:30 12:30-15:00 4hr 1-1/2 hr 3 hr 3 hr 2 hr 3 hr 2-1/2 hr llhr 1 hr 5hr 1/2 hr 2 hr 1 hr 3-1/2 hr 4-1/2 hr 1-1/2 hr 1 hr 8-1/2 hr 8-1/2 hr 19hr 3-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1 hr 1/2 hr 2-1/2 hr Pulled Tubing in stands to 0.0 ft Worked on BOP - Lubricator Perforated from 5918.0 ft to 5938.0 ft Ran Tubing in stands to 5618.0 ft Rigged up High pressure lines Injectivity test - 400.000 bbl injected at 3500.0 psi FRAC job - 1141.000 bbl injected at 3300.0 psi Monitor wellbore pressures Reverse circulated at 5618.0 ft Laid down 5618.0 ft of Tubing Made up BHA no. 4 R.I.H. to 5838.0 ft Reverse circulated at 5838.0 ft Reverse circulated at 5950.0 ft Reverse circulated at 6155.0 ft Cleared Sand traps Reverse circulated at 6155.0 ft Laid down 6155.0 ft of 3-1/2in OD drill pipe Rigged up sub-surface equipment - ESP Ran Tubing to 5555.0 ft (2-7/8in OD) Installed Tubing hanger Rigged down BOP stack Held safety meeting Rigged down BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 75.000 bbl of Diesel 2 20 October 98 Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Bixby/March H. Thackeray MPJ-21 DRLG Eline Perf 8-6-98 Date: 18-7-98 Objective: Run Eline marked line GR/CCL correlation log for primary depth control and perforate the Schrader Bluff "OB". Sequence of Events: RU Atlas. RIH with GR/CCL with rollers on marked line. No problem rolling thru 79 degree hole Tag PBTD @ 6159' and log up to above marker joints to 5390'. (collars don't show up very well due to standoff from 5 %" wheels and 1 11/16" tools - good correlation with MWD gamma ray) Correlation is 4' deep to MWD log. This GR/CCL log on marked line to serve as primary depth control. POOH Pre-Perf Safety meeting with rig crew. MU 20' of 4 %" gun. P/T lub to 500 psi. RIH with perf gun on rollers - no problems Make depth correlation pass. Log into position Perforated OB based on GR/CCL log from 5986' - 6006' with 4 ½" gun 4 spf Big Hole charges @ 0-180 phasing. POOH. All shots fired. RD Atlas. Results: Ran GR/CCL log from PBTD @ 6159' to 5390'. Perforated the Schrader Bluff OB sand from 5986 - 6006' (20') with 4 %" gun with 4 spf Big Hole charges at 0-180 degree phasing. Tie in log/date Atlas GR/CCL 8~6/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 5986 6006 4 ~ none 0-180 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Ricardo Solares FROM: J, Fox DATE: 08/06/98 RE: J-21 'OB' DATA FRAC AND PROPLOK FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak JOB SUMMARY 100.6 M# of 12-20 Ottawa sand coated with 318 gal. of PropLok resin / 100 # of proppant was placed behind casing at a rate of 20 bpm. 6% over design was pumped before going to flush. There was little or no net pressure build during the frac. The rate was slowed from 20 bpm to 14 bpm over the last 1.5 minutes of pumping in attempt to induce a screen out with no effect. The slurry was under displaced with gel by 4.8 bbl. (approx. half of the vol. between the tubing tail and top perforation). The pad size was 23.9 of which the first 20 bbls. was circulated down the tubing at 3 1/2 bpm before shutting in the choke and starting slurry. As with the past several fracs a 0.5 ppg stage has been added. Stages progressed up from there in 1ppg increments to a maximum of 10 ppa. The pre-frac data collection consisted of an: injectivity test, data frac, and step rate test similar to the last well fracced. The injectivity test consisted of 75 bbls. of seawater pumped at 10 bpm, shutdown (i.e. no need for displacement), and monitor falloff pressures for 1 hr. The data frac consisted of 150 bbl. of 75 ppt HEC gel flushed with seawater by and overdisplaced by 5 bbl, all at 20 bpm. Again a 1 hr. pressure falloff was monitored. Seawater was used for the step rate test at rates of 0.5, 0.75, 1, 1.5, 2, 3, 5, 7, 10, and 15 bpm. A final 1 hr. pressure falloff survey was monitored. HEC gel quality on location was good, Tank no. 1 ran at a Fann 300 reading of 161 @ 101 deg. F (calculated gel loading of 80ppt) and a pH of 6 while Tank no. 2 ran at a fan 300 reading of 148 @ 90 deg. F (calculated gel loading of 75 ppt) and pH of 6. The three Fann 300 readings measured in the lab when the gel was mixed in Deadhorse (by MI Drlg. Fluids) were 150 @ 103 deg., 158 @ 103 deg., and 160 @ 106 deg. The maiden voyage of the new Frac Cat data acquisition system went well. A few minor glitches the most noticeable is the time of day ( 3 hours ahead - still on Houston time) and a 4 bbl. false start on the injectivity test. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 10 75.5 10.3 1167 912 (IA) 255 0.69 seawater 10/16/98 DATA FRAC & FRAC 4:07 PM SENT VIA MICROSOFT MAIL TIME'. RATE J ANNP~ WHP STAGE ~ CUM i BPM I PSIG ~ PSlG: BBL i BBL ~ DATA FRAC PUM,~_~_,IG SUMMARY COMMENTS Bbls Bbls HEC Time gel on Final STP, ISIP, psi NWB Treat grad, Pumped gel to Perfs perfs psi friction, psi psilft 217.5 150 7.5 1181 930 (IA) 251 0.695 FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner rubber left Job was M# M# pipe, M# M# Sand, M# in hole? /size /size Flush 103,120 100.6 96.4 2500 not appl. 12/20 Ottawa not appl. DATE/TIME ~ OPERATIONS SUMMARY 06106198 ~ 1430 ~ Pre-job Safety meeting 1525 i Pressure test to 7500 psi. 1535 ~ Start injectivity test 1825 False start - rates and volumes not recording. Pump approx. 4 bbl. 1842 S/D pumps and start monitor PFO 1944 Start injectivity test. 1955.5 S/D pumps and start monitor PFO 2056.5 Start step rate test. 2116 S/D pumps and start monitoring PFO. 2317 Start circulating in pad at 3.5 bpm. 2321 Close in choke, start mixing sand, and bullheading. 2343 100 ppg stage reaching perfs. 2350 Call flush 2352 Start slowing rate down in an attempt to induce screenout 2353 S/D pumps and monitor pressure falloff for 15 min. TIME'RATE BPM PUMPING SUMMARY ~ ANNPi WHP , STAGE CUM ! PSlG ' PSlG BBL BBL COMMENTS 08/06/98 INJECTIVITY TEST DISPLACEMENT = 60.4 BBLS 1534 ~ 0 / 10 636 659 0 0 Prepare to start pumping injectivity, 1535 ~ 10 1348 2257 4.8 4.8 At rate 1537 9.9 1276 2969 27.1 27.1 1539 9.9 1249 2019 42.2 42.2 1541 10.2 1242 2019 64.7 64.7 1542 10/0 1167 1913 75.5 75.5 S/D pumps and monitor pressure falloff. ISIP = 912 psig. 1543 0 872 975 75.5 1545 0 850 943 1550 0 810 906 1555 0 777 870 1600 0 742 833 1610 0 608 700 1620 0 410 499 1630 0 268 352 1640 0 183 265 DATA FRAC . TIME RATE BPM ,. ANNP PSIG PUMPING SUMMARY WHP ~ STAGE PSIGi BBL 1643.5 0/20 0 64 0 1645 20 1280 3341 18 1647 19.7 1176 3088 60 1649 20.0 1229 3181 93 1650 20.0 1234 3181 112 1652 20.1 1196 3171 150 1654 20.0 1190 3084 190 CUM COMMENTS BBI 75.5 Prepare to start data frac. 93 At rate. 135 Gel on perfs. 168 187 226 Go to flush 265 293.1 293.1 1655 20 / 0 1181 3144 218 S/D pumps and monitor pressure falloff. 1656 0 918 1021 1658 i 0 881 975 :1700 0 853 947 1705 ', 0 813 906 1710 ': 0 769 870 1720 0 694 787 1730 0 632 723 1740 0 555 645 1750 0 493 581 STEP RATE 2056 0 / 0.5 438 ~ 522 0 ~ 293.1 Prepare to start step rate test 2058 0.5 853 ' 925 i 1 294 Final press, before increasing rate to next step. 2100 0.75 857 970 2.5 295 Final press, before ~ncreas~ng rate to next step. 2102 1.0 936 : 1044 5 298 Final press, before increasing rate to next step. 2104 1.5 960 ' 1098" 8 301 Final press, before ~ncreas~ng rate to next step. 2106 2.0 962 ' 1103 12 305 Final press, before ~ncreas~ng rate to next step. 2108 3.0 969 ~ 1172 i 18 311 Final press, before ~ncreasmg rate to next step. 2110 5.0 1005 1336 ~ 27 320 Final press, before ~ncreas~ng rate to next step. 2112 6.9 1048 1520 13 333 Final press, before ~ncreas~ng rate to next step. 2114 10.1 1093 1858 20 353 Final press, before ~ncreas~ng rate to next step. 2116 15.0 / 0 1139 2504 31 382.0 Final press, before S/D pumps to monitor PFO. 2118 0 863 957 0 382.0 2120 0 811 906 2125 0 727 819 2130 0 669 760 2140 0 564 654 2150 0 489 577 2200 0 425 513 2210 0 368 458 2220 0 326 412 FRAC TIME~ RATE ~ BPM PUMPING SUMMARY ANNP~ WHP STAGE i CUM ' PSIG' PSIG ' BBL ~ BBL COMMENTS 2316.5 0 / 3.5 82 8 0 ~ 382.0 Open choke to start circulating first 20 bbl. of gel. 2319 3.6 119 367 10 392 2321 3.2 / 20 577 746 18 400 Close choke, start sand, and come up on rate. 2322 20 1178 3136 20 412 @ rate 2323 20.2 1146 2962 48 430 2324 20.0 1146 2948 60 442 Pad reaching perfs. 2325.5 19.9 1220 3057 83 465 0.5 ppg reaching perfs. 2329.5 20.2 1176 3012 169 551 1 ppg reaching perfs. 2332.5 20.0 1146 2934 235 617 2 ppg reaching perfs. Pod temp. = 87 deg. 2334.5 19.9 1141 3049 271 653 3 ppg reaching perfs. 2335.5 20.0 1137 3094 296 678 4 ppg reaching perfs. 2337 19.9 1145 3200 321 703 5 ppg reaching perfs. 2338 20.0 1156 3304 343 725 6 ppg reaching perfs. 2339.5 19.9 1161 3368 368 750 7 ppg reaching perfs. 2340.5 20.0 1172 3419 392 774 8 ppg reaching perfs. Pod temp. = 84 deg. 2341.5 20.0 1179 3496 417 799 9 ppg reaching perfs. 2343.3 20.1 1204 3547 447 829 10 ppg reaching perfs. 2345.3 20.1 1205 3515 493 875 2347 20.1 1203 3515 518 900 Pod temp. = 83 deg. 2349 20.2 1203 3520 566 948 At design 2350 20.4 1201 3525 590 972 Call flush. 2352 20.0 1200 3213 627 1009 Begin to slow rate. 2353 13.7 1124 2344 641 1023 2353.5 0 998 1080 644 1026.5 S/D pumps and monitor pressure 2355 0 973 1057 Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 382 Bbls FRAC: 644 Bbls '1026 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WINDOW DF/FRAC SEA H20 ; pH ; 7 GEL QUALITY CONTROL CHECK SEA H20 75# GEL ~ 75# GEL TEMP ~r pH ~ VISCOSITY 73 6 148 @ 90 deg. PIPE TIME n/a XL TIME n/a XL pH n/a FLUID ADDITIVES Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Bixby/March H. Thackeray MPJ-21 DRLG Eline Perf 8-7-98 Date: 18-8-98 Objective: Eline perforate the Schrader Bluff "OA". Sequence of Events: RU Atlas. MU 20' of 4 %" gun wi GR/CCL on rollers Pre Job Safety meeting with rig crew. P/T lub to 500 psi. RIH with perf gun on rollers - no problems Make depth correlation pass. Correlate to Atlas marked line GR/CCL Log 8/6/98 (4' deep to MWD log) Log into position Perforated OA based on GR/CCL log from 5918'- 5938' with 4 %" gun 4 spf Big Hole charges @ 0-180 phasing. POOH. All shots fired. RD Atlas. Results: Perforated the Schrader Bluff OA sand from 5918 - 5938' (20') with 4 %" gun with 4 spf Big Hole charges at 0-180 degree phasing. Tie in log/date Atlas GR/CCL 8/6~98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter 5918 5938 4 ~ Shot Density Orientation Phasing 4 none 0-180 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: Ricardo Solares FROM: J, Fox DATE: 08108198 RE: J-21 'OA' DATA FRAC AND PROPLOK FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak JOB SUMMARY 120.5 M# of 12-20 Ottawa sand coated with 3/8 gal. of PropLok resin / 100 # of proppant was placed behind casing at a rate of 20 bpm. 32% over design was pumped before going to flush. There was little or no net pressure build during the frac. The rate was slowed from 20 bpm to 14 bpm over the last 1.5 minutes of pumping in attempt to induce a screen out with no effect. The slurry was under displaced with gel by 5.2 bbl. (approx. half of the vol. between the tubing tail and top perforation). The pad size was 24.3 bbl all of which was bullheaded (i.e. no fluid was circulated in). As with the past several fracs a 0.5 ppg stage has been added. Stages progressed up from there in 1 ppg increments to a maximum of 8 ppa. The pre-frac data collection consisted of an: injectivity test, data frac, and step rate test similar to the last well fracced. The injectivity test consisted of 75 bbls. of seawater pumped at 10 bpm, shutdown (i.e. no need for displacement), and monitor falloff pressures for I hr. The data frac consisted of 150 bbl. of 75 ppt HEC gel flushed with seawater by and overdisplaced by 5 bbl, all at 20 bpm. Again a 1 hr. pressure falloff was monitored. Seawater was used for the step rate test at rates of 0.5, 0.75, 1, 1.5, 2, 3, 5, 7, 10, and 15 bpm. A final 1 hr. pressure falloff survey was monitored. HEC gel quality on location was good. The two Fann 300 readings measured in the lab when the gel was mixed in Deadhorse (by MI Drlg. Fluids) were 151 @ 93 deg., and 157 @ 94 deg. Both of these are representative of what a 75 ppt HEC viscosity should be. pHs were 6.74 and 6.01 respectively. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 10 75.3 10.2 1426 967 (IA) 460 0.708 seawater DATA FRAC 10/16/98 4:08 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL TIME = RATE ~ANNPI WHP !STAGE' CUM : i BPM i PSIG ! PSIG ', BBL BBL ~ PU M,~..,~iG SUMMARY COMMENTS Bbls Bbls HEC Time gel on Final STP, ISIP, psi NWB Treat grad, Pumped gel to Perfs perfs psi friction, psi psi/ft 216.2 150 7.5 1406 1111 (IA) 295 0.745 FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner rubber left Job was M# M# pipe, M# M# Sand, M# in hole? /size /size Flush 121.8 120.5 91.0 1.$ not appl. 12/20 Ottawa not appl. DATE/TIME OPERATIONS SUMMARY 08107/98 2340 Pre-job Safety meeting 08~08~98 0022 Pressure test to 7500 psi. 0025 Start 75 bbl. water injectivity test 0033 S/D pumps and start monitor PFO 0141.5 Start data frac. 0152 S/D pumps and start monitor PFO 0310 Start step rate test, 0329.7 S/D pumps and start monitoring PFO, 0513 Start frac stimulation. 0548 Call flush 0551 Start slowing rate down in an attempt to induce screenout 0552 S/D pumps and monitor pressure falloff for 15 min. TIME ~ RATE ANNP ' BPM 'PSIG PUMPING SUMMARY WHP STAGE , CUM PSIG BBL BBL COMMENTS 08/08/98 INJECTIVITY TEST DISPLACEMENT = 60.2 BBLS 0025 , 0 / 10 0 0 0 0 Prepare to start pumping injectivity, 0025.7 ~ 10 1318 2275 5.8 5.8 At rate 0027.5 i 10 1351 2220 26 26 0031 10.0 1419 2275 59 59 0032 10 / 0 1426 I 2280 75.3 75.3 S/D pumps and monitor pressure falloff. ISIP - '. 967 psig. 0033 0 988 : 993 75.3 0035 0 657751 0040 0 278 362 0045 0 163 243 0050 0 117 192 0100 0 67 146~ 0110 0 43 124 0120 0 29 1051 0130 0 18 96 0139 0 / 20 0 73 0.3 75.3 Prepare to start data frac. 0142 20 1358 3754 16 91 At rate. 0143 20.2 1373 3186 58 125 0144 20.1 1371 3127 60 135 Gel on perfs. 0146 20.2 1404 3218 100 175 0149 20.1 1402 3255 150 225 Go to flush TIME~ RATE I BPM PUMPING SUMMARY ANNP "'~VHP ~ STAGE ' CUM i PSIG ~ PSIG i BBL BB[ COMMENTS 0150 ', 20.0 1395 3241 180 255 01512 i 19.8 / 0 1406 3580 215 291.5 S/D pumps and monitor pressure falloff. ISlP = ~ 1111 psig 0154 0 977 1071 0157 0 930 1021 0200 0 895 989 O2O5 0 853 943 0210 0 816 902 0220 0 763 851 O23O 0 699 787 O24O 0 615 700 0250 0 518 600 0300 0 432 517 STEP RATE 0310 0 / 0.5 349 485 0 291.5 Prepare to start step rate test 0312 0.5 975 1055 2.2 292.6 Final press, before ~ncreas~ng rate to next step. 0314 0.75 1113 1227 3.4 Final press, before increasing rate to next step. 0316 1.0 1175 1295 5.6 Final press, before ~ncreas~ng rate to next step. 0318 1.5 1206 1332 8.6 Final press, before ~ncreas~ng rate to next step. 0320 2.0 1201 1332 13.0 Final press, before ~ncreas~ng rate to next step. 0322 3.0 1193 1382 20.5 Final press, before ~ncreas~ng rate to next step. 0324 5.0 1243 1575 28.6 Final press, before increasing rate to next step. 0326 7.1 1272 1776 42 Final press, before ~ncreas~ng rate to next step. 0328 10.1 1248 2156 61 Final press, before ~ncreas~ng rate to next step. 0330 15.0 / 0 1325 2943 90.4 381.1 Final press, before S/D pumps to monitor PFO. 0335 0 840 934 0340 0 651 737 0350 0 362 444 0400 0 245 325 0410 0 192 270 0420 0 161 238 0430 0 139 220 0440 0 120 197 FRAC :0511 0 78 160 0.8 381.1 Prepare to start 0513 0 / 20 155 687 4.2 0514 20 1257 3658 19.9 401 @ rate 0515.3 20.4 1245 3072 416 Slurry reaching 0.5 ppg 0517.7 19.9 1320 3104 465 Pad reaching perfs. PUMPING SUMMARY TIME , RATE r ANNP i'~WHp~ STAGE ~ CUM COMMENTS BPM PSIG r PSIG 'BBL I BBL 0519.3 20.3 ' 1316 3100 500 ~ Pod temp. : 85 deg. 0520.7 20.1 ; 1301 3075 518 0.5 ppg reaching perfs. 0521.3 20.3 1279 3050 535 I ppg reaching perfs. 0525 19.8 1236 2980 608 2 ppg reaching perfs. Pod temp. = 87 deg. 0525.6 19.9 1234 3050 ~ 622 3 ppg reaching perfs. 0527 20.1 1234 3100 650 4 ppg reaching perfs. 0528.5 20.1 1230 3163 685 5 ppg reaching perfs. 0531.5 19.9 1228 3246 740 6 ppg reaching perfs. Pod temp. = 83 deg 0534 19.8 1223 3305 794 7 ppg reaching perfs. 0536 20.2 1230 3351 829 0537 20.2 1230 3328 845 8 ppg reaching perfs.. 0538.5 20.2 1230 3346 885 0540.5 20.2 1230 3342 925 Pod temp. = 82 deg 0542.3 20.0 1230 3351 965 At design proppant volume. 0544.5 20.1 1234 3346 1005 0546.7 20.0 1236 3305 1045 0548 20.1 1236 3374 1066 Cut sand 0549.4 20.0 1236 3406 1086 Call flush. 0550 20.4 1237 3360 1107 Swt. from gel sweep to seawater 0551.2 14.9 1206 2509 1136 Begin to slow rate in an attempt to induce screen out. 0552 13 / 0 1131 1241 1141 S/D pumps and monitor pressure 0553 0 1116 1199 0555 0 1091 1181 0600 0 1052 1140 Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 292 Bbls FRAC: 760 Bbls '1'141 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME PETREDAT WINDOW NONE FLUID ADDITIVES 2% KCI makeup water for gel 75 ppt J-512 HEC gelling agent Halliburton surfactant was used throughout the actual fracture treatment. Dowell F-75 was used during the data frac. Facility M Pt J Pad Date/Time Progress Report Well MPJ-21 Rig (null) Duration Activity 24 Aug 98 08:01-18:01 18:01-18:31 18:31-19:31 19:31-20:46 20:46-01:01 25 Aug 98 01:01-05:01 05:01-06:00 06:00-07:30 10hr 1/2 hr 1 hr 1-1/4 hr 4-1/4 hr 4 hr 3/4 hr 1-1/2 hr Rig moved 100.00 % Held safety meeting Rigged up Drillfloor / Derrick Removed Xmas tree Installed BOP stack Repaired Other sub-surface equipment Removed BOP stack Installed Xmas tree Page Date 1 20 October 98 Facility Date/Time 04 Sep 98 05 Sep 98 06 Sep 98 07 Sep 98 Progress Report M Pt J Pad Well MPJ-21 Page 1 Rig Nabors 5S Date 20 October 98 06:00-06:30 06:30-20:30 20:30-22:00 22:00-00:30 00:30-01:00 01:00-02:00 02:00-06:00 06:00-06:30 06:30-09:00 09:00-11:30 11:30-17:00 17:00-19:00 19:00-20:00 20:00-21:00 21:00-23:30 23:30-00:30 00:30-01:30 01:30-06:00 06:00-06:30 06:30-11:00 11:00-15:30 15:30-17:00 17:00-18:00 18:00-18:15 18:15-20:00 20:00-02:00 02:00-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-06:00 Duration 1/2 hr 14hr 1-1/2 hr 2-1/2 hr 1/2 hr 1 hr 4 hr 1/2 hr 2-1/2 hr 2-1/2 hr 5-1/2 hr 2 hr 1 hr 1 hr 2-1/2 hr 1 hr 1 hr 4-1/2 hr 1/2 hr 4-1/2 hr 4-1/2 hr 1-1/2 hr 1 hr 1/4 hr 1-3/4 hr 6 hr 1 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 22 hr Activity Held safety meeting Rig moved 100.00 % Rigged up High pressure lines Circulated at 3063.0 ft Monitor wellbore pressures Removed Xmas tree Installed BOP stack Held safety meeting Tested BOP stack Retrieved Tubing hanger Retrieved Other sub-surface equipment Retrieved ESP Repaired Tubing handling equipment Ran Tubing to 3704.0 ft (2-7/8in OD) Repaired Tubing handling equipment Ran Tubing in stands to 3500.0 ft Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 4400.0 ft Held safety meeting Ran Tubing in stands to 5361.2 ft Installed ESP Circulated at 2645.0 ft Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Ran Tubing to 5756.0 ft (2-7/8in OD) Space out tubulars Installed Tubing hanger Removed BOP stack Installed Xmas tree Installed Hanger plug Held safety meeting Freeze protect well - 75.000 bbl of Oil Rig moved 100.00 % SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MPU / MPJ-21 500292282500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: lli0.~.~C:~i~i'a[![.~ MWD SURVEY JOB NUMBER: AKMM80001 KELLY BUSHING ELEV. = 64.12 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -64.12 0 0 N .00 E .00 1t~.00 112.00 47.88 0 0 N .00 E .00 202.15 202.15 138.03 0 9 N 68.72 W .17 293.86 293.86 229.74 0 26 S 65.58 W .38 382.73 382.71 318.59 1 36 S 56.77 W 1.31 .00N .00E .00 .00N .00E .00 .04N .llW .10 .06S .54W .54 .88S t.89W 2.03 472.82 472.75 408.63 2 2 S 70.08 W .67 561.91 561.71 497.59 3 51 S 78.85 W 2.10 653.96 653.43 589.31 5 40 S 78.22 W 1.97 746.10 745.'12 681.00 5 41 S 77.12 W .12 834.98 833.40 769.28 7 28 S 79.09 W 2.01 2.12S 4.45W 4.79 3.24S 8.88W 9.36 4.76S 16.37W 17.00 6.71S 25.29W 26.13 8.79S 35.27W 36.32 929.36 926.69 862.57 9 48 S 78.55 W 2.48 1021.14 1016.79 952.67 12 3 S 76.46 W 2.49 1113.76 1107.06 1042.94 13 43 S 75.90 W 1.81 1205.69 1195.89 1131.77 16 2 S 79.48 W 2.71 1298.44 1284.35 1220.23 18 53 S 78.81 W 3.08 11.55S 49.17W 50.49 15.34S 66.16W 67.89 20.29S 86.22W 88.55 25.27S 109.30W 112.15 30.52S 136.65W 140.00 1390.40 1371.18 1307.06 19 32 S 79.25 W .71 1480.91 1456.57 1392.45 19 12 S 78.58 W .45 1574.87 1544.66 1480.54 21 27 S 78.75 W 2.40 1665.79 1628.33 1564.21 24 36 S 80.11 W 3.52 1757.39 1711.29 1647.17 25 31 S 79.24 W 1.08 36.28S 166.37W 170.27 42.05S 195.82W 200.28 48.46S 227.82W 232.91 54.96S 262.78W 268.47 61.92S 300.96W 307.27 1850.10 1794.18 1730.06 27 42 S 75.69 W 2.91 1942.99 1874.88 1810.76 31 36 S 75.89 W 4.19 2035.82 1952.33 1888.21 35 16 S 75.69 W 3.97 2128.34 2026.99 1962.87 37 5 S 77.53 W 2.29 2220.32 2099.57 2035.45 38 42 S 78.82 W 1.94 70.98S 341.49W 348.78 82.25S 386.03W 394.69 94.81S 435.61W 445.79 107.44S 488.75W 500.38 l19.01S 544.04W 556.88 2313.58 2170.86 2106.74 41 34 S 79.12 W 3.08 2406.40 2238.68 2174.56 44 31 S 79.41 W 3.20 2482.13 2292.12 2228.00 45 41 S 78.82 W 1.63 2609.50 2377.86 2313.74 49 40 S 76.66 W 3.37 2704.04 2436.95 2372.83 52 56 S 77.09 W 3.47 130.50S 603.04W 616.98 142.30S 665.29W 680.33 152.43S 717.97W 733.97 172.48S 809.97W 828.12 189.23S 881.82W 901.88 2796.62 2490.35 2426.23 56 35 S 79.98 W 4.70 2889.86 2539.56 2475.44 59 41 S 78.99 W 3.43 2980.45 2583.10 2518.98 62 50 S 79.78 W 3.56 3071.82 2623.38 2559.26 64 50 S 80.03 W 2.20 3163.40 2659.97 2595.85 68 3 S 78.35 W 3.90 204.22S 955.92W 977.48 218.68S 1033.77W 1056.64 233.30S 1111.84W 1136.05 247.67S 1192.57W 1218.02 263.43S 1275.01W 1301.94 ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MPU / MPJ-21 500292282500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111097 MWD SURVEY JOB NUMBER: AKMM80001 KELLY BUSHING ELEV. = 64.12 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3255.59 2691.31 2627.19 72 10 S 77.66 W 4.52 3348.18 2717.23 2653.11 75 18 S 77.39 W 3.39 3438.63 2737.44 2673.32 78 51 S 76.83 W 3.97 3530.69 2755.01 2690.89 79 7 S 76.92 W .31 3622.18 2772.78 2708.66 78 28 S 77.54 W .97 281.45S 1359.80W 1388.62 300.65S 1446.58W 1477.49 320.32S 1532.50W 1565.62 340.84S 1620.51W 1655.96 360.67S 1708.03W 1745.69 3714.61 2791.52 2727.40 78 7 S 77.90 W .55 3805.21 2810.43 2746.31 77 46 S 78.36 W .62 3897.69 2830.55 2766.43 77 5 S 78.06 W .81 3990.63 2849.78 2785.66 79 1 S 75.78 W 3.18 4083.36 2867.44 2803.32 79 0 S 76.53 W .79 379.92S 1796.47W 1836.19 398.15S 1883.18W 1924.80 416.59S 1971.54W 2015.06 437.17S 2060.10W 2105.95 458.96S 2148.48W 2196.92 4174.84 2885.58 2821.46 78 7 S 76.83 W 1.02 4267.29 2905.21 2841.09 77 21 S 75.98 W 1.22 4359.88 2927.83 2863.71 74 21 S 76.71 W 3.33 4453.08 2955.51 2891.39 71 4 S 77.20 W 3.55 4545.80 2987.72 2923.60 68 15 S 79.59 W 3.88 479.62S 2235.73W 2286.55 500.85S 2323.54W 2376.84 522.05S 2410.77W 2466.56 542.13S 2497.46W 2555.52 559.64S 2582.60W 2642.45 4641.11 3025.68 2961.56 64 47 S 79.76 W 3.64 4735.71 3068.59 3004.47 61 15 S 79.19 W 3.78 4833.92 3118.99 3054.87 56 59 S 79.50 W 4.35 4929.15 3173.54 3109.42 53 5 S 81.34 W 4.38 5024.61 3233.19 3169.07 49 32 S 80.70 W 3.77 575.30S 2668.60W 2729.83 590.70S 2751.47W 2814.10 606.28S 2834.28W 2898.35 619.30S 2911.22W 2976.33 630.92S 2984.82W 3050.75 5118.65 3296.21 3232.09 46 17 S 79.65 W 3.54 5214.57 3364.45 3300.33 42 58 S 79.31 W 3.48 5310.17 3436.13 3372.01 39 52 S 80.62 W 3.36 5405.83 3511.02 3446.90 37 4 S 78.60 W 3.22 5500.88 3588.71 3524.59 33 15 S 77.23 W 4.10 642.81S 3053.58W 3120.50 655.11S 3119.83W 3187.86 666.15S 3182.10W 3251.08 676.85S 3240.64W 3310.57 688.27S 3294.16W 3365.29 5596.48 3669.20 3605.08 32 2 S 78.67 W 1.50 5691.72 3749.96 3685.84 31 57 S 78.26 W .25 5786.93 3830.88 3766.76 31 38 S 78.97 W .51 5882.15 3912.07 3847.95 31 19 S 77.85 W .70 5977.16 3993.45 3929.33 30 49 S 77.64 W .55 699.05S 3344.59W 3416.86 709.14S 3394.04W 3467.33 719.05S 3443.23W 3517.51 729.04S 3491.95W 3567.24 739.45S 3539.88W 3616.28 6073.07 4075.81 4011.69 30 50 S 77.42 W .12 6168.36 4157.69 4093.57 30 40 S 77.11 W .24 6202.20 4186.82 4122.70 30 28 S 76.57 W 1.02 6260.00 4236.64 4172.52 30 28 S 76.57 W .00 750.06S 3587.87W 3665.43 760.80S 3635.41W 3714.16 764.72S 3652.17W 3731.37 771.53S 3680.68W 3760.66 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3760.67 FEET AT SOUTH 78 DEG. 9 MIN. WEST AT MD = 6260 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 258.26 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 6,260.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MPU / MPJ-2t 500292282500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111097 JOB NUMBER: AKMM80001 KELLY BUSHING ELEV. = 64.12 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -64.12 1000.00 996.12 932.00 2000.00 1922.84 1858.72 3000.00 2592.03 2527.91 4000.00 2851.56 2787.44 .00 N .00 E 14.31 S 61.86 W 89.80 S 415.91 W 236.39 S 1128.96 W 439.43 S 2069.01 W .00 3.88 3.88 77.16 73.28 407.97 330.81 1148.44 740.46 5000.00 3217.'37 3153.25 6000.00 4013.06 3948.94 6260.00 4236.64 4172.52 627.90 S 2966.21 W 741.95 S 3551.31 W 771.53 S 3680.68 W 1782.63 634.19 1986.94 204.31 2023.36 36.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MPU / MPJ-21 500292282500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111097 JOB NUMBER: AKMM8000! KELLY BUSHING ELEV. = 64.12 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 .00 .00 -64.12 64.12 64.12 .00 164.12 164.12 100.00 264.12 264.12 200.00 364.13 364.12 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .01 N .02 W .00 .00 .04 N .33 W .00 .00 .60 S 1.46 W .01 .01 464.18 464.'12 400.00 564.32 564.12 500.00 664.70 664.12 600.00 765.19 764.12 700.00 865.96 864.12 800.00 2.01 S 4.16 3.27 S 9.04 4.98 S 17.41 7.14 S 27.14 9.55 S 39.22 W .06 .05 W .20 .14 W .58 .38 W 1.07 .49 W 1.84 .77 967.35 964.12 900.00 1069.58 1064.12 1000.00 1172.63 1164.12 1100.00 1277.10 1264.12 1200.00 1382.91 1364.12 1300.00 12.86 S 55.58 17.77 S 76.16 23.60 S 100.31 29.21 S 129.99 35.81 S 163.90 W 3.23 1.40 W 5.46 2.22 W 8.51 3.05 W 12.98 4.47 W 18.79 5.80 1488.91 1464.12 1400.00 1595.84 1564.12 1500.00 1705.18 1664.12 1600.00 1816.28 1764.12 1700.00 1930.41 1864.12 1800.00 42.57 S 198.40 49.96 S 235.48 57.80 S 278.97 67.32 S 326.42 80.66 S 379.72 W 24.79 6.00 W 31.72 6.93 W 41.06 9.34 W 52.16 11.10 W 66.29 14.13 2050.26 1964.12 1900.00 2174.98 2064.12 2000.00 2304.61 2164.12 2100.00 2442.12 2264.12 2200.00 2588.44 2364.12 2300.00 96.87 S 443.69 113.48 S 516.32 129.38 S 597.23 146.92 S 689.93 168.86 S 794.43 W 86.14 19.85 W 110.86 24.72 W 140.49 29.63 W 178.00 37.51 W 224.32 46.32 2750.14 2464.12 2400.00 2939.83 2564.12 2500.00 3174.71 2664.12 2600.00 3578.78 2764.12 2700.00 4065.93 2864.12 2800.00 197.06 S 918.24 226.82 S 1076.52 265.57 S 1285.31 351.49 S 1666.51 454.97 S 2131.84 W 286.02 61.70 W 375.71 89.69 W 510.59 134.87 W 814.66 304.08 W 1201.81 387.14 4479.10 2964.12 2900.00 4726.30 3064.12 3000.00 4913.30 3164.12 3100.00 5071.47 3264.12 3200.00 5214.09 3364.12 3300.00 547.43 S 2521.43 589.15 S 2743.34 617.33 S 2898.62 636.76 S 3019.53 655.04 S 3119.50 W 1514.98 313.17 W 1662.18 147.20 W 1749.18 86.99 W 1807.35 58.17 W 1849.97 42.62 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERMICES DRILLING MPU / MPJ-21 500292282500 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 111097 JOB NUMBER: A~M80001 KELLY BUSHING ELEV. = 64.12 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5346.35 3464.12 3400.00 670.04 S 3204.69 W 1882.23 32.26 5471.25 3564.12 3500.00 684.69 S 3278.02 W 1907.13 24.90 5590.49 3664.12 3600.00 698.42 S 3341.47 W 1926.37 19.24 5708.41 3764.12 3700.00 710.94 S 3402.69 W 1944.29 17.92 5825.98 3864.12 3800.00 722.98 S 3463~33 W 1961.86 17.57 5943.01 3964112 3900.00 735.70 S 3522.79 W 1978.89 17.03 6059.46 4064.12 4000.00 748.54 S 3581.06 W 1995.34 16.45 6175.84 4164.12 4100.00 761.66 S 3639.13 W 2011.72 16.38 6260.00 4236.64 4172.52 771.53 S 3680.68 W 2023.36 11.64 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~/~--] ,.~~ ~' MWD Formation Evaluation Logs - MPJ-21, AK-MM-80001 October 21, 1998 MPJ-21: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22825-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22825-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE A'ITACHED COPIES OF THE TRANSMI'VFAL LETYER TO THE ATYENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchora~,e._Alaaka~ OCT . Date: Alaska 0ii 6. ~ ~,,: i~. Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Sign 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries. Inc. Comoanv 0 I:t I I--I-- I IM Oi To: WELL LOG TRANSMITYAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs ., MPJ-21, AK-MM-80001 October 21, 1998 1 DWG formatted Disc with verification listing. API#: 50-029-22825-00 PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING THE ATrACHED COPIES OF THE TRANSMITTAL LETYER TO THE AIWENTION OF: Sperry-Sun Drilling Services BP Exploration (Alaska) Inc. Attn: Ali Turker Petro-technical Data Center, MB3-3 5631 Silverado Way, Suite G. 900 E. Benson Blvd. Anchorawe~ ,Al~s~ ~ ?~ ~ _ 'a_a_g~ ~9~_ ~ Anchorage, Alaska 99519-6612 ~r~ 2 8 ]'998 Date: v~I ~ ,, . . Sign '~:k~ Ala~a 0il ~. ~as Cons. ~,0mrnt~0n Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 Oct. 12, 1998 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the PDC GR/CCL, for well MPJ-21, Job # 98489 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS- 9/29/98 StYe of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor -~.~3._001 Porcupine Drive a r~C~b rage;, --AK---9950T I CH LIS Tape OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 I CH LIS Tape Sent Certified Mail: P 067 695 493 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska Date Delivered: OCT 1 5 1998 0il & -~s Schlumberger GeoQuest 500 W. Intemational Airport Road Anchorage, Alaska 99618-1199 Received b~ State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 20-Aug-98 Transmittal of Final Prints. Please sign and return copy to the following' Western Atlas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 and BP Exploration (Alaska)Inc. Petrotechnicai Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Well Name I Services I Bluelines !R/F Sepia I Film MPJ-21 GR/CCL PERF (6AUG) I 1 MPJ-21 GPJCCL PERF (7AUG) 1 1 MPJ-21 GPJCCL DEPTH REF. 1 1 MPH-05 LEAK DETECTION 1 I Received b~.' RECEIVED AUG 1998 Alaska ~ Cons. C0mmi~[on Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 29, 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-21 BP Exploration (Alaska) Inc. Permit No. 97-200 Sur. Loc. 2179'NSL, 3276'WEL, Sec. 28, T13N, R10E, UM Btmnhole Loc. 1426'NSL, 1621'WEL, Sec. 29, T13N, R10E, UM Dear Mr. Alvord: 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. BIo~vout 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 North Slope pager~ y--- Chairman BY ORDER OF THE COMMISSION dlffenclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork I~Drill DRedrill Ilb. Typeofwell FI Exploratory F'lStratigraphicTest I~ Development Oil D Re-Entry D Deepenl D Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE - 64.5' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4. Location of well at surface '7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2179' NSL, 3276' WEL, SEC. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1472' NSL, 1400' WEL, SEC. 29, T13N, R10E, UM MPJ-21 At total depth 9. Approximate spud date Amount $200,000.00 1426' NSL, 1621' WEL, SEC. 29, T13N, R10E, UM 10/31/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 1621'I No Close Approach 2560 6184' MD / 4173' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum HoleAngle 76.44° Maximum surface 1292 psig, At total depth (TVD) 3719'/1663 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD 'I'VD MD TVD (include stage data) 24" 20" 91.1 # H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 9-7/8" 7" 26# L-80 BTC-Mod 6153' 31' 31' 6184' 4173' 1456 sx PF 'E', 302 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface intermediate Production Liner ;,, ~,..~.. 0il & Gas Cons. C0nlmission Perforation depth: measured ,~r,~ _. true vertical Anch0rag8 120. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Ddlling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAO 25.050 Requirements Contact Engineer Name/Number: James Robert$on, 564-5159 Prepared By Name/Number:. Kathy Oampoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip~a,ord .,/~?.+ (~. ~ Title Senior Drilling Engineer Date Commission Use Only Permit Number I APl Number I Appr(valE~to I See cover letter ~-2-<::3,C:::> 50- o2_..~-- ~-- 2.- 2:'2- ~'- t~ '~.c~ C[q for other requirements Conditions of Approval: Samples Required []Yes .l~No Mud Log Require~ []Yes '[~No Hydrogen Sulfide Measures []Yes~No Directional Survey Required []Yes []No Required Working Pressure for BOPE ~[2M; [-13M; []5M; r"ll0M; r-]15M Other: ~;rigina.! Signed By by order of f Approved By .,3avid W, Johnston Commissioner the commission Date Fnrrn lf3-401 RRv 12-r)1-R~ Submit I ) Trir, licate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): James E. Robertson IMP J-21 Well Plan Summary ISCHRADER BLUFF PRODUCER 564-5159 Surface Location' 2179 FSL, 3276 FEL, S28 T13N R10E UM Target Location: 1472 FSL, 1400 FEL, S29 T13N R10E UM Bottom Hole Location: 1426 FSL, 1621 FEL, S29 T13N R10E UM I AFE Number: 1337099 I I Estimated Start Date: I 31 OCT 97 lED: I S 84' I I Well Design: Formation Markers: I Rig: I Nabors22E I I Operating days to complete: ITvD: I® 16.0 I KBE: 64.5 ft Schrader Bluff Producer Formation Tops MD TVDSS KOP 300 300 Base of Permafrost 1900 1775 Top of Ugnu 5040 3233 Top M Sand 5130 5441 Top NA (Target) 5734 3719 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 5769 3749 NCND 5809 3784 NE 5831 3803 NF 5887 3852 OA 5931 3890 OA4 5970 3924 OB 6OO9 3957 Top of Seabee 6034 3979 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 6184 4108 TD at 150' MD past base of Schrader CasingJ'rub ing Program: Hole Size Csg/ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 9-7/8" 7" 26# L80 BTC-MOD 6153' 31 '/31' 6184' / 4173' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at ±3719' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1663 psi (8.60 ppg EMW), is 1292 psi, well below the internal yield pressure rating of the 7" casing. Lo~lgin~l Program: Open Hole Logs: MWD from surface to TD LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr through the Ugnu and Schrader Bluff intervals. Cased Hole Logs: NONE Mudloggers are NOT required for this well. Mud Program: Spud Mud ISpecial design considerations I See "Drilling Hazards and Risks" section about dealing with the I possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel 9el Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 10.2 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.8 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1300' MD Maximum Hole Angle: Close Approach Well: Waste Management: 76.44 NONE Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on J-Pad have been permitted for annular injection. MP J-21 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill 9-7/8" surface hole as per directional plan to 6184' MD / 4173' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/ROP from the top of the Ugnu to TD. NOTE: Fill hole with mud and check diverter for leaks before spudding in. NOTE: Short trip no deeper than 300' md past the base of permafrost. NOTE: Utilize lubricants as necessary to enhance sliding performance. NOTE: Drill at a controlled rate of no more than 200 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. 9. N/D Diverter. N/U FMC Gert 6 Wellhead and Tree. Note that MP J-21 will have 2-7/8" tubing. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: See the latest Milne Point I-Pad Data Sheet prepared by Pete Van Dusen for information on I pad. Particularly close attention should be paid to hydrate experiences on previous I-Pad wells. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: NO HYDRATES HAVE BEEN ENCOUNTERED ON ANY WELLS DRILLED AT MILNE POINT 'J' PAD TO DATE. If hydrates are encountered the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Aisc, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the form%o[~ ~ ~ ~¢~ .~rl~j~1~ ize the movement of hydrates into the wellbore. ~'i 2. Close Approach: There are no close approach problems with MP J-21. 3. Lost Circulation: 7 Schrader Bluff wells have been drilled on Milne Point 'J' pad since 1990 afld none of trh~r~erienced any problems associated with lost circulation. In an effort to continue this trend maintain slow, steady running speeds while running casing and ensure mud is in good shape before POOH to run casing. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have been associated with the drilling of Schrader Bluff wells on Milne Point 'J' Pad to date. Some tight hole on trips has been encountered in the 2000' TVD to 3500' TVD range. Once tripped through the tight hole problems went away. The wells on Milne Point 'H' Pad drilled during the summer of 1997 encountered severe tight hole problems; especially swabbing problems while POOH. It appears that utilization of a 9-7/8~ bit has aided in minimizing swabbing problems on the Milne Point 1-08 well drilled in mid October 1997. At this point we will continue to utilize a 9-7/8" bit to give a little more annular clearance between the hole and BHA in an effort to minimize the swabbing problem. We will also break circulation at the first indication of swabbing on short trips. If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 7. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Ddlling Engineer. A 'C' cement for the second stage tail cement will be incorporated into the cementing program only if hydrates are encountered. MP J-21 7" SURFACF_JPRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 BBL water STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 453 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 4630' MD TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 302 SACKS THICKENING TIME: Greater than 4 hrsat 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (6184' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (5130' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 4630' MD SPACER: STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: 50 BBL Weighted Spacer (To weight of mud circulated before pumping Stage2). TYPE 'E' PERMAFROST Retarder 12.0 ppg 1003 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM ES CEMENTER AT 2100' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: NOT APPLICABLE N/A N/A N/A N/A 000 SACKS THICKENING TIME: N/A WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 9-5/8" Rigid Straight Blade Centralizers - one (1) per joint on the bottom twenty-eight (28) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (28+2 = 30) Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform 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 12.0-15.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is ,not necessary. .! Anactr~11 Sehlumberge~ ~ ..................................................................................................................................... ?'7 ..................... ' ...................................... D LL.tl EaSt: BOth Avenue " LI ~dl'choracje, AK 99518 ' :Z (90?) 349-4511 Fax 344-1622 D/RZC~IONJ~ tll~. Pld~ J~or g]'IAR.BD gBRVtCEg DRZI~INO Well ...... :.~: HPa-21 S597-07 (P01) Field ........ ~ Mtlne Doing, J-Pad Ccx~pu~a:lon..: Ht~lmum Cugvab=re UnL~ ........ : FEET SurfaCe bat..: 70.45056549 ~ Surface Lou9.~' 149.57537255 R begal DeecrLp~ton Surface ...... =,2L79 PSb 32?6 FRb S28 T13N R.1.0~ UM · arge: ....... : 1472 ~Sb ~400 ~b ~2~ TL3N R10~U14 LOCATIONS - AI~aKR Zone= 4 X-COord Y-Cootd 552045.45 6.014577.38 548649.00 6013847.OD 548426-9~ 5013799.68 m ,mm STATION MKRSURED 3NCLN DIRI~CTION IDHNTIPICATION DEPTH ANG~B AZ INU'J~I I0~ 0.00 O.O0 0.00 KOP BUILD ~/100 300.00 0.00 258.26 400.00 1.00 258.26 BUZbD 3.S/L00 500.00 2.00 258.26 600.00 3.50 258.26 PROP0SIID WIlLL PROFEIaE' almmmmmmm~rlmmm VERTiCAL-DEPTHS 0.00 -64.50 300.00 235.50 399.99 335.49 499.96 599.84 P=epared, .... : 22 Ap= Yert s,ect az.~ 258.26 ~ elevations: 64.50 ~ Magnetic Dcln: +28.021 iR) Se&~e Facto=.~ 0.9.9990308 Convergence,.: +0.40014983 I ANADRILL AKA'Dpc SI;CTION C00RDIN~T~ISrFRC~ AIASXA Zone 4 0.00 0.00 ~ 0.'00 E SS2045.45 0,87 0.18 S 0.85 N 552044.60 6014597.20 3.49 0.71 9 3,%2 N 552042.04 6014576.65 8.29 1.69 S 6,11 ~ 552037.35 6014575.64 T00G Db/ PACR 100 102L o.oo 102~ 0.00 102b L.00 102b 1.0o 102b 1.50~ 700.00 5.00 258.26 800-00 ?.OD 258.26 900.00 9.00 258.26 1000.00 11.00 255.26 1100.00 13.00 255.26 699.56 635.06 799.O1 734.51' 898.Q3 833.53 996.51 932.01 L094.32 1029.82 15.70 3.19 S. 15.37 W 552030.10 6014574.08 3021 1.S0 26.15 5.32 S 25,60 W $52019.89 g0345?1.88 KS 2.00 40.07 8.15 S 39.23 W 552006.28 6014568.96 HE 2.00 57.43 31.68.9 56.23 N 551989.31 6014565.31 }~g 2.00 78.22 15.91 S 76.S9 ~ 551968.98 6014560.94 HS 2.00 ~200.00 15.00 1300.00 ~7.00 258.26 1£91.34 1126.84 258.26 1287.46 1222.96 ~02.41 20.83 S 100.27 ~ 551945.34 6014555.85 ~S 2.00 129.97 26.4~ 3 127.26 H 551918.39 601~550.06 HS 2.00 (Anadrlll (e)97 HPJ23p0L 3.0C L2~02 P~ P) -) .) HBJ-21 $097-07 (B01) 22 Apr 1997 P&ge 2 : ~ ~ m m ! ~ m m m ~ ~ m m ~ ~ m mm m m mmm~m STAT ~O~ MEASURED l £DENTI~ICATIO~ DEPTH ANGLE 1400.00 19.00 15o0.00 2~.o'0 1600.oo I?O0.O0 25.OO 2/~00 ~Ur~ ~762.00 26.2~ 3,5/100 ~mmmmmmm z~m~mmmmmmm~mmm D£R~CT~O~ VERTICAL-D~PTH~, AZIMUTH TVD SUB mmmmmmm~= ==~==mmm 258,26 t382.56 [31fl,06 258,26 1476.53 1412.03 258,26 £569.24 £50&,74 258,26 £660,59 1596.09 258,26 1736,50 £652~00. t873.49 26.24 258,26 1816.50 ~900.00 27.17 258.26 1840.16 2000,00 30.67 ' 258.26 1927.70 2LO0.O0, 34.17 258.26 2012,10 2200.00 37.67 258.26 2093,07 2300.00 ' 41.17 2400.00 44.6~ ! 2500.D0 48.17 2600.00 5].67 2700.00 55.17 8iqD 3.S/L00 BUILD DROP 4/100 2800.00 58;67 2900.00 62,17 3000.00 65.6~ 3100.00 69.17 3200.00 72.6~ 76.17 76.44 76.44 75.30 71,38 3300.'00 3307,69 437~.54 4~00.00 ~500,00 25m.2; 2Sa.2~ 22&3.54 25e.2~ 231~.45 25e.26 2~56.04 258.26 2~3'6,43 250.26 258.26 258.26 258.26 258.26 25'8.26 258.26 258.26 258.26 258~26 249'1.01 2540.3"/ 2584.33 2622.72 2655.41 1752.00 '1775.68 1863.20 1947.60 2028.57 2105,81 2179.04 22~7.97 2312.34 2371.93 2426.51 24?5.67 2519.83 2558,22 2590.91 mmmmm~m ~m~mmmmm~z~mmmmmmmmm x~mmmmmm~mmmmmmu~am SBCT~ON COORDI~L~TES-FROM ALASKA Zone 4 DEPART HEhLHEAD X Y . 160.88 32;72 S 157.51 B 551068.19 6014543.56 195'0~ 39.66 ~ ~91.00 W 5~054.65 6014536.37 ., 232.53 4?.30 S 227.67 ~ 551818.13 6014528.S0 273.21 55.57 ~ 267.49 ~ 55£77~.38 6014519.95 300.02 6~02 8 293.?4 ~ S$~752.]7 60145£4.31 · · . 349.31 71.05 9 342.0~ W S51703.9G 6014503.95 HS 36£.22 ~3.47 8 353.67 W '551692.34 6014~01.45 409.57 03.3[ ~ 401.D1 W 551645.07 6014491.26 l-lS 3.50 ~63.17 9~.21 ~ 453.49 W $51592.68 521.82 106.14 B, 510.91'~ 551535.34 6014467.68 RS 3.50 585.31 553.39 725,82 802,32 882,6~ 966.38 1053.34 1143.14 1235.46 1329.95 .. 132.90 147.63 163.19 1'79.53 573.0; ~ 551473.28 6014454.34 HS 3.50 639.73 H .551406.q2 6014440.03 ILg 3.50 710.'65 W 551335.92 6014424.00 HS 3.50 785,55 W 551261.34 6014~08.72 HB 3.50 864.16 W 551182.65 6014391.84 HS 3.50 2682,27 26t7.77 1426.26 2684.09 2619.59 1433.73 2934.D4 2869'.54 2469.86 2940.49 2875.99 2495.52 2969.08 2904.58 259£.32 196.57 8 946.18 232.52 $ 1119.24 251.30 8 1209.63 270.52 8' 1302.is 551100.75 6014374.23 HS 3.50 551015.95 6014355.~5 H9 3.50 550927.97 6014337.07 }19 3.50 55063V.72 60143~7.67 H2 3.50 550745.35 6014297.80 ~S 3,50 290.~] S 1396.44 2~1.63 S 1~03.76 S02636 S 2418.22 507.60 S 2443.35 527.08 ~ 2537.15 550651.20 6034277.56 HS 3.50 550643.90 6034275.99 HS 3.50 549631.03 60L4058.18 h$ 0.00 549605.94 6014052.78 bE 4.00 549512.29 6014032.64 LS 4.00 4600.00 67.38 4700.00 63.38 4800.00' 59.38 (AnadrllL (c)97 MPJ21P01 3.0C 12:02 PM P) 25fl.26 258.26 250,26 3004.30 2939,B0 3045,95 2901,45 3093,84 3029.34 2684.89 27?5.78 2863.55 546 12 S 2628.77 564.60 S 2~17.76 582.45 S 2803.68 549420.82 60~&012.97 549351.9? 6013993.87 549246.17 6013975.42 I,S 4.00 LS 4.00 LS 4.00 ,. Ivt~J:21 ~Bg~-O? (~03) 22 ~pr 3997 Page .3. '. . . . m~=:~:mmmmmmm~m~ STATION mmmmmm~m ammmmm' mmm~u~mm M'KASURBD £NC/~ DIRHCT20~ DEPTH A~I.~ AZIt4I,"~4 4900.00 55.38 258.26 5000.00 53.38 250.26 ,. 5300.00 47.38 258.26 5200..00 43.38 258.26 5300.00 .39.38 258.26 ~m~mmmmmmmmmmmmm VRRTJCAL-DEPTHS 'I~D SUB-SBA ~mmmm/mm mmmmmeem 314T.74' 32~2.47 320~.97 3342.70 32~8.20 34Z~.42 3353.22 maa~mmmm SECTION DEPART 2947.76 ~028.00 3375.D5 3241.L4 mmmunAmx~ammmmmmsln~m a~mmmmmmetmm~lmmmmu mtea Emmm COOR,1)XNATES-PR0~ AXaR~KA ~one 4 TO0~ Db/ W~bLHEAD X y PACK L00 mmumm~mamm mmmmmlm~m ammmmmm~m ~slmmmmmen ~mmm ~mmm S99.58 9 2886.13 W 549163.85 6033957.~2 ~8 4.00 615.90 8 296~.?0 ~ 549085.43 6033940.85 'bg 4.00 631.34 8 3039.00 ~ 549013.23 6033924.89 b8 4.00 545.82 8 3308.67 ~ S48941.66 6033909.94 bS 4,D0 659.26 8. 3373.38 W S48877.06 6013896.04 bg 4'.00 RND..4/100 DROP TOe ;CHI~AD~R / r~ . .' OR OB 5400.00 5500,00 5534.47 5734.44 '5734.4~ , . 5809.52 593L,92 6009.29 35.38 258,26 31,38 258.26 30,00 258,26 30,00 '258,26 30.00 258.26 30.00 30.00 30.,00 30.'00 30.00 258.26 259.26 25B.26 258,26 2S8,26. 3497.17 3580.65 3'630~29 3793.50 3V03.50 ,. 3e1~.5o ~648,S0 3667.50 3954.50 402~.50 3432.67 3301.83 6V3.60 S 3232.81 W 5488L7.72 3536.i5 3356.84 682.79 ~ 3286.67 H 548763.95 35~5.79 3374.43 686.37 E 3303.89 N 5~8746,76 3739.00 3474.43 706.V1 6 3401.80 W 5%8649.D0 3739.00 3474.43 706.71 g 340~.80 W 548649.00 3?49.00 3491.75 730.23 S 34L8.~6 . 548632.07 3984,00 3513.96 7'34.34 ~ 3430.54 # 549632.31 3803.00 3522.93 715,$8 8 3449.28 # 548603.59 3890.00 3573.36 725,79 8 3498~46 # 548652,49 3957.00 36Li.84 734.66 S 3S3~.34 ~ 540514,67 6013883,28 L,..q , ~03287~.72 LS 6ot~868,o2 Ks 6o~3847.oo Hs 6ot3847,oo Hs G013839.tl H8 6013836.8L HS 6013826.25 HS. 6013818.11 HS 4 .OD 4. O0 4.00 0.00 0.00 0 o.0o 0.00 0.00 0.00 TD 6034.69 30'.00 6184.69 30.00 258.26 4043.50 3979.00 3624.5~ 258.26 4L73.40' 4108.90 3699.5~ 937,24 $ 35§8,77 W 548502.26 60338X5,44 HS 0.00 752.50 $ '3622.20 W 548425.9% 60~3799.68 0.00 (~madcil'l ('c)}? ~PJ21POI 3.0C 12:02 PM 13) ANADRILL AKA-DPC il i . i, SHARED SERVTCE¢' DRILLTN6 ..... I('' ...... , , · Ill Ill F'--I ANADRiLL AKA-DPC MPJ-21 SB97-07 (P01) VERTICAL SECTION VlE~ ....... Sec[ion at: 258.26 TVD Sca~e.' ~ ~nch : 600 feet o-----~--- Dep Sca~e.' ~ ~nch ~ 600 fee~ .... ; ..... Orawn ' 22 Apr ~§§7 Anadri ]1 SchJumDerger i O' 8) K~ BUILD ~/lO0 300 300 -0 0,~ c) 8uI~ t.5/~00 5~ 500 3 2.00 0 ....... O) 6VILO E/)O0 7~ ?GO ~8 5.00 E) E~ 2/~00 ~ILD ~762 ~7~6 300 F) BUILD 3.5/100 1873 ~816 3~9 ~8.A4 Gl ENO 3,5/~ 8UI~ 3~08 ~4 1d34 76.44 0 ...... r .... HI ~OP 4/~00 43?4 ~34 ~470 76,~ [I ENO ~/iO00~P 5534 38t0 337~ 30.00 Jl TAROT ~x~x~ 5734 3783 3474 ~,00 0 K] TO 6~85 4173 ]700 30.00 '0 ~ , ~,, .. ~0 ....... ~o . ......... ~,. ....... ------- =-- : -~=~-_ .... : ............ · ~~-~ ...... ~-~- . iO " ~ ................. . 0 '"~' ' , o 300 600 soo ~o ~oo ~o ~oo ~a~ aTOO ~ooo 3~o 3~oo : Section Departure mm ....... ~n ~ I adi, ,--,J{"f '=I--IT~H I'~f3T7__.kkF' J~-iF .I-.F- 'I~iT JFFI' /n,-'. /,'-n T SHARED SERVICES DR'rLLTN6 ..... ~-.:'-tl.,I,__L__ II I I VERTICAL SECTION VIEW I" lSecti~n at: 258.26 ITYD Scale.: ! inch = ~O0 feet IDep Scale.: ~ inch = JO0 fee~ IDrown ..... : 22 Apr 1997 I- i /nadr] ] ] Sch]um~'enger HaPkeP ~d~nt~ic~t~on MD ~8 SEGTN IN~N ........ AI END ~/t00 D~P 55~4 36~0 ~37~ ~0.00 8} TAROT ~~ 5734 3783 3474 30.00 C} TO 6i85 4i73 3700 30,00 ..... . ~ ~-.. , .~ .. " ~ ..... X ~~~-~ 4' .. ~ ...... rapg~,~u~j~feet ! . -~ -~ ................................. ~..................... I .,.,. .... '~-~........._ 1 ~ ~ ~- ~,%.%~ ~%-.-,,, .~ ¢~_~ ~ ............................. ... -. ; .~ , ,. H. O0 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 · 3650 3700 3750 3800 · Sect. ion Dep~r'tur'e L~'~¢,i'i [¢)g'/~oJ2jpoj 3.aC J~:o6 P~ P] ................... ANADRILL AKA-DPC : , , · '1 Marker IMent i f icatlon ND 1',1/8 A) KB 0 ON OE B) KOP BUILD d/tOO 30 OH O E C) BUILD i.5/iOO 500 , S D) BUILD 2/,00 700 SS E) ENO ~/100 BOIL, I7,~- 6,.~ FI BUILD ,.5/,00 ,B73 7iS 342, G) E~D 3.5/,00 BUILD 330, 2§2S H) ,aP 4/,00 4374 5025 [) E~ 4/100 DROP 5534 6B§ S 3304 J] I/~GET x,~xxx,xx~x 5734 707 S 3402 K) TD 6J85 75~ S MPJ-21 SB97-07 (PO PLAN V i i i i mil Im i i CLDSURE .....' 3700 f~et at Azimuth ~5B.26 DECLINATION.' +~B.02~ (E) SCALE ' ~ inch = 500 feet DRANN · 22 Apr' 1997 target ([ladiu$ ~(~ 4250 4000 3750 5500 3250 3000 2750 ~00 2250 200O ~7~ 1500 i250 fO00 750 500 250 0 250 <- HESI - EASI -> ' -- i mill mm ........ m mill m m mm mil mil m m m m m : ?.F, ..~v-. - ..,-. - .,~-. --~.~ ......... : ,~,~ ~- ~,.~.,~ ~.-,~ - ............... -) ~ MON J-1 NORTH t~ + ~ ,~oo + · J-01 · J-11 · J-02 I J-08 I J-03 · J-lO · J-04 · J-16 · J-17 ~- J-18 · J-19 · J-20 -~ J-21 [] J-06 · J-12 · J-09 · J-13 · J-05 · J-14 · J-07 600 ~ MON d-2 SOUTH VICINITY MAP N.T.S. '~-- N-600 SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 1.3, 199.5. MPU J-PAD LEGEND NOTES 1. DATE OF SURVEY: OCTOBER 13, 1995. 2. REFERENCE FIELD BOOK: MP95-19 (pgs. 43-44). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. 4. GEODETIC COORDINATES ARE NAD 1927. 5. PAD SCALE FACTOR IS 0.9999031. 6. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS J-1 AND J-2. AS-BUILT CONDUCTOR · EXISTING WELL LOCATED WITHIN PROTRACTED SECTION 28, T. 1.3 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECI~ON NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=6,014,659.75 N= 909.90 70'27'02.848" 70.4507911' 35.1' 2,262' FSI_ J-18 X= 552,008.70 E= 1024.81 149'54'32.404" 149.5756678' 3,312' FEL Y=6,014,577.38 N= 819.72 70'27'02.036" 70.4505656' 35.0' : 2,179' FSI_ J-21 X= 552,045.45 E= 1,025.44 149'54'31.341"' 149.5753725' 5276' FEL 10/t4/95 O~IG~NAL ^S-BUILT ISSUE .o.I 0AT~ I R£V1DO61 T8 5^0 / "¥ lcd/ BARNHART !CHECKED: DENNY 10/14/95 DRAYaNG: MPJPADAB JO~ NO: SCALE: L BP EXPLORATION MILNE POINT UNIT J PAD CONDUCTOR AS-BUILT WELLS J-J8 &: J-21 [SHEE'I O~ ] 1 °"°~"~/ I ool~a.~zI VENDOR Ai ASKAST14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 001 ~7 CI~ ! O01771t 100. O0 100. O0 PYMT ~OMMENTS' pe]'~it ~;o d~ill application HANDL[NO INST' s/h Kathy Campoa~or, x5122 ...... ~,,~ ~,.~ ,~ ,.. ~. ~.=~ ~ ~==~ ~,~. ~.,~ ~.~ rilE ATTACHED CHECK IS IN PAYMENT FOR ITi;M~ OF.~"t.;; · WELL PERMIT CHECKLIST COMPANY ~/o WELL NAME /~¢,,~ I~'"'" Z / PROGRAM: exp [] dev/J~redrll [] serv [] wellbor__q,L~eg ~ ann. disposal para req [] FIELD&POOL ,.~'.,~,~ ADMINISTRATION ENGINEERING GEOLOGY APPR DA.TE / 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... ~ N Surface casing protects all known USDWs ........... ) N CMT vol adequate to circulate on conductor & surf csg ..... ) N CMT vol adequate to tie-in long string to surf csg ........ (;) N CMT will cover all known productive horizons .......... ( ), N Casing designs adequate for C, T, B & permafrost ....... ) N Adequate tankage or reserve pit ................. (~ N If a re-drill, has a 10-403 for abandonment been approved... Y N Adequate wellbore separation proposed ............. N If diverter required, does it meet regulations .......... N Drilling fluid program schematic & equip list adequate ..... N BOPEs, do they meet regulation ................ N BOPE press rating appropriate; test to ~ psig. N Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Y 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. /,Y' N ' 1 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for we.eklyprogress reports // Y N lexploratory only] ..... ,2' REMARKS GEOLOGY: ENGINEERING: COMMISSION: JDH ~ R N C.(~,,,~,~ CO Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09~97 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. Sperry-Sun Drilling Services LIS Scan Utility Thu Oct 15 10:48:24 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Tape Header Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD 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: MWD RUN 2 AK-MM-80001 HALL LOCKWOOD Scientific Technical M (] OF LMED Date MPJ-21 (DEPTH CO 500292282500 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 15-0CT-98 28 13N 10E 2179 3276 OCT 28 1998 Oil' ~' '~' ' & L~eS ~.~.3ns. Commission ~chor~e FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 64.10 35.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 20.000 112.0 PRODUCTION STRING 9.875 6265.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL MWD DEPTHS ARE CORRECTED/SHIFTED TO THE WESTERN ATLAS WIRELINE-CCL GAMMA RAY WHICH WAS LOGGED ON AUGUST 06, 1998. THE SURVEY PROVIDED WITH THE LOG PRESENTATIONS IS NOT DEPTH CORECTED AND IT IS NOT THE FINAL NOR OFFICIAL SURVEY. HOWEVER, THE LAST LINE DOES REPRESENT DEPTH SHIFTING AND IS PROJECTED TO DEPTH CORRECTED TD. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. ALL MWD RUNS REPRESENT MPJ-21 WITH API#: 50-029-22825-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 62650'MD, 4241.50'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 2491 0 6193 5 RPM 2491 0 6193 5 RPS 2491 0 6193 5 RPX 2491 0 6193 5 GR 2499 0 6201 0 FET 2562 0 6193 5 ROP 2563 0 6265 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) GR 2490.0 5415.5 5419.5 5422.0 5444.5 5468.0 5476.5 5489 0 5491 5 5523 5 5525 5 5548 5 5658 0 5908 5 5997 0 6133 5 6150 0 6260 5 EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: BASELINE DEPTH 2491.0 5416 5 5420 5 5423 5 5446 5 5470 0 5478 0 5491.5 5495.0 5524.0 5527.5 5550.5 5662.0 5912.5 6001.5 6137.5 6155.0 6265.5 MERGED MAIN PASS. $ BIT RUN N0 MERGE TOP MERGE BASE 2 2562.0 6265.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical loH depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 2491 6265.5 4378.25 7550 ROP 13.8478 2176.03 277.067 7406 GR 10.267 115.786 57.8345 7405 RPX 2.1598 78.2482 10.9499 7406 RPS 2.2731 113.79 11.7993 7406 RPM 2.106 199.231 11.5843 7406 RPD 2.292 222.335 12.1801 7406 FET 0.1484 8.3597 0.844559 7264 First Reading 2491 2563 2499 2491 2491 2491 2491 2562 Last Reading 6265.5 6265.5 6201 6193.5 6193.5 6193.5 6193.5 6193.5 First Reading For Entire File .......... 2491 Last Reading For Entire File ........... 6265.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Sel-vice name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2490 0 2490 0 2490 0 2490 0 2498 0 2561 0 2562 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 6188.5 6188.5 6188.5 6188.5 6196.0 6188.5 6260.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTRON_AG. RESIS. 4 $ BOREHOLE A_ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: 10-NOV-97 5.07 5.46 MEMORY 6265.0 2562.0 6265.0 30.5 79.1 TOOL NUMBER PO869PCRGM6 PO869PCRGM6 9.880 9.9 SPUD/LSND MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/w-DOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 2 FT/H 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 0HMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 FET MWD 2 HOUR 4 1 68 9.30 68.0 9.0 1400 5.2 2.900 2.510 2.400 4.000 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 28.4 Name Min Max Mean DEPT 2490 6260.5 4375.25 ROP 13.8478 2176.03 277.21 GR 10.267 115.786 57.8162 RPX 2.1598 78.2482 10.9522 RPS 2.2731 113.79 11.802 RPM 2.106 199.231 11.5871 First Last Nsam Reading Reading 7542 2490 6260.5 7398 2562 6260.5 7397 2498 6196 7398 2490 6188.5 7398 2490 6188.5 7398 2490 6188.5 RPD 2.292 222.335 12.1831 7398 FET 0.1484 8.3597 0.844624 7256 2490 6188.5 2561 6188.5 First Reading For Entire File .......... 2490 Last Reading For Entire File ........... 6260.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Thu Oct 15 10:56:16 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Tape Header Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Namer UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD 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: MWD RUN 2 AK-MM- 80001 HALL LOCKWOOD MPJ-21 500292282500 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 15-0CT-98 28 13N 10E 2179 3276 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 64.10 35.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 20.000 112.0 PRODUCTION STRING 9.875 6265.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL MWD DEPTHS ARE CORRECTED/SHIFTED TO THE WESTERN ATLAS WIRELINE-CCL GAMMA RAY WHICH WAS LOGGED ON AUGUST 06, 1998. THE SURVEY PROVIDED WITH THE LOG PRESENTATIONS IS NOT DEPTH CORECTED AND IT IS NOT THE FINAL NOR OFFICIAL SURVEY. HOWEVER, THE LAST LINE DOES REPRESENT DEPTH SHIFTING AND IS PROJECTED TO DEPTH CORRECTED TD. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. ALL MWD RUNS REPRESENT MPJ-21 WITH API#: 50-029-22825-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 62650'MD, 4241.50'TVD. SROP = SMOOTHED PJ~TE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PAt{SE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 2491.0 6193.5 RPM 2491 0 6193 5 RPS 2491 0 6193 5 RPX 2491 0 6193 5 GR 2499 0 6201 0 FET 2562 0 6193 5 ROP 2563 0 6265 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 2491 0 5416 5 5420 5 5423 5 5446 5 5470 0 5478.0 5491.5 5495.0 5524.0 5527.5 5550.5 5662.0 5912.5 6001.5 6137.5 6155.0 6265.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: GR 2490.0 5415.5 5419.5 5422.0 5444.5 5468.0 5476.5 5489.0 5491.5 5523.5 5525.5 5548.5 5658.0 5908.5 5997.0 6133.5 6150.0 6260.5 EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 2562.0 6265.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 2491 6265.5 4378.25 7550 ROP 13.8478 2176.03 277.067 7406 GR 10.267 115.786 57.8345 7405 RPX 2.1598 78.2482 10.9499 7406 RPS 2.2731 113.79 11.7993 7406 RPM 2.106 199.231 11.5843 7406 RPD 2.292 222.335 12.1801 7406 FET 0.1484 8.3597 0.844559 7264 First Reading 2491 2563 2499 2491 2491 2491 2491 2562 Last Reading 6265.5 6265.5 6201 6193.5 6193.5 6193.5 6193.5 6193.5 First Reading For Entire File .......... 2491 Last Reading For Entire File ........... 6265.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2490 0 2490 0 2490 0 2490 0 2498 0 2561 0 2562 0 SURFACE SOFTWARE VERSION: DOW/W-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: STOP DEPTH 6188.5 6188.5 6188.5 6188.5 6196.0 6188.5 6260.5 10-NOV-97 5.07 5.46 MEMORY 6265.0 2562.0 6265.0 30.5 79.1 TOOL NUMBER PO869PCRGM6 PO869PCRGM6 9.880 9.9 SPUD/LSND MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.30 68.0 9.0 1400 5.2 2.900 2.510 2.400 4.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 28.4 First Name Min Max Mean Nsam Reading DEPT 2490 6260.5 4375.25 7542 2490 ROP 13.8478 2176.03 277.21 7398 2562 GR 10.267 115.786 57.8162 7397 2498 RPX 2.1598 78.2482 10.9522 7398 2490 RPS 2.2731 113.79 11.802 7398 2490 RPM 2.106 199.231 11.5871 7398 2490 Last Reading 6260.5 6260.5 6196 6188.5 6188.5 6188.5 RPD 2.292 222.335 12.1831 7398 FET 0.1484 8.3597 0.844624 7256 2490 6188.5 2561 6188.5 First Reading For Entire File .......... 2490 Last Reading For Entire File ........... 6260.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File COMPANY NAIVE WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO * * ALASKA COMPUTING CENTER * * *WESTBRNATLAS LOGS PROCESSED* * ............. BY ............. * ~ BP ~P~O~Tio~Date..~ : MPJ-2i : MILNEPOINT : NORTH SLOPE : AK : 500292282500 : 98489 LIS Tape Verification Listing Schlumberger Alas.~a Compu. ting Center 29-SEP-1998 11:24 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/09/29 ORIGIN : FLIC REEL NAFZE : 98489 CONTINUATION # : PREVIOUS REEL : COFE4F2~f : BP EXPLORATION, MILNE POINT, MPJ-21, API #50-029-22825-00 **** TAPE H~ER **** SERVICE NAFiE : EDIT DATE : 98/09/29 ORIGIN : FLIC TAPE NAM~ : 98489 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~aVT : BP EXPLORATION, MILNE POINT, MPJ-21, API #50-029-22825-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NA~E: MPJ- 21 API NUf4BER: 500292282500 OPERATOR: BP EXPLORATION LOGGING COMPANY: WESTERN ATLAS TAPE CREATION DATE: 29-SEP-98 JOB NUMBER: 98489 LOGGING ENGINEER: R. ECK OPERATOR WITNESS: THACKERAY SURFACE LOCATION SECTION: 28 TOWNSHIP .. 13N RANGE: 10E FNL: FSL: 2179 FEL: 3276 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 64.12 GROUND LEVEL: 35. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 6242.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaso~a Compqting Center 29-SEP-1998 11:24 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GR CCL CONTAINED HEREIN IS THE WESTERN ATLAS GR/CCL/TENS DATA ACQUIRED ON BP EXPLORATION WELL MPJ-21 ON 6-AUG-98. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/09/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIA~BER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GR 6160.0 5392.0 CCL 6157.0 5392.0 $ CURVE SHIFT DATA - PASS TO PASS (F1EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GR CCL .............. REMARKS: THIS FILE CONTAINS THE CLIPPED GR/CCL/TENS DATA FOR THE LIS Tape Verification Listing Schlumberger Alaska Compu. ting Center 29-SEP-1998 11:24 PAGE: MAIN PASS. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CCL LB 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CCL V 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 6160.000 GRCH. GR 56.311 TENS.CCL 354.208 CCL.CCL DEPT. 5392.000 GRCH. GR 33.495 TENS.CCL -19.316 CCL.CCL -999.250 8.580 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-SEP-1998 11:24 PAGE: **** FILE TRAILER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENU~fBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~flV~XRY VENDOR TOOL CODE START DEPTH STOP DEPTH 6167.0 5383.5 GR LOG HEADER DATA DATE LOGGED: 6-AUG-98 SOFTWARE VERSION: JO01 1.1 TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 6155.0 TD LOGGER (FT) : 6159.0 TOP LOG INTERVAL (FT): 5390.0 BOTTOM LOG INTERVAL (FT) : 6158.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR GR GAAff4A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : TOOL ~ER CCL GR LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-SEP-1998 11:24 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6242.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE 8.50 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) .' FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG RAN WITHMARKED LINE FOR PRIMARY DEPTH CONTROL. THIS FILE CONTAINS THE RAW GR/CCL/TENS DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaslca Comp~ting Center 29-SEP-1998 11:24 PAGE: 6 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 GR PS1 GAPI 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PSi V 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 6167. 000 GR. PS1 O. 000 TENS. PS1 O. 000 CCL. PS1 DEPT. 5383.500 GR.PS1 0.000 TENS. PSi -500.000 CCL.PS1 40.000 3.900 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 98/09/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska. Comp~ting Center 29-SEP-1998 11:24 PAGE: **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 98/09/29 ORIGIN : FLIC TAPE NA~E : 98489 CONTINUATION # : 1 PREVIOUS TAPE : COI~_2~f . BP EXPLORATION, MILNE POINT, MPJ-21, API #50-029-22825-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 98/09/29 ORIGIN : FLIC REEL NANiE : 98489 CONTINUATION # : PREVIOUS REEL : COf~2~f : BP EXPLORATION, MILNE POINT, MPJ-21, API #50-029-22825-00